Companies: 10,795     total market cap: $143.196 T
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Hawaiian Electric Industries
HE
#4328
Rank
$2.63 B
Marketcap
๐Ÿ‡บ๐Ÿ‡ธ United States
Country
$15.26
Share price
-0.78%
Change (1 day)
51.69%
Change (1 year)
๐Ÿ”‹ Electricity๐Ÿšฐ Utility companies โšก Energy
Categories
  1. Hawaiian Electric Industries
  2. Quarterly Reports (10-Q)
  3. Submitted on 2024-08-09

Hawaiian Electric Industries - 10-Q quarterly report FY


Text size:
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
 FORM 10-Q
 
☒      QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the quarterly period ended June 30, 2024
 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 CharterCommission File NumberI.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)
RegistrantTitle of each classTrading Symbol(s)Name of each exchange on which registered
Hawaiian Electric Industries, Inc. Common Stock, Without Par ValueHENew York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Hawaiian Electric Industries, Inc.Yes☒No☐ Hawaiian Electric Company, Inc. Yes☒No☐
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
Hawaiian Electric Industries, Inc.Yes☒No☐ Hawaiian Electric Company, Inc.Yes☒No☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.
Hawaiian Electric Industries, Inc.: Hawaiian Electric Company, Inc.:
Large accelerated filer☒Smaller reporting company☐Large accelerated filer☐Smaller reporting company☐
Accelerated filer☐Emerging growth company☐Accelerated filer☐Emerging growth company☐
Non-accelerated filer☐Non-accelerated filer☒
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Hawaiian Electric Industries, Inc.☐Hawaiian Electric Company, Inc.☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Hawaiian Electric Industries, Inc.Yes☐No☒Hawaiian Electric Company, Inc.Yes☐No☒
Securities registered pursuant to 12(b) of the Act:
APPLICABLE ONLY TO CORPORATE ISSUERS:
Indicate the number of shares outstanding of each of the issuers’ classes of common stock, as of the latest practicable date.
Class of Common Stock 
Outstanding July 31, 2024
Hawaiian Electric Industries, Inc. (Without Par Value) 110,303,446 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 June 30, 2024
 
TABLE OF CONTENTS
 
Page No. 
ii
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three and six months ended June 30, 2024 and 2023
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three and six months ended June 30, 2024 and 2023
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three and six months ended June 30, 2024 and 2023
5
 
six months ended June 30, 2024 and 2023
  
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three and six months ended June 30, 2024 and 2023
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three and six months ended June 30, 2024 and 2023
11
 
six months ended June 30, 2024 and 2023
12
 
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i

Hawaiian Electric Industries, Inc. and Subsidiaries
Hawaiian Electric Company, Inc. and Subsidiaries
Form 10-Q—Quarter ended June 30, 2024
GLOSSARY OF TERMS
Terms Definitions
ABL Facility
Asset-based lending facility
ABRAlternate Base Rate
ACLAllowance for credit losses, which is the current credit loss standard, requires recording the allowance based on the expected loss model
AES HawaiiAES Hawaii, Inc.
AOCIAccumulated other comprehensive income/(loss)
ARAAnnual revenue adjustment
ASBAmerican Savings Bank, F.S.B., a wholly owned subsidiary of ASB Hawaii, Inc.
ASB HawaiiASB Hawaii, Inc., a wholly owned subsidiary of Hawaiian Electric Industries, Inc. and the parent company of American Savings Bank, F.S.B.
ASUAccounting Standards Update
CBRECommunity-based renewable energy
Company
Hawaiian Electric Industries, Inc. and its direct and indirect subsidiaries, including, without limitation, Hawaiian Electric Company, Inc. and its subsidiaries (listed under Hawaiian Electric); ASB Hawaii, Inc. and its subsidiary, American Savings Bank, F.S.B. and Pacific Current, LLC and its subsidiaries (listed under Pacific Current).
Consumer AdvocateDivision of Consumer Advocacy, Department of Commerce and Consumer Affairs of the State of Hawaii
CSSMCollective Shared Savings Mechanism
D&ODecision and order from the PUC
DERDistributed energy resources
DRIPHEI Dividend Reinvestment and Stock Purchase Plan
ECRCEnergy cost recovery clause
EIP
2010 Equity and Incentive Plan, as amended
EPAEnvironmental Protection Agency — federal
EPRMExceptional Project Recovery Mechanism
EPSEarnings per share
ESMEarnings Sharing Mechanism
EVEEconomic value of equity
Exchange ActSecurities Exchange Act of 1934
FDICFederal Deposit Insurance Corporation
federalU.S. Government
FHLBFederal Home Loan Bank
FHLMCFederal Home Loan Mortgage Corporation
FitchFitch Ratings, Inc.
FNMAFederal National Mortgage Association
FRBFederal Reserve Board
GAAPAccounting principles generally accepted in the United States of America
GHGGreenhouse gas
GNMAGovernment National Mortgage Association
GSPAGrid Services Purchase Agreement
Hamakua EnergyHamakua Energy, LLC, an indirect subsidiary of Pacific Current
Hawaii Electric LightHawaii Electric Light Company, Inc., an electric utility subsidiary of Hawaiian Electric Company, Inc.
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, Renewable Hawaii, Inc. and HE AR INTER LLC
HEI
Hawaiian Electric Industries, Inc., direct parent company of Hawaiian Electric Company, Inc., ASB Hawaii, Inc. and Pacific Current, LLC.
ii
GLOSSARY OF TERMS, continued
Terms Definitions
HEIRSPHawaiian Electric Industries Retirement Savings Plan
HELOCHome equity line of credit
HPOWERCity and County of Honolulu with respect to a power purchase agreement for a refuse-fired plant
IIJAInfrastructure Investment and Jobs Act
IPPIndependent power producer
IRLCsInterest rate lock commitments
IWSM
Interim Wildfire Safety Measures
KalaeloaKalaeloa Partners, L.P.
kWhKilowatthour/s (as applicable)
LMILow-to-moderate income
LTIPLong-term incentive plan
MahipapaMahipapa, LLC, a subsidiary of Pacific Current
Maui ElectricMaui Electric Company, Limited, an electric utility subsidiary of Hawaiian Electric Company, Inc.
Maui windstorm and wildfires
The fires in the West Maui (Lahaina) and Upcountry Maui areas that caused fatalities and widespread property damage in Lahaina on August 8, 2023
MauoMauo, LLC, a subsidiary of Pacific Current
MFD
County of Maui Department of Fire and Public Safety
Moody’sMoody’s Investors Service’s
MPIRMajor Project Interim Recovery
MRPMulti-year rate period
MSRsMortgage servicing rights
MWMegawatt/s (as applicable)
NIINet interest income
NPBCNet periodic benefit costs
NPPCNet periodic pension costs
O&MOther operation and maintenance
OCCOffice of the Comptroller of the Currency
OPEBPostretirement 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
PBRPerformance-based regulation
PIMsPerformance incentive mechanisms
PPAPower purchase agreement
PPACPurchased power adjustment clause
PSPS
Public Safety Power Shutoff
PUCPublic Utilities Commission of the State of Hawaii
PVPhotovoltaic
RAMRevenue adjustment mechanism
RBARevenue balancing account
RFPRequest for proposals
ROACEReturn on average common equity
RORBReturn on rate base
RPSRenewable portfolio standards
S&PS&P Global Ratings
SBASmall Business Administration
SECSecurities and Exchange Commission
SeeMeans the referenced material is incorporated by reference
SOFRSecured Overnight Financing Rate
UtilitiesHawaiian Electric Company, Inc., Hawaii Electric Light Company, Inc. and Maui Electric Company, Limited
VIEsVariable 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:
•the impact of the Maui windstorm and wildfires including the potential liabilities from the many lawsuits filed against the Company and the Utilities and potential regulatory penalties which may result in significant costs that may be unrecoverable (or not reimbursed on a timely basis) through insurance and/or rates;
•an increase in insurance premiums and the inability to fully recover premiums through rates or the potential inability to obtain wildfire and general liability insurance coverage at reasonable rates, if available at all;
•the uncertainties surrounding the Company’s and the Utilities’ access to capital and credit markets due to the uncertainties associated with the costs related to the Maui windstorm and wildfires;
•the ability to raise the amount of capital necessary on reasonable terms, if at all, for the Company’s and the Utilities’ contribution to the Maui wildfire tort litigation settlement in order to alleviate the conditions causing substantial doubt about the Company’s and the Utilities’ ability to continue as a going concern;
•potential dilution to existing shareholders if the Company raises funds by issuing equity or equity-linked securities;
•the inability to execute financing plans to alleviate the conditions causing substantial doubt about the Company’s and the Utilities’ ability to continue as a going concern prior to the issuance of their respective annual financial statements, which could result in an event of default and an acceleration of the Company’s and the Utilities’ debt and lead to filing for bankruptcy protection if waivers from lenders are not received;
•extreme weather events, including windstorms and other natural disasters, particularly those driven or exacerbated by climate change, which could increase the risk of the Utilities’ equipment being damaged, becoming inoperable or contributing to a wildfire;
•the suspension, material reduction or extended delay in dividends or other distributions from one or more operating subsidiaries to HEI;
•further downgrades by securities rating agencies in their ratings of the securities of HEI and Hawaiian Electric and their impact on results of financing efforts;
•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;
•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 the Utilities’ 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 ability to adequately address risks and capitalize on opportunities related to the Company’s and the Utilities environmental, social and governance priority areas, which include safety, reliability and resilience, including relating to wildfires and other extreme weather events, decarbonization, economic health and affordability, 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;
iv

•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;
•changes in interest rates and market liquidity, as well as the magnitude of such changes, which may reduce interest margins, impact funding sources, alter valuations and affect the ability to originate and distribute financial products in the primary and secondary markets;
•the continued 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 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 and conflict in the Middle East), 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 or additional 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;
v

•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);
•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;
•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;
•the final outcome of tax positions taken by HEI and its subsidiaries;
•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; 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 June 30Six months ended June 30
(in thousands, except per share amounts)2024202320242023
Revenues    
Electric utility$792,331 $794,191 $1,580,909 $1,624,552 
Bank101,943 96,885 207,087 190,742 
Other3,086 4,609 6,522 8,628 
Total revenues897,360 895,685 1,794,518 1,823,922 
Expenses    
Electric utility (includes $1,712 million of Wildfire tort-related claims in 2024) (Note 2)
2,436,771 720,566 3,161,994 1,475,052 
Bank (includes $82 million of goodwill impairment in 2024) (Note 5)
159,329 72,017 238,941 142,354 
Other20,235 10,123 36,139 20,019 
Total expenses2,616,335 802,706 3,437,074 1,637,425 
Operating income (loss)    
Electric utility(1,644,440)73,625 (1,581,085)149,500 
Bank(57,386)24,868 (31,854)48,388 
Other(17,149)(5,514)(29,617)(11,391)
Total operating income (loss)
(1,718,975)92,979 (1,642,556)186,497 
Retirement defined benefits credit—other than service costs1,281 1,153 2,563 2,305 
Interest expense, net—other than on deposit liabilities and other bank borrowings
(32,400)(29,832)(63,991)(58,630)
Allowance for borrowed funds used during construction1,344 1,295 2,730 2,426 
Allowance for equity funds used during construction3,336 3,772 6,976 7,073 
Interest income
3,134 — 6,267 — 
Income (loss) before income taxes
(1,742,280)69,367 (1,688,011)139,671 
Income tax expense (benefit)
(447,269)14,284 (435,595)29,394 
Net income (loss)
(1,295,011)55,083 (1,252,416)110,277 
Preferred stock dividends of subsidiaries473 473 946 946 
Net income (loss) for common stock
$(1,295,484)$54,610 $(1,253,362)$109,331 
Basic earnings (loss) per common share
$(11.74)$0.50 $(11.37)$1.00 
Diluted earnings (loss) per common share
$(11.74)$0.50 $(11.37)$1.00 
Weighted-average number of common shares outstanding:
Basic
110,303 109,573 110,260 109,544 
Diluted
110,303 109,780 110,260 109,870 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.

1

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Comprehensive Income (unaudited)
 Three months ended June 30Six months ended June 30
(in thousands)2024202320242023
Net income (loss) for common stock
$(1,295,484)$54,610 $(1,253,362)$109,331 
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 $(617), $(4,021), $(5,592) and $2,058, respectively
(1,686)(10,984)(15,275)5,621 
Amortization of unrealized holding losses on held-to-maturity securities, net of taxes of $1,205, $1,350, $2,334 and $2,696, respectively
3,288 3,689 6,374 7,366 
Derivatives qualifying as cash flow hedges:    
Unrealized interest rate hedging gains (losses) arising during the period, net of taxes of $11, $(117), $267 and $(52), respectively
29 (335)769 (149)
Reclassification adjustment to net income, net of taxes of $(18), $(16), $(34) and $(33), respectively
(51)(48)(99)(96)
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 of $(155), $(122), $(309) and $(244), respectively
(445)(357)(894)(714)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $160, $148, $319 and $295, respectively
459 426 918 851 
Other comprehensive income (loss), net of taxes
1,594 (7,609)(8,207)12,879 
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc.
$(1,293,890)$47,001 $(1,261,569)$122,210 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.

2

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets (unaudited) 
(dollars in thousands)June 30, 2024December 31, 2023
Assets  
Cash and cash equivalents$550,408 $679,546 
Restricted cash16,422 15,028 
Accounts receivable and unbilled revenues, net476,148 575,176 
Available-for-sale investment securities, at fair value1,061,687 1,136,439 
Held-to-maturity investment securities, at amortized cost1,179,182 1,201,314 
Stock in Federal Home Loan Bank, at cost29,204 14,728 
Loans held for investment, net5,963,345 6,106,438 
Loans held for sale, at lower of cost or fair value13,904 15,168 
Property, plant and equipment, net of accumulated depreciation of $3,415,729 and $3,317,759 at June 30, 2024 and December 31, 2023, respectively
6,298,721 6,150,126 
Operating lease right-of-use assets86,819 94,905 
Regulatory assets322,409 294,804 
Other1,057,165 877,959 
Goodwill— 82,190 
Total assets$17,055,414 $17,243,821 
Liabilities and shareholders’ equity  
Liabilities  
Accounts payable$248,668 $247,462 
Interest and dividends payable34,528 51,206 
Deposit liabilities8,036,473 8,145,778 
Other bank borrowings520,000 750,000 
Long-term debt, net—other than bank2,838,224 2,842,429 
Deferred income taxes— 297,954 
Operating lease liabilities94,565 103,900 
Finance lease liabilities443,366 339,040 
Regulatory liabilities1,175,609 1,150,690 
Defined benefit pension and other postretirement benefit plans liability82,794 82,879 
Wildfire tort-related claims1,712,000 75,000 
Other749,621 778,349 
Total liabilities15,935,848 14,864,687 
Preferred stock of subsidiaries - not subject to mandatory redemption34,293 34,293 
Commitments and contingencies (Notes 2, 4 and 5)
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: 110,303,446 shares and 110,151,798 shares at June 30, 2024 and December 31, 2023, respectively
1,709,472 1,707,471 
Retained earnings (deficit)
(326,642)926,720 
Accumulated other comprehensive loss, net of tax benefits(297,557)(289,350)
Total shareholders’ equity1,085,273 2,344,841 
Total liabilities and shareholders’ equity$17,055,414 $17,243,821 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.
3

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Changes in Shareholders’ Equity (unaudited) 
 Common stock
Retained earnings
Accumulated
other
comprehensive		 
(in thousands)SharesAmount
(deficit)
income (loss)Total
Balance, December 31, 2023
110,152 $1,707,471 $926,720 $(289,350)$2,344,841 
Net income for common stock— — 42,122 — 42,122 
Other comprehensive loss, net of tax benefits
— — — (9,801)(9,801)
Share-based expenses and other, net151 218 — — 218 
Balance, March 31, 2024
110,303 1,707,689 968,842 (299,151)2,377,380 
Net loss for common stock
— — (1,295,484)— (1,295,484)
Other comprehensive income, net of taxes
— — — 1,594 1,594 
Share-based expenses and other, net— 1,783 — — 1,783 
Balance, June 30, 2024110,303 $1,709,472 $(326,642)$(297,557)$1,085,273 
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, net101 (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 
Net income for common stock— — 54,610 — 54,610 
Other comprehensive loss, net of tax benefits— — — (7,609)(7,609)
Share-based expenses and other, net40 3,868 — — 3,868 
Common stock dividends (36¢ per share)
— — (39,447)— (39,447)
Balance, June 30, 2023109,612 $1,696,258 $876,268 $(323,149)$2,249,377 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.

4

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited)
Six months ended June 30
(in thousands)20242023
Cash flows from operating activities  
Net income (loss)
$(1,252,416)$110,277 
Adjustments to reconcile net income (loss) to net cash provided by operating activities
  
Depreciation of property, plant and equipment136,888 133,232 
Other amortization24,602 21,609 
Provision for credit losses(4,069)1,218 
Loans originated, held for sale(57,381)(14,912)
Proceeds from sale of loans, held for sale57,259 14,596 
Gain on sale of loans, net(788)(360)
Deferred income tax expense (benefit)
(455,510)(1,309)
Share-based compensation expense3,075 5,919 
Allowance for equity funds used during construction(6,976)(7,073)
Goodwill impairment
82,190 — 
Other1,537 (3,710)
Changes in assets and liabilities
Decrease in accounts receivable and unbilled revenues, net
99,756 103,695 
Decrease in fuel oil stock
1,188 47,963 
Decrease (increase) in materials and supplies
1,324 (11,662)
Increase in regulatory assets
(23,425)(10,620)
Increase in regulatory liabilities16,716 22,782 
Increase in accounts, interest and dividends payable19,857 34,946 
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes(44,470)(45,171)
Decrease in defined benefit pension and other postretirement benefit plans liability(4,784)(4,304)
Increase in Wildfire tort-related claims
1,637,000 — 
Change in other assets and liabilities(38,126)(25,499)
Net cash provided by operating activities193,447 371,617 
Cash flows from investing activities  
Principal repayments on available-for-sale investment securities52,545 68,279 
Proceeds from repayments or maturities of held-to-maturity investment securities29,417 35,604 
Purchase of stock from Federal Home Loan Bank (36,121)(62,400)
Redemption of stock from Federal Home Loan Bank21,645 70,960 
Net decrease (increase) in loans held for investment
119,072 (208,042)
Proceeds from sale of commercial loans31,067 66,655 
Purchase of loans held for investment— (26,195)
Capital expenditures(179,865)(235,875)
Other(4,237)8,160 
Net cash provided by (used in) investing activities
33,523 (282,854)
(continued)

5

Hawaiian Electric Industries, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited) (continued)
Six months ended June 30
(in thousands)20242023
Cash flows from financing activities  
Net decrease in deposit liabilities
(109,305)(104,771)
Net decrease in short-term borrowings with original maturities of three months or less
— (91,438)
Net decrease in other bank borrowings with original maturities of three months or less
— (596,810)
Proceeds from issuance of short-term debt— 65,000 
Repayment of short-term debt— (100,000)
Proceeds from issuance of other bank borrowings320,000 1,000,000 
Repayment of other bank borrowings(550,000)(250,000)
Proceeds from issuance of long-term debt4,673 250,000 
Repayment of long-term debt(9,888)(62,426)
Withheld shares for employee taxes on vested share-based compensation(1,074)(2,356)
Common stock dividends— (78,893)
Preferred stock dividends of subsidiaries(946)(946)
Other(8,174)(1,662)
Net cash provided by (used in) financing activities
(354,714)25,698 
Net increase (decrease) in cash, cash equivalents and restricted cash(127,744)114,461 
Cash, cash equivalents and restricted cash, beginning of period694,574 204,927 
Cash, cash equivalents and restricted cash, end of period566,830 319,388 
Less: Restricted cash(16,422)(5,104)
Cash and cash equivalents, end of period$550,408 $314,284 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.
6

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Income (unaudited)
Three months ended June 30Six months ended June 30
(in thousands)2024202320242023
Revenues$792,331 $794,191 $1,580,909 $1,624,552 
Expenses    
Fuel oil258,652 280,157 542,948 614,254 
Purchased power181,328 168,434 341,145 321,195 
Other operation and maintenance147,561 136,360 291,451 264,676 
Wildfire tort-related claims (Note 2)
1,712,000 — 1,712,000 — 
Depreciation62,812 60,689 125,624 121,616 
Taxes, other than income taxes74,418 74,926 148,826 153,311 
Total expenses2,436,771 720,566 3,161,994 1,475,052 
Operating income (loss)
(1,644,440)73,625 (1,581,085)149,500 
Allowance for equity funds used during construction3,336 3,772 6,976 7,073 
Retirement defined benefits credit—other than service costs1,072 1,048 2,144 2,095 
Interest expense and other charges, net(21,417)(20,872)(41,402)(41,118)
Allowance for borrowed funds used during construction1,344 1,295 2,730 2,426 
Interest income1,452 — 2,884 — 
Income (loss) before income taxes
(1,658,653)58,868 (1,607,753)119,976 
Income tax expense (benefit)
(429,758)13,070 (418,578)26,670 
Net income (loss)
(1,228,895)45,798 (1,189,175)93,306 
Preferred stock dividends of subsidiaries229 229 458 458 
Net income (loss) attributable to Hawaiian Electric
(1,229,124)45,569 (1,189,633)92,848 
Preferred stock dividends of Hawaiian Electric270 270 540 540 
Net income (loss) for common stock
$(1,229,394)$45,299 $(1,190,173)$92,308 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 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 June 30Six months ended June 30
(in thousands)2024202320242023
Net income (loss) for common stock
$(1,229,394)$45,299 $(1,190,173)$92,308 
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 of $(175), $(163), $(351) and $(326), respectively
(505)(470)(1,013)(940)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $160, $148, $319 and $295, respectively
459 426 918 851 
Other comprehensive loss, net of taxes(46)(44)(95)(89)
Comprehensive income (loss) attributable to Hawaiian Electric Company, Inc.
$(1,229,440)$45,255 $(1,190,268)$92,219 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.
7

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets (unaudited)
(dollars in thousands, except par value)June 30, 2024December 31, 2023
Assets  
Property, plant and equipment
Utility property, plant and equipment  
Land$52,019 $52,098 
Plant and equipment8,351,894 8,232,810 
Right-of-use assets - finance lease449,572 342,174 
Less accumulated depreciation(3,286,720)(3,197,514)
Construction in progress336,203 320,223 
Utility property, plant and equipment, net5,902,968 5,749,791 
Nonutility property, plant and equipment, less accumulated depreciation of $42 and $40 as of June 30, 2024 and December 31, 2023, respectively
6,940 6,942 
Total property, plant and equipment, net5,909,908 5,756,733 
Current assets  
Cash and cash equivalents88,620 106,077 
Restricted cash2,000 2,000 
Customer accounts receivable, net211,315 244,309 
Accrued unbilled revenues, net178,546 185,644 
Other accounts receivable, net57,892 111,519 
Fuel oil stock, at average cost146,091 148,237 
Materials and supplies, at average cost113,004 114,433 
Prepayments and other66,596 58,491 
Regulatory assets79,270 68,453 
Total current assets943,334 1,039,163 
Other long-term assets  
Operating lease right-of-use assets64,740 71,877 
Regulatory assets243,139 226,351 
Other237,777 189,430 
Total other long-term assets545,656 487,658 
Total assets$7,398,898 $7,283,554 
(continued)














8

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets (unaudited) (continued)
(dollars in thousands, except par value)June 30, 2024December 31, 2023
Capitalization and liabilities  
Capitalization  
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 17,854,278 shares at June 30, 2024 and December 31, 2023)
$119,048 $119,048 
Premium on capital stock810,955 810,955 
Retained earnings260,085 1,476,258 
Accumulated other comprehensive income, net of taxes-retirement benefit plans2,754 2,849 
Common stock equity1,192,842 2,409,110 
Cumulative preferred stock — not subject to mandatory redemption34,293 34,293 
Long-term debt, net1,887,793 1,934,277 
Total capitalization3,114,928 4,377,680 
Commitments and contingencies (Notes 2 and 4)
Current liabilities 
Current portion of operating lease liabilities15,902 16,617 
Current portion of long-term debt, net46,954 — 
Accounts payable194,534 191,040 
Interest and preferred dividends payable22,992 22,882 
Taxes accrued, including revenue taxes249,459 291,942 
Regulatory liabilities24,106 36,559 
Wildfire tort-related claims (Note 2)
1,712,000 75,000 
Other112,037 96,436 
Total current liabilities2,377,984 730,476 
Deferred credits and other liabilities 
Operating lease liabilities54,779 62,098 
Finance lease liabilities433,231 330,978 
Deferred income taxes— 399,001 
Regulatory liabilities1,151,503 1,114,131 
Unamortized tax credits79,231 84,312 
Defined benefit pension liability60,636 60,671 
Other126,606 124,207 
Total deferred credits and other liabilities1,905,986 2,175,398 
Total capitalization and liabilities$7,398,898 $7,283,554 

This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.
9

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Changes in Common Stock Equity (unaudited)
 
 Common stockPremium
on
capital		RetainedAccumulated
other
comprehensive		 
(in thousands)SharesAmountstockearnings
income
Total
Balance, December 31, 202317,854 $119,048 $810,955 $1,476,258 $2,849 $2,409,110 
Net income for common stock— — — 39,221 — 39,221 
Other comprehensive loss, net of taxes— — — — (49)(49)
Common stock dividends— — — (13,000)— (13,000)
Balance, March 31, 202417,854 119,048 810,955 1,502,479 2,800 2,435,282 
Net loss for common stock
— — — (1,229,394)— (1,229,394)
Other comprehensive loss, net of taxes— — — — (46)(46)
Common stock dividends— — — (13,000)— (13,000)
Balance, June 30, 202417,854 $119,048 $810,955 $260,085 $2,754 $1,192,842 
Balance, December 31, 202217,854 $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, 202317,854 119,048 810,955 1,426,065 2,816 2,358,884 
Net income for common stock— — — 45,299 — 45,299 
Other comprehensive loss, net of taxes— — — — (44)(44)
Common stock dividends— — — (32,250)— (32,250)
Balance, June 30, 202317,854 $119,048 $810,955 $1,439,114 $2,772 $2,371,889 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 Form 10-K.


10
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited)
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows (unaudited)
Six months ended June 30
(in thousands)20242023
Cash flows from operating activities  
Net income (loss)
$(1,189,175)$93,306 
Adjustments to reconcile net income (loss) to net cash provided by operating activities
  
Depreciation of property, plant and equipment125,624 121,616 
Other amortization15,082 13,017 
Deferred income tax expense (benefit)
(440,503)(6,164)
State refundable credit(5,880)(5,750)
Bad debt expense2,801 2,813 
Allowance for equity funds used during construction(6,976)(7,073)
Other17 381 
Changes in assets and liabilities  
Decrease in accounts receivable86,832 76,219 
Decrease in accrued unbilled revenues7,614 28,797 
Decrease in fuel oil stock2,146 47,730 
Decrease (increase) in materials and supplies1,429 (11,587)
Increase in regulatory assets(23,425)(10,620)
Increase in regulatory liabilities16,716 22,782 
Increase in accounts payable38,008 26,984 
Change in prepaid and accrued income taxes, tax credits and revenue taxes(43,573)(44,941)
Decrease in defined benefit pension and other postretirement benefit plans liability(3,916)(3,926)
Increase in Wildfire tort-related claims
1,637,000 — 
Change in other assets and liabilities(34,348)(7,439)
Net cash provided by operating activities185,473 336,145 
Cash flows from investing activities  
Capital expenditures(168,200)(230,149)
Other1,543 4,056 
Net cash used in investing activities(166,657)(226,093)
Cash flows from financing activities  
Common stock dividends(26,000)(64,500)
Preferred stock dividends of Hawaiian Electric and subsidiaries(998)(998)
Proceeds from issuance of long-term debt— 150,000 
Net decrease in short-term borrowings from non-affiliates and affiliates with original maturities of three months or less— (87,967)
Payments of obligations under finance leases(3,737)(1,339)
Other(5,538)(843)
Net cash used in financing activities
(36,273)(5,647)
Net increase (decrease) in cash, cash equivalents and restricted cash(17,457)104,405 
Cash, cash equivalents and restricted cash, beginning of period108,077 39,242 
Cash, cash equivalents and restricted cash, end of period90,620 143,647 
Less: Restricted cash(2,000)— 
Cash and cash equivalents, end of period$88,620 $143,647 
This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2023 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 assuming that the Company will continue as a going concern and 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, 2023.
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 June 30, 2024 and December 31, 2023, the results of their operations for the three and six months ended June 30, 2024 and 2023, and cash flows for the six months ended June 30, 2024 and 2023. 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.
For the three and six months ended June 30, 2024, the Company incurred net losses of approximately $1.30 billion and $1.25 billion, respectively. For the three and six months ended June 30, 2024, the Utilities incurred net losses of approximately $1.23 billion and $1.19 billion, respectively. The net losses were primarily due to the accrual of estimated wildfire liabilities totaling approximately $1.71 billion related to the Maui windstorm and wildfire tort-related legal claims (see Note 2).
When preparing financial statements for each annual and interim reporting period, management has the responsibility to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the Company’s ability to continue as a going concern within one year after the date that the financial statements are issued. In making its evaluation, the Company considers, among other things, risks and/or uncertainties related to its results of operations, contractual obligations, including near-term debt maturities, dividend requirements, debt covenant compliance, or other factors impacting the Company’s liquidity and capital resources. As of the date of filing of this Form 10-Q, management has not yet implemented a capital financing plan to address expected wildfire settlement payments. If the conditions resulting in the substantial doubt are not resolved prior to the issuance of the Company’s annual financial statements, or it is not yet probable that management's plans can be effectively implemented to address those conditions, the Company would be in default on certain terms of its taxable debt agreements and syndicated credit facility agreements, and lenders would have the option to call the outstanding debt. Management believes HEI’s and the Utilities’ current cash balance at June 30, 2024 of $124.4 million and $88.6 million, respectively, and available capacity on the asset-based lending facility (ABL Facility) would not be sufficient to fund the Company’s planned expenditures and operational needs, which include potential payments to settle wildfire claims.
These conditions raise substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern within one year after the date that financial statements are issued. The ability to continue as a going concern is dependent primarily upon the Company’s ability to raise the capital necessary to fund the contribution to the settlement of wildfire tort claims while also meeting their obligations to repay their liabilities arising from normal business operations when they become due. The accompanying consolidated financial statements have been prepared on a basis which assumes HEI and the Utilities are a going concern and do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amounts and classifications of liabilities that may result from any uncertainty related to HEI’s and the Utilities’ ability to continue as a going concern. Such adjustments could be material.
HEI and the Utilities are currently working with their financial advisors on a financing plan to raise the capital necessary to fund the contribution to the settlement of wildfire tort claims. The Company expects to finance the settlement payments over time through a mix of debt, common equity, equity-linked securities or other potential options. While management believes the Company will be able to raise the necessary capital, there is no assurance that management’s plans will be successful.

HEI’s and the Utilities’ future results of operations involve significant risks and uncertainties. Factors that could affect HEI’s and the Utilities’ future operating results and could cause actual results to vary materially from expectations include, but are not limited to, access to capital, ability to attract and retain key personnel, and pending or threatened litigation (including recent litigation noted above).
12

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Recent accounting pronouncements.
Segment Reporting. In November 2023, the FASB issued ASU No. 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures to improve reportable segment disclosure requirements, primarily through enhanced disclosure requirements of significant segment expenses. These amendments are effective for annual periods beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. These amendments apply on a retrospective basis. The Company is currently evaluating the impact of this amendment on the Company’s consolidated financial statements.
Income Taxes. In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvement to Income Tax Disclosures to enhance the transparency and decision usefulness of income tax disclosures. The amendments are effective for annual periods beginning after December 15, 2024. These amendments apply on a prospective basis with a retrospective option. Early adoption is permitted. The Company is currently evaluating the impact of this amendment on the Company’s consolidated financial statements.
Climate-related disclosures. In March 2024, the Securities and Exchange Commission (SEC) issued final climate-related disclosure rules under SEC Release No. 33-11275, The Enhancement and Standardization of Climate-Related Disclosures for Investors (climate disclosure rules). The rules will require annual disclosure of material greenhouse gas emissions as well as disclosure of governance, risk management and strategy related to material climate-related risks. In addition, the rules require (i) financial statement impacts of severe weather events and other natural conditions; (ii) a roll forward of carbon offset and renewable energy credit balances if material to the Company’s plan to achieve climate-related targets or goals; and (iii) material impacts on estimates and assumptions in the financial statements. The disclosure requirements will begin phasing in for annual periods beginning with calendar year 2025. The Company is currently evaluating the final rule to determine its impact on the Company’s consolidated financial statements. In April 2024, the SEC voluntarily stayed implementation of its climate disclosure rules pending completion of judicial review by the Court of Appeals for the Eighth Circuit.
Reclassifications. Reclassifications of prior year Wildfire tort-related claims amounts were reclassified from “Other liabilities” and “Other current liabilities” for the Company and the Utilities, respectively, to conform to the current year financial statement presentation. Reclassifications did not affect previously reported cash flows, net income or retained earnings.
Note 2 · Maui windstorm and wildfires
On August 8, 2023, a number of brush fires in the West Maui (Lahaina) and Upcountry Maui areas caused widespread property damage, including damage to property of the Utilities, and 102 confirmed fatalities in Lahaina (the Maui windstorm and wildfires). The Maui windstorm and wildfires were fueled by extreme winds and drought-like conditions in those parts of Maui. The circumstances surrounding the Maui windstorm and wildfires are currently the subject of several investigations.
Restoration costs and recoveries. The Utilities are continuing restoration work to rebuild portions of the electric system in Lahaina to ensure safe and reliable power to all West Maui customers. Restoration efforts include the rebuilding of transmission and distribution lines along former routes in the Lahaina area with the installation of new interim steel poles and electrical equipment. To date, power has been restored to all customers that were able to have power restored in Lahaina and the rest of West Maui.
On December 27, 2023, the Public Utilities Commission of the State of Hawaii (PUC) issued an order authorizing deferred accounting treatment for the Utilities’ incremental non-labor expenses related to the Maui windstorm and wildfires. The deferred accounting treatment applies to certain non-labor expenses incurred from August 8, 2023 through December 31, 2024 that are not already a part of the base rates. The approval pertains only to deferred cost treatment; any cost recovery of deferred costs will be the subject of a separate application(s). As of June 30, 2024, the Utilities have deferred $30.2 million of certain incremental costs related to the Maui windstorm and wildfires to a regulatory asset.
While the Utilities plan to seek recovery of damage to covered electrical infrastructure under their property insurance programs, the timing and amount of any insurance recoveries are not determinable at this time and as such, an insurance receivable has not been recorded as of the date of this filing. The Company’s property insurance has a total policy limit of $500 million with a $1 million retention for damages related to Utility-owned non-generating assets, including overhead transmission and distribution assets within 1,000 feet of such assets. The Utilities believe capital expenditures related to restoration that are not covered by insurance will be managed under their current regulatory mechanisms, the recovery of which would be subject to PUC approval.
ASB’s Lahaina branch, including most of its contents and automated teller machine, was destroyed in the fire. The Bank leased the property of its Lahaina location.
13

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Third-party claims and other proceedings.
Tort-related legal claims. As of August 8, 2024, HEI and the Utilities have each been named in approximately 700 lawsuits related to the Maui windstorm and wildfires. These civil and class action lawsuits have been filed in the Maui and Oahu Circuit Courts against HEI, the Utilities, and other defendants, including the County of Maui, the State of Hawaii and related state entities, private landowners and developers, and telecommunications companies (collectively, tort-related legal claims). Two class actions are also pending in federal court. Most of these lawsuits allege that the defendants were responsible for, and/or negligent in failing to prevent or respond to the wildfires that led to the property destruction and loss of life. Other claims include, among other things, personal injury, wrongful death, emotional distress and inverse condemnation. One lawsuit asserting similar theories and claims was filed by the County of Maui against HEI and the Utilities, one lawsuit was filed by Spectrum Oceanic, LLC against HEI and the Utilities and other defendants, and other lawsuits were filed by approximately 160 subrogation insurers against HEI, the Utilities, a private landowner, and telecommunications companies. Additional lawsuits may be filed against the Company and other defendants in the future. The plaintiffs seek to recover damages and other costs, including punitive damages. Defendants have asserted cross-claims against one another for indemnification, contribution, and subrogation.
Various unaffiliated third parties have published estimates of the total economic damage generally ranging from $3.8 billion to $6 billion. These estimates have not been validated by the Company, and they represent gross numbers that do not take into account causation or liability and do not attempt to allocate responsibility among the various defendants. As such, these estimates are not intended to provide a range of a reasonably possible loss in excess of the recorded amount under ASC Topic 450-20, “Loss Contingencies” attributable to the Company arising from the Maui windstorm and wildfires. In addition, on November 6, 2023, the Hawaii Insurance Division of the State of Hawaii Department of Commerce and Consumer Affairs released preliminary data on Maui windstorm and wildfires claims, and the Hawaii Insurance Division has subsequently provided updated data to include estimated losses for commercial property and business interruption. Through June 30, 2024, the data collected from over 200 insurers indicated estimated total insured losses of $3.3 billion for residential, commercial, personal, and other property, and business interruption. The estimated total losses for insured claims related to residential property includes homeowners insurance, dwelling-fire landlord, condominium unit owner, renters insurance, and other residential property. The estimated total losses do not account for uninsured or underinsured property losses, interest, attorneys’ fees, fire suppression and clean-up costs, evacuation costs, personal injury or wrongful death damages, medical expenses or other costs, such as potential punitive damages, fines or penalties. It is uncertain whether the insured claims reported to the Hawaii Insurance Division are complete, and together with property damage claims unaccounted for, as mentioned above, the total amount of property damage claims could be materially higher than the amount reported by the Hawaii Insurance Division. The Hawaii Insurance Division did not state whether it intends to provide updated information in the future.
The Company is actively working with the State of Hawaii and others in the community on solutions for Maui’s recovery, including the compensation of those who suffered losses in the Maui windstorm and wildfires and who are currently named as plaintiffs in the various cases. On November 8, 2023, Hawaii Governor Josh Green announced the One ‘Ohana Initiative (the One ‘Ohana Initiative) as a collective path forward to recovery from the Maui windstorm and wildfires. The One ‘Ohana Initiative is a new humanitarian aid fund of $175 million, with the objective to compensate, in an expedited manner, those who have lost loved ones and those who have suffered severe injuries in the Maui windstorm and wildfires. The One ‘Ohana Initiative provides an alternative to a lengthy and expensive legal process. Beneficiaries who have lost loved ones are anticipated to receive payments of $1.5 million per decedent, and those who suffered severe injuries are expected to share in a specially allocated pool of compensation. In exchange for receiving such a payment, beneficiaries will be required to waive their ability to pursue legal claims for wrongful death and severe injuries. Hawaiian Electric fully supports this humanitarian initiative and has contributed $75 million. The Governor announced that other parties, including the State of Hawaii, the County of Maui, and Kamehameha Schools have all agreed to contribute to the fund. Hawaiian Electric’s contribution to the Initiative was less than half of the total, and Hawaiian Electric's insurance carriers funded its share of the contributions to the fund. Hawaiian Electric’s contribution is reflective of its commitment to join with community partners to provide solutions to promote Maui’s recovery. Hawaiian Electric’s commitment to contribute to the One ‘Ohana Initiative is not an admission of guilt or reflection of fault or liability related to the wildfires. Under the One ‘Ohana Initiative, all claimants (except families of missing persons) were required to submit a completed registration form and registrants who meet the Fund’s eligibility requirements then were required to complete and submit a claim form. As of the claim-submission deadline of July 15, 2024, 35 claim forms were received that relate to death claims and 12 claim forms were received that relate to physical injury claims.
On August 2, 2024, attorneys representing the individual and class plaintiffs reached an agreement in principle with all defendants to settle all of their tort-related legal claims in the litigation arising out of the Maui windstorm and wildfires. The agreement in principle was the product of a mediation process that lasted several months and remains subject to final documentation and court approval. Under the agreement in principle, HEI and Hawaiian Electric, the State of Hawaii, the County of Maui, Kamehameha Schools, West Maui Land Co., Hawaiian Telcom and Spectrum/Charter Communications have agreed to contribute a total of approximately $4.04 billion to one or more funds that would pay the claims of those who filed
14

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
lawsuits in state and federal courts, or who may have claims but have not yet filed lawsuits, in connection with the Maui windstorm and wildfires.
The agreement in principle does not resolve claims with insurers who have asserted subrogation claims in separate lawsuits, and such insurers are not parties to the agreement in principle. However, the agreement in principle provides that the definitive settlement agreement must provide for resolution of all subrogation claims by insurers that have been or could be brought against defendants arising out of the Maui windstorm and wildfires for no additional consideration. The agreement in principle includes a condition to the defendants’ obligations providing that within 90 days from its execution, either (a) insurers that have brought claims arising out of the Maui windstorm and wildfires enter into a written agreement that provides for releases of all claims against the defendants, or (b) that a trial court enters an order providing that if the final definitive agreement between the plaintiffs and the defendants becomes effective, then those same insurers’ exclusive remedy for any claims against the defendants would be limited to asserting liens against the settlement amounts obtained by the individual plaintiffs (so long as the order becomes final and unappealable within nine months from its date of issuance or, in that time period, those same insurers agree to provide the requisite releases).
Of the total settlement amount, HEI and Hawaiian Electric would contribute a total of $1.99 billion, which includes as a credit towards that amount the $75 million previously contributed for the One ‘Ohana Initiative, to be paid in four equal annual installments, with the first installment expected to be made no earlier than mid-2025. While the agreement in principle remains subject to final documentation and court approval, the Utilities have accrued their best estimate of the loss of approximately $1.71 billion, which represents the best estimate of the lump sum amount to settle claims with the plaintiffs as of June 30, 2024. The agreement in principle contains no admission of any liability by HEI or the Utilities and reflects the collective efforts of the State, HEI and the Utilities, and other defendants to seek a comprehensive resolution of the litigation arising out of the Maui windstorm and wildfires. The Utilities will seek insurance recovery to partially mitigate the potential financial impact; however, the timing and amount of any insurance recoveries are not determinable at this time.
As part of the agreement in principle, the parties agreed to vacate all trial dates and stay the litigation, except for litigation activities between the individual plaintiffs and the subrogation insurers and actions taken to further settlement. On August 2, 2024, the Second Circuit court overseeing the Special Proceeding in which most of the individual plaintiff actions have been coordinated vacated the trial dates that previously had been set. Accordingly, no trial dates are currently set in any action. No stay of litigation has been agreed to in the subrogation actions, but no trial dates have been set in those actions.
The Company intends to vigorously defend against the litigation if a definitive settlement is ultimately not achieved. There is no assurance that the Company will be successful in the defense of the litigation or that insurance will be available or adequate to fund any potential settlements, judgments, or costs associated with the litigation. If additional liabilities were to be incurred, the loss could be material to the Company’s results of operations, financial position and cash flows and could result in violations of the financial covenants in the Company’s debt agreements. If any such losses were to be sufficiently high, the Company may not have liquidity or the ability to access liquidity at levels necessary to satisfy such losses. However, any possible loss in excess of the amount recorded cannot reasonably be estimated at this time.
Securities class action and shareholder lawsuits. On August 24, 2023, a putative securities class action captioned Bhangal v. Hawaiian Electric Industries, Inc., et al., No.: 3:23-cv-04332-JSC (the Securities Action) was filed in the United States District Court for the Northern District of California. The lawsuit alleges violations of the Securities Exchange Act of 1934 (the Exchange Act) and Rule 10b-5 promulgated thereunder against HEI and certain of its current and former officers (collectively, Defendants), and Section 20(a) of the Exchange Act against certain of HEI’s current and former officers. Plaintiff broadly alleges that Defendants made materially false and misleading statements or omissions regarding HEI’s wildfire prevention and safety protocols and related matters. Plaintiff seeks unspecified monetary damages. On December 7, 2023, the court appointed Daniel Warren as lead plaintiff and Pomerantz LLP as lead plaintiff’s counsel. On March 8, 2024, the lead plaintiff filed an amended complaint. The Company has filed a motion to dismiss that complaint and intends to vigorously defend against this action. There is no assurance that the Company will be successful in the defense of the litigation or that insurance will be available or adequate to fund any potential settlement or judgment or the litigation costs of the action. The Company does not believe that a loss is probable and any possible loss or range of loss is not reasonably estimable.
On September 11, 2023, a putative shareholder derivative action captioned Rice v. Connors, et al., No. 1CCV-23-0001181 was filed in the Circuit Court of the First Circuit, State of Hawaii. On December 6, 2023, the case was removed to the United States District Court for the District of Hawaii and captioned Rice v. Connors, et al., No. 1:23-cv-00577-JAO-BMK. On March 14, 2024, the United States District Court remanded the case to the Circuit Court of the First Circuit, State of Hawaii. This action is purportedly brought by a shareholder on behalf of nominal defendants HEI and Hawaiian Electric against certain current and former officers and directors of HEI and Hawaiian Electric. Plaintiff asserts Hawaii state law breach of fiduciary duty, abuse of control, corporate waste, unjust enrichment, and aiding and abetting breach of fiduciary duty claims allegedly arising in connection with the Maui windstorm and wildfires that occurred in August 2023 and certain of the Company’s prior
15

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
public disclosures. Plaintiff seeks, on behalf of HEI and Hawaiian Electric, compensatory and punitive damages, restitution, disgorgement, and equitable relief in the form of changes to corporate governance, policies and culture. HEI has moved to stay the proceeding pending resolution of the tort-related legal claims and the Securities Action. While the Company has obligations to indemnify and/or advance the defendants’ legal fees and costs in connection with this lawsuit, any monetary recovery in the derivative litigation should accrue to the Company. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
Three putative shareholder derivative actions were filed in the United States District Court for the Northern District of California between December 26, 2023 and February 8, 2024, including:
Kallaus v. Johns, et al., No. 3:23-cv-06627 (the Kallaus Action), Cole v. Johns, et al., No. 3:24-cv-00598 (the Cole Action), and Tai v. Seu, et al., No. 3:24-cv-01198 (the Tai Action). On March 19, 2024, upon stipulation by the parties, the court consolidated the Kallaus Action, the Cole Action, and the Tai Action under the caption In Re Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. Derivative Litigation, No. 3:23-cv-06627 (the Consolidated Derivative Actions). On June 19, 2024, Plaintiffs filed a consolidated amended complaint. The Consolidated Derivative Actions are purportedly brought by shareholders of HEI on behalf of nominal defendants HEI and Hawaiian Electric against certain current and former officers and directors of HEI and Hawaiian Electric. Plaintiffs purport to assert both Hawaii state law and federal securities law claims. Plaintiffs assert state law breach of fiduciary duty, corporate waste, unjust enrichment, gross mismanagement, and abuse of control claims purportedly arising in connection with the Maui windstorm and wildfires that occurred in August 2023 and certain public disclosures. Plaintiffs also assert claims under Section 10(b) of the Exchange Act, and Rule 10b-5 promulgated thereunder, and generally allege that the Company and certain of its current and former officers made materially false and misleading statements or omissions regarding the Company’s wildfire prevention and safety protocols and related matters. Plaintiffs seek, on behalf of HEI and Hawaiian Electric, unspecified monetary and punitive damages, disgorgement, and other relief. HEI moved to stay the Consolidated Derivative Actions pending resolution of the tort-related legal claims and the Securities Action, and also moved to dismiss the consolidated amended complaint for failing to adequately allege that the Board’s refusal of the plaintiffs’ demands was wrongful. While the Company has certain obligations to indemnify and/or advance the defendants’ legal fees and costs in connection with this lawsuit, any monetary recovery in the Consolidated Derivative Actions should accrue to the Company. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
Two putative shareholder derivative actions were filed in the United States District Court for the District of Hawaii between April 8, 2024 and June 8, 2024, including:
Assad v. Seu, et al., No. 1:24-cv-00164 (the Assad Action), and Faris v. Seu, et al., No. 1:24-cv-00247 (the Faris Action). On July 3, 2024, upon stipulation by the parties, the court consolidated the Assad Action and Faris Action under the caption In Re Hawaiian Electric Industries, Inc., Stockholder Derivative Litigation, No. 1:24-cv-00164 (the Hawaii Federal Derivative Actions). Both actions are purportedly brought by shareholders on behalf of nominal defendant HEI and against certain current and former officers and directors of HEI and Hawaiian Electric. Plaintiffs purport to assert Hawaii state law claims for breach of fiduciary duty, corporate waste, and unjust enrichment allegedly arising in connection with the Maui windstorm and wildfires that occurred in August 2023 and certain public disclosures. Plaintiffs generally allege that the Company and certain of its current and former officers made materially false and misleading statements or omissions regarding the Company’s wildfire prevention and safety protocols and related matters. Plaintiffs seek, on behalf of HEI, compensatory damages, restitution, disgorgement, injunctive relief, and equitable relief, including in the form of changes to HEI’s corporate governance policies and procedures. On July 30, 2024, upon HEI’s motion, the court stayed the Hawaii Federal Derivative Actions pending resolution of the motion to dismiss the Securities Action and the motions to stay and dismiss the Consolidated Derivative Actions. While the Company has obligations to indemnify and/or advance the defendants’ legal fees and costs in connection with this lawsuit, any monetary recovery in the derivative litigation should accrue to the Company. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
Maui windstorm and wildfires costs. Legal costs in connection with the litigation and loss contingencies are expensed as incurred. The Company has $165 million of excess liability insurance and $25 million of miscellaneous professional liability insurance for third party claims, including claims related to wildfires, with a retention of $0.3 million and $1.0 million, respectively, and $145 million directors and officers liability insurance to cover claims related to the shareholder and derivative lawsuits, with a retention of $1.0 million. As of June 30, 2024, the Company’s and Utilities’ insurance receivable totaled $34.8 million and $29.6 million, respectively, under the policies. As of June 30, 2024, HEI and its subsidiaries have approximately $41 million, $25 million and $133 million of insurance coverage remaining under the excess liability, miscellaneous professional liability and directors and officers liability policies, respectively.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
See table below for the incremental expenses related to the Maui windstorm and wildfires.
Year ended December 31, 2023Three months ended June 30, 2024Six months ended June 30, 2024
(in thousands)
Electric utility
HEI Consolidated
Electric utility
HEI Consolidated
Electric utility
HEI Consolidated
Maui windstorm and wildfires related expenses:
Legal expenses$24,737 $34,876 $17,613 $25,000 $28,348 $40,027 
Wildfire tort-related claims
75,000 75,000 1,712,000 1,712,000 1,712,000 1,712,000 
Other expense
15,071 28,507 9,262 11,295 23,094 26,386 
Total Maui windstorm and wildfires related expenses114,808 138,383 1,738,875 1,748,295 1,763,442 1,778,413 
Insurance recoveries
(98,613)(104,580)(16,379)(18,875)(26,348)(31,452)
Deferral treatment approved by the PUC1
(14,692)(14,692)(7,656)(7,656)(15,554)(15,554)
Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment$1,503 $19,111 $1,714,840 $1,721,764 $1,721,540 $1,731,407 
1    Related to the PUC’s order, received on December 27, 2023, approving deferred accounting treatment for the Utilities’ incremental non-labor expenses related to the August 2023 Maui windstorm and wildfires. Amounts were reclassified to a regulatory asset.
On May 4, 2024, HEI and the Utilities reached an agreement to settle indemnification claims asserted by the State of Hawaii without any admission of fault or responsibility. Under the terms of the agreement, HEI and the Utilities agreed to contribute up to $18.4 million through the end of 2024 related to the costs of the professional advisors engaged by the State of Hawaii to advise on a variety of matters related to the Maui windstorm and wildfires. Under certain circumstances, HEI and the Utilities have the unilateral right to terminate the agreement and stop paying the costs for future periods. As of June 30, 2024, a total of $10.6 million of such costs were accrued and reflected in Maui windstorm and wildfires related expenses-Other expense in the table above. HEI and the Utilities are seeking insurance recoveries for such costs; however, the timing and amount of any insurance recoveries are not determinable at this time.
In addition, the Utilities incurred $2.1 million and $7.7 million of total capital costs related to the Maui windstorm and wildfires for the three and six months ended June 30, 2024, respectively.
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Note 3 · Segment financial information
(in thousands) Electric utilityBankOtherTotal
Three months ended June 30, 2024    
Revenues$792,331 $101,943 $3,086 $897,360 
Income (loss) before income taxes$(1,658,653)$(57,106)$(26,521)$(1,742,280)
Income taxes (benefit)(429,758)(11,319)(6,192)(447,269)
Net income (loss)(1,228,895)(45,787)(20,329)(1,295,011)
Preferred stock dividends of subsidiaries499 — (26)473 
Net income (loss) for common stock$(1,229,394)$(45,787)$(20,303)$(1,295,484)
Six months ended June 30, 2024    
Revenues$1,580,909 $207,087 $6,522 $1,794,518 
Income (loss) before income taxes$(1,607,753)$(31,293)$(48,965)$(1,688,011)
Income taxes (benefit)(418,578)(6,440)(10,577)(435,595)
Net income (loss)(1,189,175)(24,853)(38,388)(1,252,416)
Preferred stock dividends of subsidiaries998 — (52)946 
Net income (loss) for common stock$(1,190,173)$(24,853)$(38,336)$(1,253,362)
Total assets (at June 30, 2024)
$7,398,898 $9,280,805 $375,711 $17,055,414 
Three months ended June 30, 2023    
Revenues$794,191 $96,885 $4,609 $895,685 
Income (loss) before income taxes$58,868 $25,055 $(14,556)$69,367 
Income taxes (benefit)13,070 4,851 (3,637)14,284 
Net income (loss)45,798 20,204 (10,919)55,083 
Preferred stock dividends of subsidiaries499 — (26)473 
Net income (loss) for common stock $45,299 $20,204 $(10,893)$54,610 
Six months ended June 30, 2023    
Revenues$1,624,552 $190,742 $8,628 $1,823,922 
Income (loss) before income taxes$119,976 $48,762 $(29,067)$139,671 
Income taxes (benefit)26,670 9,996 (7,272)29,394 
Net income (loss)93,306 38,766 (21,795)110,277 
Preferred stock dividends of subsidiaries998 — (52)946 
Net income (loss) for common stock $92,308 $38,766 $(21,743)$109,331 
Total assets (at December 31, 2023)
$7,283,554 $9,673,192 $287,075 $17,243,821 
 
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.
Sales from Hamakua Energy, LLC (Hamakua Energy) to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation.
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Note 4 · Electric utility segment
Unconsolidated variable interest entities.
Power purchase agreements.  As of June 30, 2024, 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. Excluding the potential liabilities from the Maui windstorm and wildfires, 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 (viii) 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.
August 2023 Maui windstorm and wildfires. See Note 2.
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 the termination of the original PPA. Following the termination, Hu Honua filed a lawsuit in the U.S. District Court for the District of Hawaii. The parties reached a settlement that was conditioned on the PUC’s timely, non-appealable final approval of an amended and restated PPA dated May 9, 2017. On May 23, 2022, following a contested case hearing, 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
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order denying the amended and restated PPA. 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. On June 7, 2023, Hu Honua filed a status report with the U.S. District Court for the District of Hawaii, stating, among other things, that because settlement of the underlying federal lawsuit was contingent on timely, non-appealable, final approval of the amended and restated PPA by the PUC, that the Hawaii Supreme Court’s opinion made fulfillment of the condition impossible, and therefore the settlement agreement between the Hawaiian Electric defendants (HEI, Hawaiian Electric, and Hawaii Electric Light) and Hu Honua is null and void and of no further effect. On November 16, 2023, Hu Honua filed its Motion for Leave to File Third Amended and Supplemental Complaint and for Permissive Joinder with the U.S. District Court for the District of Hawaii, asking the court to grant it leave to file a Third Amended and Supplemental Complaint, which would amend its claims and add three new proposed defendants. The hearing on this motion took place on February 14, 2024. The court issued a decision and order on the motion on April 2, 2024, which was consistent with Hawaii Electric Light's position, only allowing amendments that were agreed to and not allowing Hu Honua to add new claims or parties, effectively leaving Hu Honua with its previously-pled breach of contract and antitrust claims. Hu Honua filed its objection to the order on April 16, 2024 and the Hawaiian Electric defendants filed their response to the objection on April 30, 2024. A hearing on Hu Honua’s objection took place on July 30, 2024 and the parties are awaiting a court order to be issued.
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 (BESS) 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.
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 Environmental Protection Agency (EPA) has since identified environmental impacts in the subsurface soil at the Site. In cooperation with the State of Hawaii Department of Health 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 $2.5 million as of June 30, 2024, 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.
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 June 30, 2024, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $9.5 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.
Kapolei pipeline. James Campbell Company (JCC) through its wholly owned subsidiary, Aina Nui Corporation discovered petroleum contamination in ground water during construction of a project in Kapolei in late 2022 and incurred approximately $0.8 million in remediation costs. JCC made a joint demand for these costs in June 2023 to the two companies, including Hawaiian Electric, that have pipelines in the area of the contamination. This demand was updated in April 2024 to
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$1.4 million to incorporate additional costs. It has not been determined whether the nature of the contamination is consistent with what was in the Utilities’ pipelines or is wholly or partially the responsibility of the other pipeline owner and whether the costs were properly incurred. At this time, the parties are engaging in settlement discussions and the Utilities have determined that the estimated probable loss is not material.
Endangered Species Act. The Utilities received a 60-day notice under the federal Endangered Species Act, from Earthjustice on behalf of the American Bird Conservancy and Conservation Council for Hawaii in early February 2024. The 60-day notice is the pre-cursor to a citizen’s suit under the Endangered Species Act. The notice alleges that the Utilities are out of compliance with the Act due to alleged impacts on endangered seabirds caused by the Utilities’ powerlines, street lights and facility lights on Maui and Lanai. The Utilities are already in the process of drafting a Habitat Conservation Plan and will be applying for associated state and federal permits. The notice asserts that the scope of the plan should be broader and that additional interim measures are required while the plan and permits are pending. At this time, the parties are engaging in settlement discussions and the Utilities are unable to determine the ultimate outcome or the amount of any possible loss.
Commitments.
Purchase commitments. In the ordinary course of business, the Utilities enter into various agreements to purchase power and lease fuel barge. As of December 31, 2023, the Utilities estimated future purchase obligations of $1.7 billion. See Note 4 of the Notes to the Consolidated Financial Statements in Item 8 of the 2023 Form 10-K.
On March 28, 2024, AES West Oahu Solar project reached commercial operations, which has a capacity of 12.5 MW with 50 MWh batteries and total annual payment of $3.2 million. On May 31, 2024, AES Kuihelani Solar project on Maui reached commercial operations, which has a capacity of 60 MW with 240 MWh batteries and total annual payment of $13.2 million. On June 7, 2024, the Kupono Solar project on Oahu reached commercial operations, which has a capacity of 42 MW with 168 MWh batteries and total annual payment of $11.5 million. For the six months ended June 30, 2024, $107.4 million of finance lease liabilities with corresponding right-of-use assets was recorded for the battery portion of the PPAs and a total of three Stage 1 and Stage 2 renewable projects provide the Utilities of 114.5 MW, with 458 MWh batteries.
Purchases from all IPPs were as follows:
 Three months ended June 30Six months ended June 30
(in millions)2024202320242023
Kalaeloa$79 $67 $145 $134 
HPOWER16 16 33 34 
Puna Geothermal Venture14 9 27 17 
Hamakua Energy5 19 16 39 
Kapolei Energy Storage
6 — 12 — 
Wind IPPs37 33 67 57 
Solar IPPs21 22 36 36 
Other IPPs 1
3 2 5 4 
Total IPPs$181 $168 $341 $321 
1 Includes hydro power and other PPAs.
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.
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 was placed in service on October 25, 2023. Maui Electric petitioned and received from
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the State of Hawaii Department of Health a one-year extension to the mandatory retirement of Kahului Power Plant and there is now flexibility to operate the units until the end of 2028. 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 June 30, 2024, $25.5 million has been incurred for the project.
Waena Battery Energy Storage System Project. In September 2020, Maui Electric filed a PUC application to purchase and install a 40 MW BESS at its Waena Site in Central Maui. In December 2023, the PUC approved Maui Electric’s request to commit funds estimated at $82.1 million, for the purchase and installation of the project, and to recover costs for the project under EPRM. Project costs incurred as of June 30, 2024 amount to $0.6 million.
Climate Adaptation Transmission and Distribution Resilience Program. The Utilities maintain that improving resiliency of the electric grid is an urgent matter and recognizes that climate change is making Hawaii increasingly vulnerable to sever weather events. On January 31, 2024, the PUC approved the Utilities’ request to commit an estimated $189.7 million in funds for the Climate Adaptation Transmission and Distribution Resilience Program, over a project period of five years. The project is to focus on, among other things, system hardening in wildfire risk areas to prevent ignition and to enable quicker response, video camera and weather monitors in wildfire risk areas and to add situational awareness, and strengthening transmission lines.
The project costs to be recovered through EPRM is subject to a cap of $95 million and any amount in excess will be subject to the PUC’s further review. On August 7, 2024, the Utilities received a notification from the U.S. Department of Energy that its application for $95 million in federal funds under the Infrastructure Investment and Jobs Act (IIJA) has been awarded. Project costs incurred as of June 30, 2024 amount to $1.8 million.
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 continued as previously implemented (e.g., the Energy Cost Recovery Clause, Purchased Power Adjustment 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 PIMs, a SSM, and extended the timeframe for an existing PIM. Specifically, the PUC approved (1) a (penalty-only) generation-caused interruption reliability PIM, (2) a (penalty/reward) interconnection requirements study PIM, (3) a (reward-only) Collective Shared Savings Mechanism (CSSM), and (4) a modification and extension of the existing Interim Grid Services PIM (reward-only). 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
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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 Long-Term Grid Services PIM, modification/evaluation of existing PIMs, and comprehensive PBR Framework review priority topics.
In accordance with the June 2022 D&O, the Utilities filed their FIP on September 30, 2022, Long-Term Grid Services PIM proposal on July 3, 2023, and FF Retirement Report on April 12, 2024.
On October 16, 2023, the Utilities filed a request for limited suspension of the Transmission and Distribution (T&D) System Average Interruption Duration Index (SAIDI) PIM, the T&D System Average Interruption Frequency Index (SAIFI) PIM, and the target heat rate provision of Maui Electric Maui Division’s Energy Cost Recovery Clause (ECRC) tariff starting from August 8, 2023. On December 28, 2023, the PUC issued an order granting a temporary suspension of Maui Electric’s T&D SAIDI and SAIFI PIMs and Maui Electric Maui Division’s target heat rate provision from August 8, 2023 through June 30, 2024, which the tariffs became effective on January 1, 2024.
On November 3, 2023, the Utilities, Ulupono Initiative LLC, and the County of Hawaii filed a stipulation on proposed modifications to the RPS-A, Call Center, AMI Utilization, and interconnection requirements study PIMs. On June 24, 2024, the PUC issued an order (1) approving modifications to the interconnection requirements study PIM to expand its application to firm generation projects effective August 1, 2024, (2) approving a consolidated target for the Call Center PIM and modifying the target performance based on the average of the Utilities’ performance, weighted by the number of calls for the last eight quarters as of December 31, 2023, to be effective August 1, 2024, (3) denying the proposed modifications to the RPS-A PIM and clarifying that it will continue to operate according to its existing tariff language; and (4) denying the proposed modifications to the AMI Utilization PIM and declining to extend the PIM beyond its scheduled sunset date of December 31, 2023.
On December 26, 2023, the PUC issued an order (1) confirming that the Interim Grid Services PIM will sunset on December 31, 2023, (2) extending the Interconnection Approval PIM through December 31, 2024, and (3) determining that it will continue examination of the Long-Term Grid Services PIM into 2024 as part of a broader examination that addresses barriers to the utilization of DERs to meet grid needs.
On April 1, 2024, the Utilities filed a request for partial temporary suspension and modification of the T&D SAIDI and T&D SAIFI PIMs to specifically suspend the T&D SAIDI and T&D SAIFI PIMs for wildfire risk circuits from January 1, 2024 to December 31, 2025. The Utilities also proposed that circuits not identified as wildfire risk circuits would continue to be subject to the existing PIMs on a prorated basis. On April 26, 2024, the PUC issued a procedural schedule to govern review of the request, a D&O is requested by December 16, 2024.
On June 19, 2024, the PUC issued an order (June 2024 order) providing preliminary guidance regarding the comprehensive evaluation of the PBR Framework that will commence in the fourth year of the PBR Framework’s first MRP (PBR Framework Review). The PUC has developed a high-level review structure and timeline for the PBR Framework Review and divided the remainder of the first MRP into three phases: (i) the evaluation of the current PBR Framework, (ii) the examination of proposal for modifications to the PBR Framework, and (iii) the implementation of modifications prior to commencing the second MRP. At the PBR Working Group meeting held on June 26, 2024, the PUC staff solicited the parties’ feedback on the scope of the PBR Framework Review and discussed other considerations, including rebasing target revenues. On July 19, 2024, as requested by the PUC staff, the parties filed written feedback to materials presented and discussed at the June Working Group meeting and in the June 2024 order. The PUC intends to issue a detailed process order initiating the PBR Framework Review.
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 ARA mechanism replaced the previous revenue adjustment mechanism (RAM). 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 to the extent such adjustments are not included in base rate unless modified with PUC approval. 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 deadband 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
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the deadband in either direction, and a 90/10 sharing for any further difference. A reopening or review of the PBR terms may 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.
On August 31, 2023, the PUC issued an order temporarily suspending the ESM until further notice. The intent of the order is to address the unintended consequence of customers potentially bearing the costs associated with the Maui windstorm and wildfires through the operation of the ESM without prior PUC review.
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 June 30, 2024, the Utilities annualized MPIR and EPRM revenue amounts totaled $33.1 million, including revenue taxes, for the Schofield Generating Station ($16.5 million), West Loch PV project ($3.3 million), Grid Modernization Strategy (GMS) Phase 1 project ($11.2 million for all three utilities), Waiawa UFLS project ($0.1 million) and Waena Switchyard/Synchronous project ($2.0 million) that included the 2023 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 2023 MPIR amounts for the Schofield Generating Station, West Loch PV, GMS Phase 1, and Waiawa UFLS projects effective June 1, 2023 and for the Waena Switchyard project effective January 1, 2024 through the RBA rate adjustment.
As of June 30, 2024, the PUC approved four EPRM applications for projects totaling $218.5 million to the extent the project costs are not included in rates. Currently, the Utilities are seeking EPRM recovery for four additional projects with total project costs up to $712.9 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 (Pilot Process). 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 will be considered approved as submitted. The PUC may modify the pilot as originally proposed, and the Utilities will 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 March 11, 2024, the Utilities filed their annual Pilot Update report covering pilot projects that were active during 2023, including reporting on pilot projects that were initiated prior to the commencement of the Pilot Process. The Pilot Update reported on approximately $3.0 million of 2023 recorded pilot project costs including revenue taxes for the Utilities. The 2023 recorded pilot project costs were included in the Utilities’ proposed adjustments to target revenue in the 2024 spring revenue report filed on March 28, 2024.
Performance incentive mechanisms. The following PIMs and SSMs were approved by the PUC and are applicable for the 2023 evaluation period and through June 30, 2024.
•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.
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•Service Reliability Performance measured by Transmission and Distribution-caused SAIDI and SAIFI (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 $6.4 million for calendar year 2023 - for both indices in total for the three utilities). On December 28, 2023, the PUC issued an order granting a temporary suspension of Maui Electric’s T&D SAIDI and SAIFI PIMs from August 8, 2023 through June 30, 2024. For the 2023 evaluation period, the Utilities incurred $3.7 million in penalties.
•Call Center Performance measured by the percentage of calls answered within 30 seconds. The previous target performance was 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. On June 24, 2024, the PUC issued an order approving a consolidated target for the Call Center PIM and modifying the target performance based on the average of the Utilities’ performance, weighted by the number of calls for the last eight quarters as of December 31, 2023, to be effective August 1, 2024. 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 prorated in proportion to the actual amount of energy utilized, which is estimated to occur from 2023 to 2025. Based on the in-service date of two projects, the Utilities earned the second portion of the incentive of approximately $0.1 million (for Hawaiian Electric) in rewards in both 2023 and the first quarter of 2024. In the second quarter of 2024, the Utilities accrued the second portion of the incentive of approximately $0.1 million (for Hawaii Electric Light).
•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. In 2023, the Utilities earned $0.4 million in rewards.
•Interim Grid Services - A PIM that provides financial rewards on a $/kW basis for the acquisition of eligible grid services. The June 2022 D&O modified and extended the Interim Grid Services PIM through December 31, 2023 and 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 2023, the Utilities earned $1.1 million in rewards. The Interim Grid Services PIM sunset on December 31, 2023. The PUC intends to replace the Interim Grid Services PIM with a Long-Term PIM that incents DER grid service utilization. Review and development of the Long-Term DER Utilization PIM continues in 2024.
•Interconnection Approval PIM that provides financial rewards and penalties for interconnection times for DER systems <100 kW in size. The Interconnection Approval PIM extends through December 31, 2024. The Utilities can earn a total annual maximum reward of $3.0 million or a total annual maximum penalty of $0.9 million. In 2023, 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 $0.01 million in rewards for the program period ending June 30, 2023.
•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 Advanced Metering Infrastructure Utilization PIM sunset on December 31, 2023.
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•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 interconnection requirements study 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 2023 evaluation period, the Utilities earned $0.9 million ($1.2 million for Hawaiian Electric, $(0.6) million for Hawaii Electric Light and $0.3 million for Maui Electric) in rewards net of penalties. The net rewards related to 2023 and for the period through March 2024 were reflected in the 2024 PIMs annual report and 2024 spring revenue report filings. In the second quarter of 2024, the Utilities accrued an additional $0.1 million reward for the Phase 1 RFP PIM (for Hawaii Electric Light), which will be reflected in the upcoming 2024 fall revenue report filing.
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’ 2024 spring revenue report filed on March 28, 2024 was approved by the PUC on May 16, 2024. The filing reflected ARA revenues for recovery of the COVID-19 related deferred costs through the Z-factor and the accelerated return of the Enterprise Resource Planning system benefits savings to Hawaii Electric Light and Maui Electric customers as part of the customer dividend, as follows. (See discussion under “Regulatory assets and liabilities” below).
(in millions)Hawaiian ElectricHawaii Electric LightMaui ElectricTotal
Recovery of COVID-19 related costs$2.2 $0.5 $0.5 $3.2 
Return of ERP benefit liability— (1.3)(1.9)(3.2)
Net 2024 ARA revenues$2.2 $(0.8)$(1.4)$— 
The net incremental amounts between the 2023 fall and 2024 spring revenue reports are shown in the following table. The amounts are to be collected (refunded) from June 1, 2024 through May 31, 2025 under the RBA rate tariffs, which were included in the 2024 spring revenue report filing.
(in millions)Hawaiian ElectricHawaii Electric LightMaui ElectricTotal
Incremental ARA revenues
$2.2 $(0.8)$(1.4)$— 
Incremental PIMs (net)(1.3)(1.1)(0.2)(2.6)
Incremental MPIR/EPRM revenue adjustment3.0 0.7 1.2 4.9
Incremental Pilot Process cost recovery1.9 0.3 0.5 2.7
Net incremental amount to be collected (refunded) under the RBA rate tariffs
$5.8 $(0.9)$0.1 $5.0 

Regulatory assets and liabilities.
Regulatory asset related to retirement of Honolulu generating units 8 and 9. On December 22, 2023, the PUC issued a decision and order approving the Utilities’ request to establish a regulatory asset for the remaining net book value of the fossil fuel generating units for both Honolulu units 8 and 9 assets that retired on December 31, 2023, and amortize the regulatory asset over approximately nine years. The PUC also ruled that the Utilities may seek to include the regulatory asset in rate base and seek to recover the amortization expense and a return on the unamortized balance of the regulatory asset in the next rate
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case or rate re-setting proceeding. As of June 30, 2024, the Utilities have recorded $28.3 million in regulatory assets for the remaining net book value of Honolulu generating units 8 and 9.
Regulatory assets for Maui windstorm and wildfires related costs. On December 27, 2023, the PUC issued an order authorizing deferred accounting treatment for the Utilities’ incremental non-labor expenses under specific cost categories related to the August 2023 Maui windstorm and wildfires. The deferred accounting treatment applies to certain non-labor expenses incurred from August 8, 2023 through December 31, 2024 that are not already a part of base rates. The approval pertains to deferred cost treatment. The requests for cost recovery of deferred costs will be the subject of a separate application at which time the PUC will evaluate whether such costs were prudently incurred and reasonable and determine the extent to which such costs will be eligible for recovery, and the period over which recovery will occur. If the PUC denies recovery of any deferred costs, such costs would be charged to expense in the period that those costs are no longer considered probable of recovery.
As of June 30, 2024, the Utilities have recorded $30.2 million in regulatory assets for the incremental costs incurred related to the Maui windstorm and wildfires event.
Regulatory liabilities for Enterprise Resource Planning/Enterprise Asset Management (ERP/EAM). 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 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 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. On December 29, 2023, the PUC approved the Utilities’ proposal to accelerate flow-through of the ERP benefits savings currently tracked in regulatory liability accounts to Hawaii Electric Light and Maui Electric customers as part of the customer dividend in the ARA, to mitigate the impact of the Utilities’ recovery of the COVID-19 related costs on customers. See “Regulatory assets for COVID-19 related costs” section below.
As of June 30, 2024, the Utilities’ regulatory liability was $13.1 million ($1.9 million for Hawaiian Electric, $4.5 million for Hawaii Electric Light and $6.7 million for Maui Electric) for the O&M expense savings that are being amortized or to be included in future rates. 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 13, 2024 for the period January 1 through December 31, 2023.
Regulatory assets for COVID-19 related costs. On December 29, 2023, the PUC issued a decision and order (December 2023 D&O) approving the Utilities’ request to recover the COVID-19 related deferred costs up to $8.8 million evenly over a three-year recovery period from 2024 through 2026 through the Z-factor in the ARA. Following the Utilities’ motion for clarification or in the alternative partial reconsideration of the December 2023 D&O, on February 27, 2024, the PUC issued an order clarifying the December 2023 D&O and approving, among other things, the Utilities’ requests to base the recovery on the recorded balances as of December 31, 2023 and to modify the recovery period to begin June 1, 2024 and end May 31, 2027. As of June 30, 2024, the Utilities have recorded $8.3 million in regulatory assets for deferral of COVID-19 related costs.
Regulatory assets for suspension of disconnections related costs. Based on the circumstances related to the Maui windstorm and wildfires, on August 31, 2023 and subsequently on October 13, 2023, the PUC issued orders directing all regulated utilities located on, or providing utility service on Maui, including the Utilities, among other things, (i) to suspend disconnections of services and associated disconnection fees beginning from August 8, 2023, through the end of the emergency relief period established by the Governor’s Emergency Proclamations related to the Maui windstorm and wildfires, which currently continues through August 31, 2024 (Suspension Period); (ii) to suspend any and all rules and provisions of individual utility tariffs that prevent or condition re-connection of disconnected customers during the Suspension Period; (iii) not to charge customers interest on past due payments or impose any late payment fees through the Suspension Period; (iv) to establish regulatory assets to record costs directly related to the suspension of disconnections, and to record receipt of governmental aid
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and donation-based aid, loans or grants, and/or all other assistance measures, and any cost savings realized; and (v) to file a notice with the PUC regarding any upcoming application or other request pursuant to HRS Sections 269-16.3, -17, -17.5, -18, -19, or -19.5 and/or regarding any significant financial change to the Maui utility, at least 60 days prior to filing such application or other request with the PUC. The orders also discourage the filing of emergency or general rate increases in response to the emergency situation. In future proceedings, the PUC will assess the utility’s request for recovery of these regulatory assets including whether it is reasonable and necessary, the appropriate period of recovery for the approved amount of regulatory assets, any amount of carrying costs thereon, any savings directly attributable to suspension of disconnects, and other related matters. As of June 30, 2024, the Utilities have recorded $1.7 million in regulatory assets for the incremental costs incurred due to the suspension of disconnections.
Condensed consolidating financial information. Condensed consolidating financial information for Hawaiian Electric and its subsidiaries are presented for the three and six months ended June 30, 2024 and 2023, and as of June 30, 2024 and December 31, 2023.
On March 21, 2024, Hawaiian Electric formed HE AR INTER LLC, which was established to pursue financing through a secured asset-based (accounts receivable) credit facility. As of June 30, 2024, there was no activity.
Hawaiian Electric unconditionally guarantees Hawaii Electric Light’s and Maui Electric’s obligations (a) to the State of Hawaii for the repayment of principal and interest on Special Purpose Revenue Bonds issued for the benefit of Hawaii Electric Light and Maui Electric, and (b) under their respective private placement note agreements and the Hawaii Electric Light notes and Maui Electric notes issued thereunder. Hawaiian Electric is also obligated, after the satisfaction of its obligations on its own preferred stock, to make dividend, redemption and liquidation payments on Hawaii Electric Light’s and Maui Electric’s preferred stock if the respective subsidiary is unable to make such payments.
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Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Three months ended June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustments
Hawaiian Electric
Consolidated
Revenues$564,628 117,663 110,040 — — $792,331 
Expenses
Fuel oil187,386 28,941 42,325 — — 258,652 
Purchased power137,139 31,068 13,121 — — 181,328 
Other operation and maintenance93,717 24,544 29,300 — — 147,561 
Wildfire tort-related claims (Note 2)
1,369,600 171,200 171,200 — — 1,712,000 
Depreciation42,003 10,964 9,845 — — 62,812 
Taxes, other than income taxes53,214 10,943 10,261 — — 74,418 
   Total expenses1,883,059 277,660 276,052 — — 2,436,771 
Operating loss
(1,318,431)(159,997)(166,012)— — (1,644,440)
Allowance for equity funds used during construction2,578 288 470 — — 3,336 
Equity in earnings of subsidiaries(246,099)— — — 246,099 — 
Retirement defined benefits credit (expense)—other than service costs928 168 (24)— — 1,072 
Interest expense and other charges, net(15,717)(2,974)(4,559)— 1,833 (21,417)
Allowance for borrowed funds used during construction1,034 85 225 — — 1,344 
Interest Income2,972 241 72 — (1,833)1,452 
Loss before income taxes
(1,572,735)(162,189)(169,828)— 246,099 (1,658,653)
Income tax benefit
(343,611)(42,027)(44,120)— — (429,758)
Net loss
(1,229,124)(120,162)(125,708)— 246,099 (1,228,895)
Preferred stock dividends of subsidiaries— 133 96 — — 229 
Net loss attributable to Hawaiian Electric
(1,229,124)(120,295)(125,804)— 246,099 (1,229,124)
Preferred stock dividends of Hawaiian Electric270 — — — — 270 
Net loss for common stock
$(1,229,394)(120,295)(125,804)— 246,099 $(1,229,394)


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Three months ended June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net loss for common stock
$(1,229,394)(120,295)(125,804)— 246,099 $(1,229,394)
Other comprehensive loss, net of taxes:
      
Retirement benefit plans:      
Adjustment for amortization of net gains recognized during the period in net periodic benefit cost, net of taxes
(505)(39)(57)— 96 (505)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes459 35 50 — (85)459 
Other comprehensive loss, net of taxes
(46)(4)(7)— 11 (46)
Comprehensive loss attributable to common shareholder
$(1,229,440)(120,299)(125,811)— 246,110 $(1,229,440)

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Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Three months ended June 30, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiary
Consolidating adjustments
Hawaiian Electric
Consolidated
Revenues$570,689 112,074 111,428 — — $794,191 
Expenses
Fuel oil213,471 20,471 46,215 — — 280,157 
Purchased power119,460 37,246 11,728 — — 168,434 
Other operation and maintenance88,967 21,666 25,727 — — 136,360 
Depreciation40,800 10,636 9,253 — — 60,689 
Taxes, other than income taxes54,046 10,389 10,491 — — 74,926 
   Total expenses516,744 100,408 103,414 — — 720,566 
Operating income53,945 11,666 8,014 — — 73,625 
Allowance for equity funds used during construction2,959 354 459 — — 3,772 
Equity in earnings of subsidiaries11,414 — — — (11,414)— 
Retirement defined benefits credit (expense)—other than service costs905 168 (25)— — 1,048 
Interest expense and other charges, net(14,742)(2,975)(3,155)— — (20,872)
Allowance for borrowed funds used during construction1,030 113 152 — — 1,295 
Income before income taxes55,511 9,326 5,445 — (11,414)58,868 
Income taxes9,942 2,118 1,010 — — 13,070 
Net income45,569 7,208 4,435 — (11,414)45,798 
Preferred stock dividends of subsidiaries— 133 96 — — 229 
Net income attributable to Hawaiian Electric
45,569 7,075 4,339 — (11,414)45,569 
Preferred stock dividends of Hawaiian Electric270 — — — — 270 
Net income for common stock$45,299 7,075 4,339 — (11,414)$45,299 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Three months ended June 30, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other
subsidiary
Consolidating
adjustments		Hawaiian Electric
Consolidated
Net income for common stock$45,299 7,075 4,339 — (11,414)$45,299 
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)(55)(66)— 121 (470)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes426 53 57 — (110)426 
Other comprehensive loss, net of taxes
(44)(2)(9)— 11 (44)
Comprehensive income attributable to common shareholder
$45,255 7,073 4,330 — (11,403)$45,255 

30

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Six months ended June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustmentsHawaiian Electric
Consolidated
Revenues$1,128,808 235,272 216,829 — — $1,580,909 
Expenses
Fuel oil397,585 60,126 85,237 — — 542,948 
Purchased power254,657 63,124 23,364 — — 341,145 
Other operation and maintenance184,601 49,134 57,716 — — 291,451 
Wildfire tort-related claims (Note 2)
1,369,600 171,200 171,200 — — 1,712,000 
Depreciation84,007 21,928 19,689 — — 125,624 
Taxes, other than income taxes106,623 21,900 20,303 — — 148,826 
   Total expenses2,397,073 387,412 377,509 — — 3,161,994 
Operating loss
(1,268,265)(152,140)(160,680)— — (1,581,085)
Allowance for equity funds used during construction5,399 637 940 — — 6,976 
Equity in earnings of subsidiaries(240,075)— — — 240,075 — 
Retirement defined benefits credit (expense)—other than service costs1,855 336 (47)— — 2,144 
Interest expense and other charges, net(30,009)(5,888)(8,790)— 3,285 (41,402)
Allowance for borrowed funds used during construction2,113 192 425 — — 2,730 
Interest Income5,635 396 138 — (3,285)2,884 
Loss before income taxes
(1,523,347)(156,467)(168,014)— 240,075 (1,607,753)
Income tax benefit
(333,714)(40,829)(44,035)— — (418,578)
Net loss
(1,189,633)(115,638)(123,979)— 240,075 (1,189,175)
Preferred stock dividends of subsidiaries— 267 191 — — 458 
Net loss attributable to Hawaiian Electric
(1,189,633)(115,905)(124,170)— 240,075 (1,189,633)
Preferred stock dividends of Hawaiian Electric540 — — — — 540 
Net loss for common stock
$(1,190,173)(115,905)(124,170)— 240,075 $(1,190,173)


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Six months ended June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustmentsHawaiian Electric Consolidated
Net loss for common stock
$(1,190,173)(115,905)(124,170)— 240,075 $(1,190,173)
Other comprehensive loss, net of taxes:
Retirement benefit plans:
Adjustment for amortization of net gains recognized during the period in net periodic benefit cost, net of taxes
(1,013)(77)(116)— 193 (1,013)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes918 70 99 — (169)918 
Other comprehensive loss, net of taxes(95)(7)(17)— 24 (95)
Comprehensive loss attributable to common shareholder
$(1,190,268)(115,912)(124,187)— 240,099 $(1,190,268)
31

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Six months ended June 30, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiaryConsolidating adjustmentsHawaiian Electric
Consolidated
Revenues$1,172,219 227,362 225,101 — (130)$1,624,552 
Expenses
Fuel oil467,298 48,231 98,725 — — 614,254 
Purchased power229,739 71,332 20,124 — — 321,195 
Other operation and maintenance172,200 43,016 49,460 — — 264,676 
Depreciation81,838 21,271 18,507 — — 121,616 
Taxes, other than income taxes110,999 21,126 21,186 — — 153,311 
   Total expenses1,062,074 204,976 208,002 — — 1,475,052 
Operating income110,145 22,386 17,099 — (130)149,500 
Allowance for equity funds used during construction5,599 638 836 — — 7,073 
Equity in earnings of subsidiaries22,955 — — — (22,955)— 
Retirement defined benefits credit (expense)—other than service costs1,809 337 (51)— — 2,095 
Interest expense and other charges, net(29,299)(5,806)(6,143)— 130 (41,118)
Allowance for borrowed funds used during construction1,948 204 274 — — 2,426 
Income before income taxes113,157 17,759 12,015 — (22,955)119,976 
Income taxes20,309 4,027 2,334 — — 26,670 
Net income92,848 13,732 9,681 — (22,955)93,306 
Preferred stock dividends of subsidiaries— 267 191 — — 458 
Net income attributable to Hawaiian Electric92,848 13,465 9,490 — (22,955)92,848 
Preferred stock dividends of Hawaiian Electric540 — — — — 540 
Net income for common stock$92,308 13,465 9,490 — (22,955)$92,308 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Six months ended June 30, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiaryConsolidating adjustmentsHawaiian Electric Consolidated
Net income for common stock$92,308 13,465 9,490 — (22,955)$92,308 
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
(940)(111)(129)— 240 (940)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes851 103 114 — (217)851 
Other comprehensive loss, net of taxes
(89)(8)(15)— 23 (89)
Comprehensive income attributable to common shareholder$92,219 13,457 9,475 — (22,932)$92,219 

32

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other
subsi-
diaries
Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Assets      
Property, plant and equipment
Utility property, plant and equipment      
Land$42,860 5,645 3,514 — — $52,019 
Plant and equipment5,471,342 1,483,570 1,396,982 — — 8,351,894 
Right-of-use assets - finance lease362,741 36,074 50,757 — — 449,572 
Less accumulated depreciation(2,001,115)(676,745)(608,860)— — (3,286,720)
Construction in progress264,823 27,641 43,739 — — 336,203 
Utility property, plant and equipment, net4,140,651 876,185 886,132 — — 5,902,968 
Nonutility property, plant and equipment, less accumulated depreciation5,293 115 1,532 — — 6,940 
Total property, plant and equipment, net4,145,944 876,300 887,664 — — 5,909,908 
Investment in wholly owned subsidiaries, at equity482,112 — — — (482,112)— 
Current assets      
Cash and cash equivalents58,819 18,864 10,860 77 — 88,620 
Restricted cash2,000 — — — — 2,000 
Advances to affiliates110,000 — — — (110,000)— 
Customer accounts receivable, net143,860 33,223 34,232 — — 211,315 
Accrued unbilled revenues, net131,246 25,080 22,220 — — 178,546 
Other accounts receivable, net59,341 12,802 24,179 — (38,430)57,892 
Fuel oil stock, at average cost112,116 13,843 20,132 — — 146,091 
Materials and supplies, at average cost65,354 14,154 33,496 — — 113,004 
Prepayments and other50,896 5,784 14,203 — (4,287)66,596 
Regulatory assets65,372 4,872 9,026 — — 79,270 
Total current assets799,004 128,622 168,348 77 (152,717)943,334 
Other long-term assets      
Operating lease right-of-use assets32,387 24,197 8,156 — — 64,740 
Regulatory assets200,662 15,123 27,354 — — 243,139 
Other212,914 37,056 35,144 — (47,337)237,777 
Total other long-term assets445,963 76,376 70,654 — (47,337)545,656 
Total assets$5,873,023 1,081,298 1,126,666 77 (682,166)$7,398,898 
(continued)
























33

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet (continued)
June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other
subsi-
diaries
Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Capitalization and liabilities
Capitalization
Common stock equity
$1,192,842 243,878 238,157 77 (482,112)$1,192,842 
Cumulative preferred stock—not subject to mandatory redemption
22,293 7,000 5,000 — — 34,293 
Long-term debt, net
1,386,884 244,409 256,500 — — 1,887,793 
Total capitalization
2,602,019 495,287 499,657 77 (482,112)3,114,928 
Current liabilities
Current portion of operating lease liabilities5,804 7,216 2,882 — — 15,902 
Current portion of long-term debt39,961 4,995 1,998 — — 46,954 
Short-term borrowings from affiliate— — 110,000 — (110,000)— 
Accounts payable146,724 23,805 24,005 — — 194,534 
Interest and preferred dividends payable17,001 3,228 3,394 — (631)22,992 
Taxes accrued, including revenue taxes180,419 40,640 32,687 — (4,287)249,459 
Regulatory liabilities10,442 8,284 5,380 — — 24,106 
Wildfire tort-related claims (Note 2)
1,369,600 171,200 171,200 — — 1,712,000 
Other83,336 28,351 38,149 — (37,799)112,037 
Total current liabilities1,853,287 287,719 389,695 — (152,717)2,377,984 
Deferred credits and other liabilities
Operating lease liabilities31,854 17,342 5,583 — — 54,779 
Finance lease liabilities348,341 34,712 50,178 — — 433,231 
Deferred income taxes— 7,019 25,521 — (32,540)— 
Regulatory liabilities830,156 205,042 116,305 — — 1,151,503 
Unamortized tax credits57,247 11,052 10,932 — — 79,231 
Defined benefit pension and other postretirement benefit plans liability75,433 — — — (14,797)60,636 
Other74,686 23,125 28,795 — — 126,606 
Total deferred credits and other liabilities1,417,717 298,292 237,314 — (47,337)1,905,986 
Total capitalization and liabilities$5,873,023 1,081,298 1,126,666 77 (682,166)$7,398,898 
34

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
December 31, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsi-diary		Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Assets      
Property, plant and equipment
Utility property, plant and equipment      
Land$42,859 5,645 3,594 — — $52,098 
Plant and equipment5,398,281 1,459,639 1,374,890 — — 8,232,810 
Finance lease right-of-use assets306,099 36,075 — — — 342,174 
Less accumulated depreciation(1,925,660)(666,581)(605,273)— — (3,197,514)
Construction in progress247,836 33,488 38,899 — — 320,223 
Utility property, plant and equipment, net4,069,415 868,266 812,110 — — 5,749,791 
Nonutility property, plant and equipment, less accumulated depreciation5,295 115 1,532 — — 6,942 
Total property, plant and equipment, net4,074,710 868,381 813,642 — — 5,756,733 
Investment in wholly owned subsidiaries, at equity
722,211 — — — (722,211)— 
Current assets      
Cash and cash equivalents89,755 10,658 5,587 77 — 106,077 
Restricted cash2,000 — — — — 2,000 
Advances to affiliates70,500 — — — (70,500)— 
Customer accounts receivable, net172,747 38,216 33,346 — — 244,309 
Accrued unbilled revenues, net136,367 25,102 24,175 — — 185,644 
Other accounts receivable, net143,160 13,318 32,521 — (77,480)111,519 
Fuel oil stock, at average cost108,228 17,968 22,041 — — 148,237 
Materials and supplies, at average cost64,334 14,397 35,702 — — 114,433 
Prepayments and other40,767 7,724 11,638 — (1,638)58,491 
Regulatory assets58,920 5,771 3,762 — — 68,453 
Total current assets886,778 133,154 168,772 77 (149,618)1,039,163 
Other long-term assets      
Operating lease right-of-use assets34,856 27,470 9,551 — — 71,877 
Regulatory assets189,417 13,575 23,359 — — 226,351 
Other134,033 36,439 33,129 — (14,171)189,430 
Total other long-term assets358,306 77,484 66,039 — (14,171)487,658 
Total assets$6,042,005 1,079,019 1,048,453 77 (886,000)$7,283,554 
(continued)























35

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet (continued)
December 31, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsi-diary		Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Capitalization and liabilities
Capitalization
Common stock equity$2,409,110 359,790 362,344 77 (722,211)$2,409,110 
Cumulative preferred stock—not subject to mandatory redemption22,293 7,000 5,000 — — 34,293 
Long-term debt, net1,426,516 249,339 258,422 — — 1,934,277 
Total capitalization3,857,919 616,129 625,766 77 (722,211)4,377,680 
Current liabilities
Current portion of operating lease liabilities6,788 7,025 2,804 — — 16,617 
Short-term borrowings-affiliate— — 70,500 — (70,500)— 
Accounts payable136,102 29,418 25,520 — — 191,040 
Interest and preferred dividends payable17,085 3,098 3,074 — (375)22,882 
Taxes accrued, including revenue taxes211,840 43,932 37,808 — (1,638)291,942 
Regulatory liabilities20,013 8,508 8,038 — — 36,559 
Wildfire tort-related claims
75,000 — — — — 75,000 
Other90,131 33,240 50,170 — (77,105)96,436 
Total current liabilities556,959 125,221 197,914 — (149,618)730,476 
Deferred credits and other liabilities
Operating lease liabilities34,262 20,792 7,044 — — 62,098 
Finance lease liabilities295,935 35,043 — — — 330,978 
Deferred income taxes280,029 51,661 67,311 — — 399,001 
Regulatory liabilities803,404 199,173 111,554 — — 1,114,131 
Unamortized tax credits61,130 11,650 11,532 — — 84,312 
Defined benefit pension and other postretirement benefit plans liability74,842 — — — (14,171)60,671 
Other77,525 19,350 27,332 — 124,207 
Total deferred credits and other liabilities1,627,127 337,669 224,773 — (14,171)2,175,398 
Total capitalization and liabilities$6,042,005 1,079,019 1,048,453 77 (886,000)$7,283,554 

36

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Changes in Common Stock Equity
Six months ended June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other
subsidiaries
Consolidating
adjustments		Hawaiian Electric
Consolidated
Balance, December 31, 2023$2,409,110 359,790 362,344 77 (722,211)$2,409,110 
Net loss for common stock
(1,190,173)(115,905)(124,170)— 240,075 (1,190,173)
Other comprehensive loss, net of taxes(95)(7)(17)— 24 (95)
Common stock dividends(26,000)— — — — (26,000)
Balance, June 30, 2024$1,192,842 243,878 238,157 77 (482,112)$1,192,842 
 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Changes in Common Stock Equity
Six months ended June 30, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiary		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 stock92,308 13,465 9,490 — (22,955)92,308 
Other comprehensive loss, net of taxes
(89)(8)(15)— 23 (89)
Common stock dividends(64,500)(8,950)(7,350)— 16,300 (64,500)
Balance, June 30, 2023$2,371,889 349,227 359,161 77 (708,465)$2,371,889 

Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Cash Flows
Six months ended June 30, 2024
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other
subsidiaries
Consolidating
adjustments		Hawaiian Electric
Consolidated
Net cash provided by operating activities$137,811 36,712 12,800 — (1,850)$185,473 
Cash flows from investing activities      
Capital expenditures(95,431)(27,981)(44,788)— — (168,200)
Advances to affiliates
(39,500)— — — 39,500 — 
Other535 245 (1,087)— 1,850 1,543 
Net cash used in investing activities(134,396)(27,736)(45,875)— 41,350 (166,657)
Cash flows from financing activities      
Common stock dividends(26,000)— — — — (26,000)
Preferred stock dividends of Hawaiian Electric and subsidiaries(998)— — — — (998)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less
— — 39,500 — (39,500)— 
Payments of obligations under finance leases(3,382)(311)(44)(3,737)
Other(3,971)(459)(1,108)— — (5,538)
Net cash provided by (used in) financing activities
(34,351)(770)38,348 — (39,500)(36,273)
Net increase (decrease) in cash, cash equivalents and restricted cash(30,936)8,206 5,273 — — (17,457)
Cash, cash equivalents and restricted cash, beginning of period91,755 10,658 5,587 77 — 108,077 
Cash, cash equivalents and restricted cash, end of period60,819 18,864 10,860 77 — 90,620 
Less: Restricted cash(2,000)— — — — (2,000)
Cash and cash equivalents, end of period$58,819 18,864 10,860 77 — $88,620 

37

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Cash Flows
Six months ended June 30, 2023
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiary		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net cash provided by operating activities$274,412 43,352 34,681 — (16,300)$336,145 
Cash flows from investing activities     
Capital expenditures (152,823)(33,512)(43,814)— — (230,149)
Advances to affiliates
— 4,500 21,700 — (26,200)— 
Other2,086 912 1,058 — — 4,056 
Net cash used in investing activities(150,737)(28,100)(21,056)— (26,200)(226,093)
Cash flows from financing activities     
Common stock dividends(64,500)(8,950)(7,350)— 16,300 (64,500)
Preferred stock dividends of Hawaiian Electric and subsidiaries(540)(267)(191)— — (998)
Proceeds from issuance of long-term debt100,000 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(1,241)(98)— — — (1,339)
Other(571)(135)(137)— — (843)
Net cash provided by (used in) financing activities(81,019)15,550 17,322 — 42,500 (5,647)
Net increase in cash and cash equivalents
42,656 30,802 30,947 — — 104,405 
Cash and cash equivalents, beginning of period27,579 5,092 6,494 77 — 39,242 
Cash and cash equivalents, end of period$70,235 35,894 37,441 77 — $143,647 

38

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Note 5 · Bank segment
Selected financial information
American Savings Bank, F.S.B.
Statements of Income and Comprehensive Income Data
 Three months ended June 30Six months ended June 30
(in thousands)2024202320242023
Interest and dividend income    
Interest and fees on loans$72,960 $67,966 $145,931 $132,808 
Interest and dividends on investment securities13,218 13,775 28,182 28,412 
Total interest and dividend income86,178 81,741 174,113 161,220 
Interest expense    
Interest on deposit liabilities18,015 9,661 35,447 16,498 
Interest on other borrowings6,479 8,852 14,633 16,573 
Total interest expense24,494 18,513 50,080 33,071 
Net interest income61,684 63,228 124,033 128,149 
Provision for credit losses(1,910)43 (4,069)1,218 
Net interest income after provision for credit losses63,594 63,185 128,102 126,931 
Noninterest income    
Fees from other financial services5,133 5,009 10,007 9,688 
Fee income on deposit liabilities4,630 4,504 9,528 9,103 
Fee income on other financial products2,960 2,768 5,703 5,512 
Bank-owned life insurance2,255 1,955 5,839 3,380 
Mortgage banking income364 230 788 360 
Gain on sale of real estate— 495 — 495 
Other income, net423 678 1,109 1,479 
Total noninterest income15,765 15,639 32,974 30,017 
Noninterest expense    
Compensation and employee benefits29,802 29,394 62,261 59,598 
Occupancy5,220 5,539 10,283 11,127 
Data processing4,960 5,095 9,806 10,107 
Services4,250 2,689 8,401 5,284 
Equipment2,477 2,957 5,126 5,603 
Office supplies, printing and postage1,006 1,109 2,024 2,274 
Marketing747 834 1,523 1,850 
Goodwill impairment
82,190 — 82,190 — 
Other expense5,813 6,152 10,755 12,343 
Total noninterest expense136,465 53,769 192,369 108,186 
Income (loss) before income taxes
(57,106)25,055 (31,293)48,762 
Income tax (benefit)
(11,319)4,851 (6,440)9,996 
Net income (loss)
(45,787)20,204 (24,853)38,766 
Other comprehensive income (loss), net of taxes1,633 (7,210)(8,135)11,220 
Comprehensive income (loss)
$(44,154)$12,994 $(32,988)$49,986 

39

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:
 Three months ended June 30Six months ended June 30
(in thousands)2024202320242023
Interest and dividend income$86,178 $81,741 $174,113 $161,220 
Noninterest income15,765 15,639 32,974 30,017 
Less: Gain on sale of real estate— 495 — 495 
*Revenues-Bank101,943 96,885 207,087 190,742 
Total interest expense24,494 18,513 50,080 33,071 
Provision for credit losses(1,910)43 (4,069)1,218 
Noninterest expense136,465 53,769 192,369 108,186 
Less: Gain on sale of real estate— 495 — 495 
Less: Retirement defined benefits credit—other than service costs(280)(187)(561)(374)
*Expenses-Bank159,329 72,017 238,941 142,354 
*Operating income (loss)-Bank
(57,386)24,868 (31,854)48,388 
Add back: Retirement defined benefits credit—other than service costs(280)(187)(561)(374)
Income (loss) before income taxes
$(57,106)$25,055 $(31,293)$48,762 
Goodwill. Goodwill is initially recorded as the excess of the purchase price over the fair value of the net assets acquired in a business combination and is subsequently evaluated at least annually for impairment. The Company has identified ASB as a reporting unit and ASB’s goodwill relates to past acquisitions and is ASB’s only intangible asset with an indefinite useful life. The Company performs assessments of the carrying value of its goodwill at least annually and whenever events occur or circumstances change that would more-likely-than-not reduce the fair value of a reporting unit below its carrying amount. Examples of these events and circumstances include a significant change in business climate, an adverse action or assessment by a regulator, competition, loss of key personnel, a more-likely-than-not expectation that a reporting unit or a significant portion of a reporting unit will be sold or otherwise disposed of, and other factors.
HEI and ASB have been undertaking a comprehensive review of strategic options for ASB. During the course of this process, HEI and ASB had determined it is more-likely-than-not that the fair value of ASB is less than its carrying value. In light of this, as part of its on-going goodwill evaluation and the change in circumstances, after performing the goodwill impairment test as of June 30, 2024, HEI and ASB determined the full amount of its goodwill was impaired. As a result of our June 30, 2024 impairment test we recorded a pretax goodwill impairment charge of $82.2 million for the three and six months ended June 30, 2024. The impairment charge is recorded in “Total Noninterest Expense” in ASB’s Statements of Income and Comprehensive Income Data, and recorded in “Bank Expenses” in the Company’s Condensed Consolidated Statements of Income. The impairment charge was non-cash in nature and did not affect the Company’s current liquidity, cash flows or any debt covenants under the Company’s existing credit agreements.
40

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
American Savings Bank, F.S.B.
Balance Sheets Data
(in thousands)June 30, 2024December 31, 2023
Assets    
Cash and due from banks $139,114  $184,383 
Interest-bearing deposits195,721 251,072 
Cash and cash equivalents334,835 435,455 
Investment securities
Available-for-sale, at fair value 1,061,687  1,136,439 
Held-to-maturity, at amortized cost (fair value of $1,058,691 and $1,103,668, at June 30, 2024 and December 31, 2023, respectively)
1,179,182 1,201,314 
Stock in Federal Home Loan Bank, at cost 29,204  14,728 
Loans held for investment 6,030,158  6,180,810 
Allowance for credit losses (66,813) (74,372)
Net loans 5,963,345  6,106,438 
Loans held for sale, at lower of cost or fair value 13,904  15,168 
Other 698,648  681,460 
Goodwill —  82,190 
Total assets $9,280,805  $9,673,192 
Liabilities and shareholder’s equity    
Deposit liabilities—noninterest-bearing $2,515,062  $2,599,762 
Deposit liabilities—interest-bearing 5,521,411  5,546,016 
Other borrowings 520,000  750,000 
Other 226,488  247,563 
Total liabilities 8,782,961  9,143,341 
  
Common stock 1  1 
Additional paid-in capital359,048 358,067 
Retained earnings 439,202  464,055 
Accumulated other comprehensive loss, net of tax benefits    
Net unrealized losses on securities$(291,864) $(282,963)
Retirement benefit plans(8,543)(300,407)(9,309)(292,272)
Total shareholder’s equity497,844  529,851 
Total liabilities and shareholder’s equity $9,280,805  $9,673,192 
Other assets    
Bank-owned life insurance $197,714  $187,857 
Premises and equipment, net 181,855  187,042 
Accrued interest receivable 29,003  28,472 
Mortgage-servicing rights 7,906  8,169 
Low-income housing investments104,394 112,234 
Deferred tax asset122,927 104,292 
Other 54,849  53,394 
Total other assets
 $698,648  $681,460 
Other liabilities    
Accrued expenses $110,173  $115,231 
Cashier’s checks 37,372  40,479 
Advance payments by borrowers 11,477  10,107 
Other 67,466  81,746 
Total other liabilities
 $226,488  $247,563 
    
41

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
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 and borrowings from the Federal Reserve Bank.
Investment securities.  The major components of investment securities were as follows:
 Amortized costGross unrealized gainsGross unrealized lossesEstimated fair
value		Gross unrealized losses
 Less than 12 months12 months or longer
(dollars in thousands)Number of issuesFair 
value		AmountNumber of issuesFair 
value		Amount
June 30, 2024        
Available-for-sale
U.S. Treasury and federal agency obligations$9,226 $— $(343)$8,883 — $— $— 8 $8,883 $(343)
Mortgage-backed securities*1,229,529 3 (223,731)1,005,801 — — — 115 1,005,191 (223,731)
Corporate bonds35,171 — (2,244)32,927 — — — 3 32,927 (2,244)
Mortgage revenue bonds14,076 — — 14,076 — — — — — — 
 $1,288,002 $3 $(226,318)$1,061,687 — $— $— 126 $1,047,001 $(226,318)
Held-to-maturity
U.S. Treasury and federal agency obligations$59,929 $— $(7,839)$52,090 — $— $— 3 $52,090 $(7,839)
Mortgage-backed securities*1,119,253 41 (112,693)1,006,601 30 314,047 (9,253)72 685,612 (103,440)
 $1,179,182 $41 $(120,532)$1,058,691 30 $314,047 $(9,253)75 $737,702 $(111,279)
December 31, 2023
Available-for-sale
U.S. Treasury and federal agency obligations$12,437 $— $(427)$12,010 — $— $— 9 $12,010 $(427)
Mortgage-backed securities*1,279,852 — (202,684)1,077,168 3 1,649 (22)116 1,075,519 (202,662)
Corporate bonds35,239 — (2,336)32,903 — — — 3 32,903 (2,336)
Mortgage revenue bonds14,358 — — 14,358 — — — — — — 
 $1,341,886 $— $(205,447)$1,136,439 3 $1,649 $(22)128 $1,120,432 $(205,425)
Held-to-maturity
U.S. Treasury and federal agency obligations$59,917 $— $(7,135)$52,782 — $— $— 3 $52,782 $(7,135)
Mortgage-backed securities* 1,141,397 2,221 (92,732)1,050,886 37 378,326 (7,610)43 432,082 (85,122)
 $1,201,314 $2,221 $(99,867)$1,103,668 37 $378,326 $(7,610)46 $484,864 $(92,257)
* 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 June 30, 2024 and December 31, 2023, 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, an agency of the government or a government-sponsored entity. 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 June 30, 2024 and December 31, 2023.
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.
42

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
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:
June 30, 2024Amortized 
cost		Fair value
(in thousands)  
Available-for-sale
Due in one year or less$626 $614 
Due after one year through five years43,771 41,196 
Due after five years through ten years14,076 14,076 
Due after ten years— — 
 58,473 55,886 
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies1,229,529 1,005,801 
Total available-for-sale securities$1,288,002 $1,061,687 
Held-to-maturity
Due in one year or less$— $— 
Due after one year through five years39,849 35,286 
Due after five years through ten years20,080 16,804 
Due after ten years— — 
59,929 52,090 
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies1,119,253 1,006,601 
Total held-to-maturity securities$1,179,182 $1,058,691 
There were no sales of available-for-sale securities for the three and six months ended June 30, 2024 and 2023.
The components of loans were summarized as follows:
June 30, 2024December 31, 2023
(in thousands)  
Real estate:  
Residential 1-4 family$2,603,825 $2,595,162 
Commercial real estate1,368,907 1,374,038 
Home equity line of credit973,216 1,017,207 
Residential land20,818 18,364 
Commercial construction181,148 172,405 
Residential construction17,254 17,843 
Total real estate5,165,168 5,195,019 
Commercial648,286 743,303 
Consumer244,637 272,256 
Total loans6,058,091 6,210,578 
Less: Deferred fees and discounts(27,933)(29,768)
Allowance for credit losses (66,813)(74,372)
Total loans, net$5,963,345 $6,106,438 
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.
As of June 30, 2024, ASB had commitments to borrowers for loans and unused lines and letters of credit of $1.9 billion, of which, commitments to lend to borrowers experiencing financial difficulty whose loan terms have been modified were nil.
43

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Allowance for credit losses.  The allowance for credit losses (balances and changes) by portfolio segment were as follows:
(in thousands)Residential
1-4 family		Commercial real
estate		Home
equity line of credit		Residential landCommercial constructionResidential constructionCommercial loansConsumer loansTotal
Three months ended June 30, 2024        
Allowance for credit losses:         
Beginning balance$6,406 $20,334 $8,073 $672 $3,401 $41 $7,614 $24,516 $71,057 
Charge-offs— — — — — — (126)(3,000)(3,126)
Recoveries7 — 9 — — — 190 686 892 
Provision(194)(1,678)1,470 87 (32)(3)(1,361)(299)(2,010)
Ending balance$6,219 $18,656 $9,552 $759 $3,369 $38 $6,317 $21,903 $66,813 
Three months ended June 30, 2023        
Allowance for credit losses:         
Beginning balance$4,612 $22,701 $6,053 $620 $735 $28 $11,936 $24,611 $71,296 
Charge-offs(181)— (297)— — — (157)(2,568)(3,203)
Recoveries2 — 17 3 — — 206 904 1,132 
Provision275 (2,423)1,366 30 1,814 (2)(627)(590)(157)
Ending balance$4,708 $20,278 $7,139 $653 $2,549 $26 $11,358 $22,357 $69,068 
Six months ended June 30, 2024        
Allowance for credit losses:         
Beginning balance$7,435 $22,185 $7,778 $621 $3,603 $43 $9,122 $23,585 $74,372 
Charge-offs(842)— — — — — (240)(5,719)(6,801)
Recoveries193 — 247 — — — 285 1,686 2,411 
Provision(567)(3,529)1,527 138 (234)(5)(2,850)2,351 (3,169)
Ending balance$6,219 $18,656 $9,552 $759 $3,369 $38 $6,317 $21,903 $66,813 
Six months ended June 30, 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(990)— (360)— — — (384)(4,891)(6,625)
Recoveries6 — 34 3 — — 604 1,812 2,459 
Provision(578)(1,620)1,340 (67)1,354 (20)(1,288)1,897 1,018 
Ending balance$4,708 $20,278 $7,139 $653 $2,549 $26 $11,358 $22,357 $69,068 

44

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Allowance for loan commitments.  The allowance for loan commitments by portfolio segment were as follows:
(in thousands)Home equity
 line of credit		Commercial constructionCommercial loansTotal
Three months ended June 30, 2024
Allowance for loan commitments:
Beginning balance$600 $3,100 $400 $4,100 
Provision100 — — 100 
Ending balance$700 $3,100 $400 $4,200 
Three months ended June 30, 2023
Allowance for loan commitments:
Beginning balance$400 $2,600 $1,400 $4,400 
Provision200 1,200 (1,200)200 
Ending balance$600 $3,800 $200 $4,600 
Six months ended June 30, 2024
Allowance for loan commitments:
Beginning balance$600 $4,300 $200 $5,100 
Provision100 (1,200)200 (900)
Ending balance$700 $3,100 $400 $4,200 
Six months ended June 30, 2023
Allowance for loan commitments:
Beginning balance$400 $2,600 $1,400 $4,400 
Provision200 1,200 (1,200)200 
Ending balance$600 $3,800 $200 $4,600 
Credit quality.  ASB performs an internal loan review and grading on an ongoing basis. The review provides management with periodic information as to the quality of the loan portfolio and effectiveness of its lending policies and procedures. The objectives of the loan review and grading procedures are to identify, in a timely manner, existing or emerging credit trends so that appropriate steps can be initiated to manage risk and avoid or minimize future losses. Loans subject to grading include commercial, commercial real estate and commercial construction loans.
Each commercial and commercial real estate loan is assigned an Asset Quality Rating (AQR) reflecting the likelihood of repayment or orderly liquidation of that loan transaction pursuant to regulatory credit classifications:  Pass, Special Mention, Substandard, Doubtful, and Loss. The AQR is a function of the probability of default model rating, the loss given default, and possible non-model factors which impact the ultimate collectability of the loan such as character of the business owner/guarantor, interim period performance, litigation, tax liens and major changes in business and economic conditions. Pass exposures generally are well protected by the current net worth and paying capacity of the obligor or by the value of the asset or underlying collateral. Special Mention loans have potential weaknesses that, if left uncorrected, could jeopardize the liquidation of the debt. Substandard loans have well-defined weaknesses that jeopardize the liquidation of the debt and are characterized by the distinct possibility that ASB may sustain some loss. An asset classified Doubtful has the weaknesses of those classified Substandard, with the added characteristic that the weaknesses make collection or liquidation in full, on the basis of currently existing facts, conditions, and values, highly questionable and improbable. An asset classified Loss is considered uncollectible and has such little value that its continuance as a bankable asset is not warranted.
45

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
The credit risk profile by vintage date based on payment activity or internally assigned grade for loans was as follows:
Term Loans by Origination YearRevolving Loans
(in thousands)20242023202220212020PriorRevolvingConverted to term loansTotal
June 30, 2024
Residential 1-4 family
Current$89,885 $255,714 $399,372 $715,212 $390,719 $745,688 $— $— $2,596,590 
30-59 days past due— — — — — 1,362 — — 1,362 
60-89 days past due— — — 543 — 1,304 — — 1,847 
Greater than 89 days past due— — 726 — — 3,300 — — 4,026 
89,885 255,714 400,098 715,755 390,719 751,654 — — 2,603,825 
Home equity line of credit
Current— — — — — — 905,690 63,617 969,307 
30-59 days past due— — — — — — 1,403 632 2,035 
60-89 days past due— — — — — — 542 216 758 
Greater than 89 days past due— — — — — — 885 231 1,116 
— — — — — — 908,520 64,696 973,216 
Residential land
Current5,402 3,748 4,524 4,797 1,737 610 — — 20,818 
30-59 days past due— — — — — — — — — 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — — — — — 
5,402 3,748 4,524 4,797 1,737 610 — — 20,818 
Residential construction
Current550 7,501 9,203 — — — — — 17,254 
30-59 days past due— — — — — — — — — 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — — — — — 
550 7,501 9,203 — — — — — 17,254 
Consumer
Current18,275 70,089 130,936 6,589 840 328 9,746 2,071 238,874 
30-59 days past due242 552 1,040 126 12 3 61 141 2,177 
60-89 days past due22 602 1,053 53 7 3 43 25 1,808 
Greater than 89 days past due— 454 916 63 10 — 179 156 1,778 
18,539 71,697 133,945 6,831 869 334 10,029 2,393 244,637 
Commercial real estate
Pass22,976 105,110 376,911 189,510 263,783 373,432 15,482 — 1,347,204 
Special Mention— — 1,208 1,465 — 1,116 — — 3,789 
Substandard— — — 1,516 — 13,990 — — 15,506 
Doubtful— — — — — 2,408 — — 2,408 
22,976 105,110 378,119 192,491 263,783 390,946 15,482 — 1,368,907 
Commercial construction
Pass— 62,306 36,925 16,416 1,333 — 64,168 — 181,148 
Special Mention— — — — — — — — — 
Substandard— — — — — — — — — 
Doubtful— — — — — — — — — 
— 62,306 36,925 16,416 1,333 — 64,168 — 181,148 
Commercial
Pass33,205 88,184 166,815 92,150 71,214 79,756 97,353 6,929 635,606 
Special Mention— 1,685 — — — — 3,801 — 5,486 
Substandard— — 2,775 472 — 3,049 730 80 7,106 
Doubtful— — — — 88 — — — 88 
33,205 89,869 169,590 92,622 71,302 82,805 101,884 7,009 648,286 
Total loans$170,557 $595,945 $1,132,404 $1,028,912 $729,743 $1,226,349 $1,100,083 $74,098 $6,058,091 
46

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Term Loans by Origination YearRevolving Loans
(in thousands)20232022202120202019PriorRevolvingConverted to term loansTotal
December 31, 2023
Residential 1-4 family
Current$263,605 $407,304 $729,256 $399,766 $104,487 $672,408 $— $— $2,576,826 
30-59 days past due— 708 — 268 — 3,525 — — 4,501 
60-89 days past due— 726 2,694 — — 1,745 — — 5,165 
Greater than 89 days past due— 2,519 871 1,129 489 3,662 — — 8,670 
263,605 411,257 732,821 401,163 104,976 681,340 — — 2,595,162 
Home equity line of credit
Current— — — — — — 954,461 59,146 1,013,607 
30-59 days past due— — — — — — 1,219 262 1,481 
60-89 days past due— — — — — — 597 — 597 
Greater than 89 days past due— — — — — — 1,111 411 1,522 
— — — — — — 957,388 59,819 1,017,207 
Residential land
Current3,788 4,097 7,234 1,847 — 723 — — 17,689 
30-59 days past due— — — — — — — — — 
60-89 days past due— 675 — — — — — — 675 
Greater than 89 days past due— — — — — — — — — 
3,788 4,772 7,234 1,847 — 723 — — 18,364 
Residential construction
Current5,369 10,984 1,490 — — — — — 17,843 
30-59 days past due— — — — — — — — — 
60-89 days past due— — — — — — — — — 
Greater than 89 days past due— — — — — — — — — 
5,369 10,984 1,490 — — — — — 17,843 
Consumer
Current87,686 153,239 9,852 1,654 451 200 10,663 2,779 266,524 
30-59 days past due805 1,314 176 29 24 — 56 163 2,567 
60-89 days past due385 886 114 41 21 — 60 69 1,576 
Greater than 89 days past due354 786 101 24 34 — 67 223 1,589 
89,230 156,225 10,243 1,748 530 200 10,846 3,234 272,256 
Commercial real estate
Pass104,368 384,144 180,986 267,458 65,625 307,367 15,482 — 1,325,430 
Special Mention— 1,975 11,159 — 14,110 3,008 — — 30,252 
Substandard— — 1,538 — 11,048 5,770 — — 18,356 
Doubtful— — — — — — — — — 
104,368 386,119 193,683 267,458 90,783 316,145 15,482 — 1,374,038 
Commercial construction
Pass45,863 33,240 26,133 1,333 — — 65,836 — 172,405 
Special Mention— — — — — — — — — 
Substandard— — — — — — — — — 
Doubtful— — — — — — — — — 
45,863 33,240 26,133 1,333 — — 65,836 — 172,405 
Commercial
Pass124,667 199,796 106,669 73,976 37,580 80,012 87,206 6,250 716,156 
Special Mention1,860 6,989 951 — 250 — 7,352 — 17,402 
Substandard— 2,962 1,848 98 60 3,369 1,275 133 9,745 
Doubtful— — — — — — — — — 
126,527 209,747 109,468 74,074 37,890 83,381 95,833 6,383 743,303 
Total loans$638,750 $1,212,344 $1,081,072 $747,623 $234,179 $1,081,789 $1,145,385 $69,436 $6,210,578 
47

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Gross charge-offs by portfolio segment and vintage were as follows:
(in thousands)20242023202220212020PriorTotal
Six months ended June 30, 2024
Residential 1-4 family$— $— $361 $277 $— $204 $842 
Commercial real estate— — — — — — — 
Home equity line of credit— — — — — — — 
Residential land— — — — — — — 
Commercial construction— — — — — — — 
Residential construction— — — — — — — 
Commercial— — — 14 — 226 240 
Consumer398 1,969 2,803 281 75 193 5,719 
Total
$398 $1,969 $3,164 $572 $75 $623 $6,801 
Revolving loans converted to term loans during the six months ended June 30, 2024 in the commercial, home equity line of credit and consumer portfolios were $1.9 million, $11.3 million and $0.4 million, respectively. Revolving loans converted to term loans during the six months ended June 30, 2023 in the commercial, home equity line of credit and consumer portfolios were $2.0 million, $14.9 million and $0.9 million, respectively.
The credit risk profile based on payment activity for loans was as follows:
(in thousands)30-59
days
past due		60-89
days
past due
 
90 days or more past due
Total
past due		CurrentTotal
financing
receivables		Amortized cost>
90 days and
accruing
June 30, 2024       
Real estate:       
Residential 1-4 family$1,362 $1,847 $4,026 $7,235 $2,596,590 $2,603,825 $— 
Commercial real estate— — 10,908 10,908 1,357,999 1,368,907 — 
Home equity line of credit2,035 758 1,116 3,909 969,307 973,216 — 
Residential land— — — — 20,818 20,818 — 
Commercial construction— — — — 181,148 181,148 — 
Residential construction— — — — 17,254 17,254 — 
Commercial107 150 108 365 647,921 648,286 — 
Consumer2,177 1,808 1,778 5,763 238,874 244,637 — 
Total loans$5,681 $4,563 $17,936 $28,180 $6,029,911 $6,058,091 $— 
December 31, 2023       
Real estate:       
Residential 1-4 family$4,501 $5,165 $8,670 $18,336 $2,576,826 $2,595,162 $425 
Commercial real estate— — 11,048 11,048 1,362,990 1,374,038 — 
Home equity line of credit1,481 597 1,522 3,600 1,013,607 1,017,207 — 
Residential land— 675 — 675 17,689 18,364 — 
Commercial construction— — — — 172,405 172,405 — 
Residential construction— — — — 17,843 17,843 — 
Commercial163 135 244 542 742,761 743,303 — 
Consumer2,567 1,576 1,589 5,732 266,524 272,256 — 
Total loans$8,712 $8,148 $23,073 $39,933 $6,170,645 $6,210,578 $425 
48

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
The credit risk profile based on nonaccrual loans were as follows:
(in thousands)June 30, 2024December 31, 2023
With a related ACL
Without a related ACL
Total
With a related ACL
Without a related ACL
Total
Real estate:
Residential 1-4 family$9,542 $4,446 $13,988 $7,755 $2,190 $9,945 
Commercial real estate10,908 — 10,908 11,048 — 11,048 
Home equity line of credit2,211 1,091 3,302 2,626 1,135 3,761 
Residential land675 — 675 780 — 780 
Commercial construction— — — — — — 
Residential construction— — — — — — 
Commercial 169 173 342 133 301 434 
Consumer 2,656 — 2,656 2,458 — 2,458 
  Total $26,161 $5,710 $31,871 $24,800 $3,626 $28,426 
ASB did not recognize interest on nonaccrual loans for the six months ended June 30, 2024 and 2023.
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.
49

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Loan modifications made to borrowers experiencing financial difficulty during the three and six months ended June 30, 2024 were as follows:
(in thousands)
Term extension
Payment delay
Combination payment delay & term extension
Total
% of total class of loans
Three months ended June 30, 2024
Real estate loans
Residential 1-4 family$50 $2,093 $— $2,143 0.08 %
Commercial real estate— — — — — 
Home equity line of credit— — — — — 
Residential land— — — — — 
Commercial construction— — — — — 
Residential construction— — — — — 
Commercial— — — — — 
Consumer— — — — — 
Total$50 $2,093 $— $2,143 0.04 %
Six months ended June 30, 2024
Real estate loans
Residential 1-4 family$315 $4,931 $— $5,246 0.20 %
Commercial real estate— — 1,208 1,208 0.09 %
Home equity line of credit— 447 — 447 0.05 %
Residential land— 675 — 675 3.24 %
Commercial construction— — — — — 
Residential construction— — — — — 
Commercial — — — — — 
Consumer — — — — — 
Total$315 $6,053 $1,208 $7,576 0.13 %
50

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Financial effect of loan modifications during the three and six months ended June 30, 2024 for borrowers experiencing financial difficulty were as follows:
Weighted average
Term extension
(in months)
 Payment delay
(in months)
Three months ended June 30, 2024
Real estate loans
Residential 1-4 family11411
Commercial real estate— — 
Home equity line of credit— — 
Residential land— — 
Commercial construction— — 
Residential construction— — 
Commercial— — 
Consumer— — 
Six months ended June 30, 2024
Real estate loans
Residential 1-4 family14910
Commercial real estate99
Home equity line of credit— 9
Residential land— 9
Commercial construction— — 
Residential construction— — 
Commercial— — 
Consumer— — 
Credit risk profile based on payment activity for loans modified during the six months ended June 30, 2024 were as follows:
(in thousands)
Current
30-59 days
past due
60-89 days
past due
90 days or more past due
Total
Real estate loans
Residential 1-4 family$3,144 $— $— $2,102 $5,246 
Commercial real estate1,208 — — — 1,208 
Home equity line of credit447 — — — 447 
Residential land675 — — — 675 
Commercial construction— — — — — 
Residential construction— — — — — 
Commercial— — — — — 
Consumer — — — — — 
Total$5,474 $— $— $2,102 $7,576 
During the six months ended June 30, 2024, there were no loan modifications made to borrowers experiencing financial difficulty that defaulted.
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.
51

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Loans considered collateral-dependent were as follows:
Amortized cost
(in thousands)June 30, 2024December 31, 2023Collateral type
Real estate:
   Residential 1-4 family$4,524 $2,272  Residential real estate property
Commercial real estate10,908 11,048  Commercial real estate property
   Home equity line of credit1,200 1,135  Residential real estate property
     Total real estate16,632 14,455 
Commercial262 301  Business assets
     Total $16,894 $14,756 
ASB had $3.6 million and $3.4 million of consumer mortgage loans collateralized by residential real estate property that were in the process of foreclosure at June 30, 2024 and December 31, 2023, 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 $30.9 million and $8.9 million for the three months ended June 30, 2024 and 2023, respectively, and recognized gains on such sales of $0.4 million and $0.3 million for the three months ended June 30, 2024 and 2023, respectively. ASB received proceeds from the sale of residential mortgages of $57.3 million and $14.6 million for the six months ended June 30, 2024 and 2023, respectively, and recognized gains on such sales of $0.8 million and $0.4 million for the six months ended June 30, 2024 and 2023, respectively.
There were no repurchased mortgage loans for the six months ended June 30, 2024 and 2023.
Mortgage servicing fees, a component of other income, net, were $0.8 million and $0.9 million for the three months ended June 30, 2024 and 2023, respectively. Mortgage servicing fees, a component of other income, net, were $1.7 million and $1.8 million for the six months ended June 30, 2024 and 2023, respectively.
Changes in the carrying value of MSRs were as follows:
(in thousands)Gross
carrying amount		Accumulated amortizationValuation allowanceNet
carrying amount
June 30, 2024$18,114 $(10,208)$— $7,906 
December 31, 202318,241 (10,072)— 8,169 
Changes related to MSRs were as follows:
Three months ended June 30Six months ended June 30
(in thousands)2024202320242023
Mortgage servicing rights
Beginning balance$8,050 $8,745 $8,169 $9,047 
Amount capitalized179 84 377 135 
Amortization(323)(334)(640)(687)
Other-than-temporary impairment— — — — 
Carrying amount before valuation allowance7,906 8,495 7,906 8,495 
Valuation allowance for mortgage servicing rights
Beginning balance— — — — 
Provision— — — — 
Other-than-temporary impairment— — — — 
Ending balance— — — — 
Net carrying value of mortgage servicing rights$7,906 $8,495 $7,906 $8,495 
52

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
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)June 30, 2024December 31, 2023
Unpaid principal balance$1,399,592 $1,402,736 
Weighted average note rate3.57 %3.47 %
Weighted average discount rate10.00 %10.00 %
Weighted average prepayment speed6.81 %5.71 %
The sensitivity analysis of fair value of MSRs to hypothetical adverse changes of 25 and 50 basis points in certain key assumptions was as follows:
(dollars in thousands)June 30, 2024December 31, 2023
Prepayment rate:
  25 basis points adverse rate change$(133)$(90)
  50 basis points adverse rate change(296)(204)
Discount rate:
  25 basis points adverse rate change(185)(203)
  50 basis points adverse rate change(367)(402)
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 June 30, 2024 and December 31, 2023, ASB had $520.0 million and $200.0 million of FHLB advances outstanding, respectively, and borrowings with the Federal Reserve Bank of nil and $550.0 million, respectively. As of June 30, 2024, 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.
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.
53

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
The notional amount and fair value of ASB’s derivative financial instruments were as follows:
 June 30, 2024December 31, 2023
(in thousands)Notional amountFair valueNotional amountFair value
Interest rate lock commitments$5,330 $89 $6,246 $86 
Forward commitments5,250 5 5,500 (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
June 30, 2024December 31, 2023
(in thousands) Asset derivatives Liability
derivatives 		 Asset derivatives Liability
derivatives
Interest rate lock commitments$89 $— $86 $— 
Forward commitments5 — — 18 
 $94 $— $86 $18 
1 Asset derivatives are included in other assets and liability derivatives are included in other liabilities in the balance sheets.
The following table presents ASB’s derivative financial instruments and the amount and location of the net gains or losses recognized in ASB’s statements of income:
Derivative Financial Instruments Not Designated as Hedging Instruments Location of net gains (losses) recognized in the Statements of IncomeThree months ended June 30Six months ended June 30
(in thousands)2024202320242023
Interest rate lock commitmentsMortgage banking income$(47)$62 $3 $79 
Forward commitmentsMortgage banking income18 46 23 33 
 $(29)$108 $26 $112 
Low-Income Housing Tax Credit (LIHTC). ASB’s unfunded commitments to fund its LIHTC investment partnerships were $87.2 million and $87.9 million at June 30, 2024 and December 31, 2023, respectively. These unfunded commitments were unconditional and legally binding and are recorded in other liabilities with a corresponding increase in other assets. As of June 30, 2024, 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 6 · 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’s initial termination date was May 14, 2026. The $200 million Hawaiian Electric Facility’s initial termination date was May 13, 2022, but 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.
On April 21, 2023, HEI and Hawaiian Electric executed Amendment No. 1 to the Credit Facilities (Amendment). The Amendment was executed to reflect the transition from the London Inter-Bank Offered Rate to the Term Secured Overnight Financing Rate (SOFR) as the benchmark interest rate for non-Alternate Base Rate (ABR) Loans under the Credit Facilities.
On May 14, 2023, HEI and Hawaiian Electric exercised their first of two, one-year extensions to the commitment termination date with eight of the nine financial institutions to extend the Credit Facilities to May 14, 2027. The committed capacities under the HEI Facility and Hawaiian Electric Facility are $175 million and $200 million, respectively, through May 14, 2026, and step down to approximately $157 million and $180 million, respectively, through May 14, 2027.
After multiple downgrades of the Companies’ credit ratings to ratings below investment grade by Fitch, Moody’s and S&P due to the Maui windstorm and wildfires, on August 15, 2023, HEI made an initial $2.5 million draw on its $175 million existing revolving credit facility to repay maturing commercial paper. By August 23, 2023, HEI drew its remaining and Hawaiian Electric drew its full committed capacity on their respective existing revolving credit facilities, totaling $175 million and $200 million, respectively. The draws were made to provide access to liquidity and support the
54

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Company’s restoration efforts on Maui. The cash proceeds were primarily invested in highly liquid short-term investments and used for general corporate purposes.
Under the HEI and Hawaiian Electric Intercompany Borrowing and Investment Policy effective January 1, 2020 (the Intercompany Borrowing Policy), HEI has committed to make revolving short-term loans to Hawaiian Electric pursuant to the terms set forth in the standing commitment letter dated December 8, 2023 (the 2023 Commitment Letter). For loans that mature on or before December 6, 2024, the 2023 Commitment Letter provides a borrowing limit of $75 million outstanding at any time and the applicable interest rate. Hawaiian Electric currently has no borrowings under the Intercompany Borrowing Policy and the 2023 Commitment Letter.
Asset-backed lending facility credit agreement. On May 17, 2024, Hawaiian Electric, through a special-purpose subsidiary, entered into an asset-based lending facility (ABL Facility) credit agreement (ABL Credit Facility Agreement) with several banks, which, subject to the limitations and conditions set forth in such agreement, including approval by the PUC, allows borrowings of up to $250 million on a revolving basis using certain accounts receivable as collateral. Hawaiian Electric filed an application with the PUC for approval to (i) sell accounts receivable, and (ii) establish a long-term credit facility. The first approval would allow the ABL Credit Facility Agreement to become effective for 364 days and the second approval would extend the term of the ABL Credit Facility Agreement from 364 days to three years. The ABL Credit Facility Agreement has an initial term of 364 days, with an automatic extension to three years upon receipt of the second PUC approval, with three separate options to extend one additional year, subject to the consent of the lenders. On June 27, 2024, Hawaiian Electric received the first approval from the PUC for the ABL Credit Facility Agreement that allows short-term borrowings of up to $250 million, subject to the availability of a sufficient borrowing base of eligible receivables. Per the parties’ proposed stipulated procedural schedule, the second PUC decision is expected on October 30, 2024. The ABL Facility became effective on July 24, 2024.
Changes in debt. As of June 30, 2024, the Company and Hawaiian Electric were in compliance with all applicable financial covenants.
Mahipapa non-recourse loan. In March 2024, a fire destroyed the cooling tower at the Mahipapa facility on Kauai. The fire was ignited from a vendor’s welding activities being performed on the cooling tower during its scheduled maintenance. The plant is currently shut down while repairs are being performed. As a result, on June 26, 2024, the lender granted Mahipapa a deferral of two scheduled (July 2024 and September 2024) principal and interest payments totaling $3 million. The deferred payments will be repaid in quarterly payments commencing in March 2025. Mahipapa will re-commence debt payments in December 2024.



55

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Note 7 · Shareholders' equity
Accumulated other comprehensive income/(loss).  Changes in the balances of each component of accumulated other comprehensive income/(loss) (AOCI) were as follows:
HEI ConsolidatedHawaiian Electric Consolidated
 (in thousands) Net unrealized gains (losses) on securities Unrealized gains (losses) on derivativesRetirement benefit plansAOCIAOCI-Retirement benefit plans
Balance, December 31, 2023$(282,963)$1,638 $(8,025)$(289,350)$2,849 
Current period other comprehensive income (loss)(8,901)670 24 (8,207)(95)
Balance, June 30, 2024$(291,864)$2,308 $(8,001)$(297,557)$2,754 
Balance, December 31, 2022$(328,904)$1,991 $(9,115)$(336,028)$2,861 
Current period other comprehensive income (loss)12,987 (245)137 12,879 (89)
Balance, June 30, 2023$(315,917)$1,746 $(8,978)$(323,149)$2,772 

Reclassifications out of AOCI were as follows:
 Amount reclassified from AOCIAffected line item in the
 Statements of Income / Balance Sheets
Three months ended June 30Six months ended June 30
(in thousands)2024202320242023
HEI consolidated
Amortization of unrealized holding losses on held-to-maturity securities
$3,288 $3,689 $6,374 $7,366 Bank revenues
Net realized gains on derivatives qualifying as cash flow hedges
(51)(48)(99)(96)Interest expense
Retirement benefit plans:     
Amortization of prior service credit and net gains recognized during the period in net periodic benefit cost
(445)(357)(894)(714)
See Note 9 for additional details
Impact of D&Os of the PUC included in regulatory assets459 426 918 851 
See Note 9 for additional details
Total reclassifications$3,251 $3,710 $6,299 $7,407  
Hawaiian Electric consolidated
Retirement benefit plans:   
Amortization of prior service credit and net gains recognized during the period in net periodic benefit cost
$(505)$(470)$(1,013)$(940)
See Note 9 for additional details
Impact of D&Os of the PUC included in regulatory assets459 426 918 851 
See Note 9 for additional details
Total reclassifications$(46)$(44)$(95)$(89) 

56

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - (Unaudited) continued
Note 8 · Revenues
The following tables disaggregate revenues by major source, timing of revenue recognition, and segment:
Three months ended June 30, 2024Six months ended June 30, 2024
(in thousands) Electric  utilityBankOtherTotalElectric  utilityBankOtherTotal
Revenues from contracts with customers
Electric energy sales - residential$244,539 $— $— $244,539 $486,061 $— $— $486,061 
Electric energy sales - commercial251,482 — — 251,482 493,250 — — 493,250 
Electric energy sales - large light and power280,940 — — 280,940 552,027 — — 552,027 
Electric energy sales - other 4,609 — — 4,609 9,555 — — 9,555 
Bank fees— 12,723 — 12,723 — 25,238 — 25,238 
Other sales— — 2,964 2,964 — — 6,270 6,270 
Total revenues from contracts with customers781,570 12,723 2,964 797,257 1,540,893 25,238 6,270 1,572,401 
Revenues from other sources
Regulatory revenue(486)— — (486)20,704 — — 20,704 
Bank interest and dividend income— 86,178 — 86,178 — 174,113 — 174,113 
Other bank noninterest income— 3,042 — 3,042 — 7,736 — 7,736 
Other11,247 — 122 11,369 19,312 — 252 19,564 
Total revenues from other sources10,761 89,220 122 100,103 40,016 181,849 252 222,117 
Total revenues$792,331 $101,943 $3,086 $897,360 $1,580,909 $207,087 $6,522 $1,794,518 
Timing of revenue recognition
Services/goods transferred at a point in time$— $12,723 $— $12,723 $— $25,238 $— $25,238 
Services/goods transferred over time781,570 — 2,964 784,534 1,540,893 — 6,270 1,547,163 
Total revenues from contracts with customers$781,570 $12,723 $2,964 $797,257 $1,540,893 $25,238 $6,270 $1,572,401 
Three months ended June 30, 2023Six months ended June 30, 2023
(in thousands) Electric  utilityBankOtherTotalElectric  utilityBankOtherTotal
Revenues from contracts with customers
Electric energy sales - residential
$239,867 $— $— $239,867 $495,417 $— $— $495,417 
Electric energy sales - commercial
250,108 — — 250,108 504,578 — — 504,578 
Electric energy sales - large light and power
279,811 — — 279,811 570,789 — — 570,789 
Electric energy sales - other4,483 — — 4,483 9,940 — — 9,940 
Bank fees— 12,281 — 12,281 — 24,303 — 24,303 
Other sales— — 4,438 4,438 — — 8,345 8,345 
Total revenues from contracts with customers774,269 12,281 4,438 790,988 1,580,724 24,303 8,345 1,613,372 
Revenues from other sources
Regulatory revenue9,039 — — 9,039 24,643 — — 24,643 
Bank interest and dividend income
— 81,741 — 81,741 — 161,220 — 161,220 
Other bank noninterest income— 2,863 — 2,863 — 5,219 — 5,219 
Other10,883 — 171 11,054 19,185 — 283 19,468 
Total revenues from other sources19,922 84,604 171 104,697 43,828 166,439 283 210,550 
Total revenues$794,191 $96,885 $4,609 $895,685 $1,624,552 $190,742 $8,628 $1,823,922 
Timing of revenue recognition
Services/goods transferred at a point in time
$— $12,281 $— $12,281 $— $24,303 $— $24,303 
Services/goods transferred over time
774,269 — 4,438 778,707 1,580,724 — 8,345 1,589,069 
Total revenues from contracts with customers$774,269 $12,281 $4,438 $790,988 $1,580,724 $24,303 $8,345 $1,613,372 
There are no material contract assets or liabilities associated with revenues from contracts with customers existing at December 31, 2023 or as of June 30, 2024. 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.
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As of June 30, 2024, 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 9 · Retirement benefits
Defined benefit pension and other postretirement benefit plans information.  The Company contributed $3 million ($3 million by the Utilities) to its pension and other postretirement benefit plans during the first six months of 2024, compared to $4 million ($4 million by the Utilities) in the first six months of 2023. The Company’s current estimate of total contributions to its pension and other postretirement benefit plans in 2024 is comparable to 2023 at $8 million ($8 million by the Utilities). In addition, in 2024, comparable to 2023, the Company expects to pay directly $3 million ($1 million by the Utilities) of benefits.
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 June 30Six months ended June 30
 Pension benefitsOther benefitsPension benefitsOther benefits
(in thousands)20242023202420232024202320242023
HEI consolidated
Service cost$11,265 $11,396 $282 $343 $22,529 $22,792 $563 $687 
Interest cost26,506 25,622 1,867 2,157 53,012 51,243 3,734 4,314 
Expected return on plan assets(35,982)(35,197)(3,487)(3,405)(71,964)(70,392)(6,972)(6,810)
Amortization of net prior period gain— — — (219)— — — (438)
Amortization of net actuarial (gain)/losses111 189 (712)(449)222 377 (1,425)(898)
Net periodic pension/benefit cost (return)1,900 2,010 (2,050)(1,573)3,799 4,020 (4,100)(3,145)
Impact of PUC D&Os18,089 18,133 1,887 1,424 36,179 36,266 3,775 2,849 
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)$19,989 $20,143 $(163)$(149)$39,978 $40,286 $(325)$(296)
Hawaiian Electric consolidated
Service cost$10,916 $11,018 $278 $340 $21,832 $22,037 $556 $680 
Interest cost24,627 23,699 1,779 2,063 49,254 47,397 3,558 4,126 
Expected return on plan assets(33,775)(32,971)(3,434)(3,354)(67,552)(65,943)(6,868)(6,707)
Amortization of net prior period gain— — — (218)— — — (436)
Amortization of net actuarial (gain)/losses11 18 (694)(433)23 37 (1,388)(867)
Net periodic pension/benefit cost (return)1,779 1,764 (2,071)(1,602)3,557 3,528 (4,142)(3,204)
Impact of PUC D&Os18,089 18,133 1,887 1,424 36,179 36,266 3,775 2,849 
Net periodic pension/benefit cost (return) (adjusted for impact of PUC D&Os)$19,868 $19,897 $(184)$(178)$39,736 $39,794 $(367)$(355)
HEI consolidated recorded retirement benefits expense of $23 million ($23 million by the Utilities) in the first six months of 2024 and $22 million ($22 million by the Utilities) in the first six months of 2023 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 six months of 2024 and 2023, the Company’s expenses for its defined contribution plans under the Hawaiian Electric Industries Retirement Savings Plan (HEIRSP) and the ASB 401(k) Plan were $5.8 million and $4.2 million, respectively, and cash contributions were $5.8 million and $5.0 million, respectively. For the first six months of 2024 and 2023, the Utilities’ expenses and cash contributions for its defined contribution plan under the HEIRSP were $3.5 million and $2.6 million, respectively.
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Note 10 · Share-based compensation
Under the 2010 Equity and Incentive Plan, as amended and restated effective February 9, 2024 (EIP), HEI can issue shares of common stock as incentive compensation to non-employee directors and selected employees and consultants in the form of stock options, stock appreciation rights, restricted shares, restricted stock units, performance shares and other share-based and cash-based awards.
As of June 30, 2024, approximately 2.5 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 0.9 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 June 30, 2024, there were 168,177 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 June 30Six months ended June 30
(in millions)2024202320242023
HEI consolidated
Share-based compensation expense 1
$1.8 $3.9 $3.1 $5.9 
Income tax benefit0.2 0.8 0.3 1.1 
Hawaiian Electric consolidated
Share-based compensation expense 1
0.8 1.1 1.2 1.7 
Income tax benefit0.1 0.2 0.1 0.4 
1    For the three and six months ended June 30, 2024 and 2023, the Company has not capitalized any share-based compensation.
Stock awards. HEI granted HEI common stock to nonemployee directors under the 2011 Director Plan as follows:
Three months ended June 30Six months ended June 30
(dollars in millions)2024202320242023
Shares granted— 38,941 — 40,450 
Fair value$— $1.4 $— $1.5 
Income tax benefit— 0.4 — 0.4 
The number of shares issued to each nonemployee director of HEI, Hawaiian Electric and ASB is determined based on the closing price of HEI common stock on the grant date.
Restricted stock units.  Information about HEI’s grants of restricted stock units was as follows:
Three months ended June 30Six months ended June 30
 2024202320242023
Shares(1)Shares(1)Shares(1)Shares(1)
Outstanding, beginning of period90,903 $42.11 202,133 $41.25 189,024 $41.23 182,528 $39.75 
Granted— — — — — — 100,088 42.41 
Vested(1,034)44.31 (1,035)44.31 (98,084)40.43 (81,112)39.37 
Forfeited— — (1,968)42.49 (1,071)41.97 (2,374)41.79 
Outstanding, end of period89,869 $42.08 199,130 $41.22 89,869 $42.08 199,130 $41.22 
Total weighted-average grant-date fair value of shares granted (in millions)$— $— $— $4.2 
(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 six months ended June 30, 2024 and 2023, total restricted stock units and related dividends that vested had a fair value of $1.4 million and $3.7 million, respectively, and the related tax benefits were $0.3 million and $0.8 million, respectively.
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As of June 30, 2024, there was $2.8 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 1.4 years.
Long-term incentive plan payable in stock.  The 2022-24, 2023-25 and 2024-26 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 2022-24 performance period, 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 and 2024-26 performance periods), 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), carbon emissions reduction, Hawaiian Electric’s net income growth, credit rating and public safety, 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 June 30Six months ended June 30
 2024202320242023
Shares(1)Shares(1)Shares(1)Shares(1)
Outstanding, beginning of period109,643 $33.82 80,006 $50.27 76,477 $50.11 71,574 $47.67 
Granted — — — — 62,152 17.28 27,123 55.98 
Vested (issued or unissued and cancelled)— — — — (28,577)41.12 (18,691)48.62 
Forfeited(381)55.66 (722)48.92 (790)55.64 (722)48.92 
Outstanding, end of period109,262 $33.75 79,284 $50.28 109,262 $33.75 79,284 $50.28 
Total weighted-average grant-date fair value of shares granted (in millions)$— $— $1.1 $1.5 
(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:
20242023
Risk-free interest rate4.25 %4.19 %
Expected life in years33
Expected volatility52.5 %33.1 %
Range of expected volatility for Peer Group
12.3% to 52.5%
28.7% to 38.8%
Grant-date fair value (per share)
$17.28$55.98
There were no share-based LTIP awards linked to TSR with a vesting date in 2024 and 2023.
As of June 30, 2024, there was $1.8 million of total unrecognized compensation cost related to the nonvested performance awards payable in shares linked to TSR. The cost is expected to be recognized over a weighted-average period of 1.9 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 June 30Six months ended June 30
2024202320242023
 Shares(1)Shares (1)Shares(1)Shares(1)
Outstanding, beginning of period574,744 $23.68 355,310 $38.87 327,085 $39.44 309,589 $39.50 
Granted — — — — 362,963 13.09 108,499 42.41 
Vested — — — — (113,118)34.93 (62,778)48.07 
Increase above target (cancelled)(11,407)42.37 6,001 36.08 (11,953)42.32 6,001 36.08 
Forfeited(1,525)42.07 (3,834)43.53 (3,165)42.06 (3,834)43.53 
Outstanding, end of period561,812 $23.25 357,477 $38.78 561,812 $23.25 357,477 $38.78 
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)$— $— $4.8 $4.6 
(1)    Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.
For the six months ended June 30, 2024 and 2023, total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $1.7 million and $2.9 million, respectively, and the related tax benefits were $0.4 million and $0.6 million, respectively.
As of June 30, 2024, there was $6.5 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 1.9 years.
Note 11 · Income taxes
The Company’s and the Utilities’ effective tax rates (combined federal and state income tax rates) for the six months ended June 30, 2024 were 26% tax benefit. These rates differed from the combined statutory rates, due primarily to the accrual of the Utilities’ best estimate of payments to settle Wildfire tort-related claims which resulted in a substantial pretax loss, 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%, the tax benefits derived from the low income housing tax credit investments and the non-taxability of the bank-owned life insurance income.
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. In May 2024, the IRS proposed a disallowance of $8.5 million from the $12.9 million of additional R&D tax credits claimed for the 2016 to 2018 tax years. The Company is currently reviewing this proposal to determine its next steps.
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, the Company does 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 in tax year 2023. The Company is exploring clean energy tax incentives included in the IRA.

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Note 12 · Cash flows
Six months ended June 3020242023
(in millions)  
Supplemental disclosures of cash flow information  
HEI consolidated
Interest paid to non-affiliates, net of amounts capitalized$133 $75 
Income taxes paid (including refundable credits)18 28 
Income taxes refunded (including refundable credits)— 1 
Hawaiian Electric consolidated
Interest paid to non-affiliates44 33 
Income taxes paid (including refundable credits)27 38 
Income taxes refunded (including refundable credits)— 2 
Supplemental disclosures of noncash activities  
HEI consolidated
Property, plant and equipment
   Estimated fair value of noncash contributions in aid of construction (investing)
7 6 
   Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)
26 50 
Right-of-use assets obtained in exchange for finance lease obligations (financing) 108 76 
Right-of-use assets obtained in exchange for operating lease obligations (investing)1 1 
Common stock issued (gross) for director and executive/management compensation (financing)1
3 8 
Obligations to fund low income housing investments (investing)— 7 
Loans transferred from held for investment to held for sale (investing)29 72 
Transfer of retail repurchase agreements to deposit liabilities (financing)— 98 
Hawaiian Electric consolidated
Electric utility property, plant and equipment
   Estimated fair value of noncash contributions in aid of construction (investing)
7 6 
   Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)
25 49 
   Right-of-use assets obtained in exchange for finance lease obligations (financing)107 76 
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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Note 13 · 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:
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
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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 certificates. 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, repurchase agreements and other bank borrowings, fair value is estimated using quantitative discounted cash flow models that require the use of interest rate inputs that are currently offered for advances, repurchase agreements and other bank borrowings 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 marketplace 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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The following table presents the carrying or notional amount, fair value and placement in the fair value hierarchy of the Company’s financial instruments.
Estimated fair value
(in thousands)Carrying or notional amountQuoted prices in
active markets
for identical assets
 (Level 1)		Significant
 other observable
 inputs
 (Level 2)		Significant
unobservable
inputs
 (Level 3)		Total
June 30, 2024     
Financial assets     
HEI consolidated
Available-for-sale investment securities$1,061,687 $— $1,047,611 $14,076 $1,061,687 
Held-to-maturity investment securities1,179,182 — 1,058,691 — 1,058,691 
Loans, net5,977,249 — 13,899 5,494,566 5,508,465 
Mortgage servicing rights7,906 — — 17,862 17,862 
Derivative assets41,122 5 1,817 — 1,822 
Financial liabilities    
HEI consolidated
Deposit liabilities - time certificates
1,048,825 — 1,037,878 — 1,037,878 
Other bank borrowings520,000 — 518,083 — 518,083 
Long-term debt, net—other than bank
2,838,224 — 2,124,907 — 2,124,907 
Hawaiian Electric consolidated
Long-term debt, net 1,934,747 — 1,380,338 — 1,380,338 
December 31, 2023     
Financial assets     
HEI consolidated
Available-for-sale investment securities$1,136,439 $— $1,122,081 $14,358 $1,136,439 
Held-to-maturity investment securities1,201,314 — 1,103,668 — 1,103,668 
Loans, net6,121,606 — 15,176 5,723,823 5,738,999 
Mortgage servicing rights8,169 — — 18,722 18,722 
Derivative assets16,880 — 1,058 — 1,058 
Financial liabilities    
HEI consolidated
Deposit liabilities - time certificates
1,063,907 — 1,053,101 — 1,053,101 
Other bank borrowings750,000 — 747,508 — 747,508 
Long-term debt, net—other than bank2,842,429 — 2,133,225 — 2,133,225 
Derivative liabilities28,449 18 303 — 321 
Hawaiian Electric consolidated
Long-term debt, net 1,934,277 — 1,385,025 — 1,385,025 
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Fair value measurements on a recurring basis.  Assets and liabilities measured at fair value on a recurring basis were as follows:
June 30, 2024December 31, 2023
 Fair value measurements usingFair value measurements using
(in thousands)Level 1Level 2Level 3Level 1Level 2Level 3
Available-for-sale investment securities (bank segment)      
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies$— $1,005,801 $— $— $1,077,168 $— 
U.S. Treasury and federal agency obligations— 8,883 — — 12,010 — 
Corporate bonds— 32,927 — — 32,903 — 
Mortgage revenue bonds— — 14,076 — — 14,358 
 $— $1,047,611 $14,076 $— $1,122,081 $14,358 
Derivative assets     
Interest rate lock commitments (bank segment)1
$— $89 $— $— $86 $— 
Forward commitments (bank segment)1
5 — — — — — 
Interest rate swap (Other segment)2
— 1,728 — — 972 — 
 $5 $1,817 $— $— $1,058 $— 
Derivative liabilities
Forward commitments (bank segment)1
$— $— $— $18 $— $— 
Interest rate swap (Other segment)2
— — — — 303 — 
$— $— $— $18 $303 $— 
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 six months ended June 30, 2024 and 2023.
The changes in Level 3 assets and liabilities measured at fair value on a recurring basis were as follows:
Three months ended June 30Six months ended June 30
Mortgage revenue bonds2024202320242023
(in thousands)
Beginning balance$14,217 $14,766 $14,358 $14,902 
Principal payments received(141)(136)(282)(272)
Purchases— — — — 
Unrealized gain (loss) included in other comprehensive income— — — — 
Ending balance$14,076 $14,630 $14,076 $14,630 
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 June 30, 2024, the weighted average discount rate was 5.65%, which was derived by incorporating a credit spread over the one month SOFR. 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 June 30, 2024 and December 31, 2023, there were no financial instruments measured at fair value on a nonrecurring basis.
For the six months ended June 30, 2024 and 2023, 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 2023 Form 10-K and should be read in conjunction with such discussion and the 2023 annual consolidated financial statements of HEI and Hawaiian Electric and notes thereto included in HEI’s and Hawaiian Electric’s 2023 Form 10-K, as well as the quarterly condensed consolidated financial statements and notes thereto included in Item 1 of this Form 10-Q.
HEI consolidated
Recent developments. On August 8, 2023, a number of brush fires in the West Maui (Lahaina) and Upcountry Maui areas caused widespread property damage, including damage to property of the Utilities, and 102 confirmed fatalities in Lahaina (the Maui windstorm and wildfires). The circumstances surrounding the Maui windstorm and wildfires are currently the subject of several investigations.
As of August 8, 2024, HEI and the Utilities have each been named in approximately 700 lawsuits related to the Maui windstorm and wildfires. These civil and class action lawsuits have been filed in the Maui and Oahu Circuit Courts against HEI, the Utilities, and other defendants, including the County of Maui, the State of Hawaii and related state entities, private landowners and developers, and telecommunications companies (collectively, tort-related legal claims). Two class actions are also pending in federal court. Most of these lawsuits allege that the defendants were responsible for, and/or negligent in failing to prevent or respond to the wildfires that led to the property destruction and loss of life. Other claims include, among other things, personal injury, wrongful death, emotional distress and inverse condemnation. One lawsuit asserting similar theories and claims was filed by the County of Maui against HEI and the Utilities, one lawsuit was filed by Spectrum Oceanic, LLC against HEI and the Utilities and other defendants, and other lawsuits were filed by approximately 160 subrogation insurers against HEI, the Utilities, a private landowner, and telecommunications companies. Additional lawsuits may be filed against the Company and other defendants in the future. The plaintiffs seek to recover damages and other costs, including punitive damages. Defendants have asserted cross-claims against one another for indemnification, contribution, and subrogation. In addition to the tort-related legal claims, the Company is also involved in a securities class action and six shareholder lawsuits. See Note 2 of the Condensed Consolidated Financial Statements.
On August 2, 2024, attorneys representing the individual and class plaintiffs reached an agreement in principle with all defendants to settle all of their tort-related legal claims in the litigation arising out of the Maui windstorm and wildfires. HEI attached the agreement in principle to the Form 8-K that it filed on August 5, 2024. The agreement in principle was the product of a mediation process that lasted several months and remains subject to final documentation and court approval. Under the agreement in principle, HEI and Hawaiian Electric, the State of Hawaii, the County of Maui, Kamehameha Schools, West Maui Land Co., Hawaiian Telcom and Spectrum/Charter Communications have agreed to contribute a total of approximately $4.04 billion to one or more funds that would pay the claims of those who filed lawsuits in state and federal courts, or who may have claims but have not yet filed lawsuits, in connection with the Maui windstorm and wildfires.
The agreement in principle does not resolve claims with insurers who have asserted subrogation claims in separate lawsuits, and such insurers are not parties to the agreement in principle. However, the agreement in principle provides that the definitive settlement agreement must provide for resolution of all subrogation claims by insurers that have been or could be brought against defendants arising out of the Maui windstorm and wildfires for no additional consideration. The agreement in principle includes a condition to the defendants’ obligations providing that within 90 days from its execution, either (a) insurers that have brought claims arising out of the Maui windstorm and wildfires enter into a written agreement that provides for releases of all claims against the defendants, or (b) that a trial court enters an order providing that if the final definitive agreement between the plaintiffs and the defendants becomes effective, then those same insurers’ exclusive remedy for any claims against the defendants would be limited to asserting liens against the settlement amounts obtained by the individual plaintiffs (so long as the order becomes final and unappealable within nine months from its date of issuance or, in that time period, those same insurers agree to provide the requisite releases).
Of the total settlement amount, HEI and Hawaiian Electric would contribute a total of $1.99 billion, which includes as a credit towards that amount the $75 million previously contributed for the One ‘Ohana Initiative, to be paid in four equal annual installments, with the first installment expected to be made no earlier than mid-2025. While the agreement in principle remains subject to final documentation and court approval, the Utilities have accrued their best estimate of the loss of approximately $1.71 billion, which represents the best estimate of the lump sum amount to settle claims with the plaintiffs as of June 30, 2024. The agreement in principle contains no admission of any liability by HEI or the Utilities and reflects the collective efforts of the State, HEI and the Utilities, and other defendants to seek a comprehensive resolution of the litigation arising out of the Maui windstorm and wildfires. The Utilities will seek insurance recovery to partially mitigate the potential financial impact; however, the timing and amount of any insurance recoveries are not determinable at this time.
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On April 16, 2024, the County of Maui Department of Fire and Public Safety (MFD) released its After-Action Report (AAR) on the Maui windstorm and wildfires, the purpose of which was to enable future enhancements to mitigate the impact of future similar major events. The AAR identified 17 issues that the MFD faced during the Maui windstorm and wildfires or needs to address and provided 111 recommendations to consider for addressing these challenges. The issues and recommendations focus on the MFD. Some of the key areas for improvement include addressing the lack of apparatus, personnel and fire stations and the need for mutual aid and communication programs. The AAR did not address the cause or origin of the fires.
On April 17, 2024, the Hawaii Attorney General released the first of three reports that it plans on releasing regarding its investigation into the Maui windstorm and wildfires (the first AG report). The first AG report chronologically details the major events and response efforts related to the Maui windstorm and wildfires, with a focus on the events concerning the Lahaina area between 2:55 p.m. on August 8, 2023, and 8:30 a.m. on August 9, 2023. It did not address the cause or origin of the fires. The second planned report is expected to analyze the timeline and facts of the Maui windstorm and wildfires and the third planned report is expected to provide recommendations to address future events.
In the 2024 Hawaii Legislative session, bills were proposed (1) to create a statewide wildfire relief fund to compensate participating property owners, insurers, and government entities for damages resulting from future catastrophic wildfires; (2) to establish a process for the PUC to review and approve risk-based wildfire protection plans for electric utilities; and (3) to authorize the PUC to issue bonds securitized by future rate payments to pay for the risk-based wildfire protection plans and certain other costs related to catastrophic wildfires. The bills passed all committees and made it to the conference committee—the last stop in the Hawaii Legislature before the final reading—but they did not progress out of conference committee. Thereafter, Governor Josh Green announced the creation of a Hawaii Climate Advisory Team, which the Governor’s office stated in a news release would “recommend steps to create a durable fund to mitigate the impacts of dynamic climate change and to develop a fair and comprehensive structure to resolve claims related to future disasters” including “develop[ing] a customized go-forward fund structure and related claims settlement mechanics.” As to the wildfire mitigation plan and securitization bill, the Governor’s office stated in a letter that Hawaii’s “energy future and the stability and reliability of the utility is riding on this bill”; and later stated to news outlets that the Governor plans to continue negotiations and discussions with the goal of having the bill reintroduced at the next Hawaii legislative session in 2025.
In the second quarter of 2024, economic conditions in Hawaii remained stable with seasonally adjusted unemployment rate at 2.9% for June 2024 and the average daily passenger count was 1.7% lower than the comparable period in the prior year. While economic conditions remained stable during the quarter, the Utility’s kWh sales in the second quarter of 2024 were down by 1.2%, compared to the second quarter of 2023 due to a decrease in Maui sales from the Maui windstorm and wildfires and 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 4 of the Condensed Consolidated Financial Statements for a discussion of the decoupling mechanism.
At the Bank, net interest margin for the second quarter of 2024 was 2.79% as compared to 2.75% for the prior quarters ended March 31, 2024 and June 30, 2023. The increase in net interest margin was primarily due to the continued benefit from the sale of investment securities in the fourth quarter 2023 which was used to pay down maturing higher costing liabilities during the first quarter 2024. In addition, yields from earning assets increased primarily due to higher loan yields.
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. At June 30, 2024, core deposits were down approximately 1.3% from year end 2023, resulting in an increase in 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 and its deposit mix as customers move funds into higher costing certificate of deposits, which in turn will affect net interest income and net interest margin.
Since its peak in June 2022, monthly inflation rates have decreased as reflected in the U.S. Consumer Price Index (CPI). Although the inflation rate, as measured by CPI, has been cooling off from its 2022 peak, the rate is still at a moderately-high level of 3.0% as of June 30, 2024 and 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 Utilities 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 intent and ability to hold the securities till maturity and recover
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its full investment. At June 30, 2024, the unrealized losses on HTM securities not recorded to other comprehensive losses was approximately $88 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.

RESULTS OF OPERATIONS
Three months ended June 30,%
(in thousands)20242023changePrimary reason(s)*
Revenues$897,360 $895,685 — 
Increase for the bank segment, offset by decreases for the electric utility and “other” segments.
Operating income (loss)
(1,718,975)92,979 NM
Decrease for the electric utility (includes wildfire tort-related claims of $1.71 billion) and bank (includes goodwill impairment of $82.2 million) segments and higher operating loss for the “other” segment. See below for HEI Consolidated Maui windstorm and wildfires costs, net.
Net income (loss) for common stock
(1,295,484)54,610 NM
Lower net income for the electric utility and bank segments and higher net loss for the “other” segment. See below for HEI Consolidated Maui windstorm and wildfires costs, net and effective tax rate explanation.

Six months ended June 30%
(in thousands)20242023changePrimary reason(s)*
Revenues$1,794,518 $1,823,922 (2)
Decreases for the electric utility and “other” segments, partly offset by an increase for the bank segment.
Operating income (loss)
(1,642,556)186,497 NM
Decrease for the electric utility (includes wildfire tort-related claims of $1.71 billion) and bank (includes goodwill impairment of $82.2 million) segments and higher operating loss for the “other” segment. See below for HEI Consolidated Maui windstorm and wildfires costs, net.
Net income (loss) for common stock
(1,253,362)109,331 NM
Lower net income for the electric utility and bank segments and higher net loss for the “other” segment. See below for HEI Consolidated Maui windstorm and wildfires costs, net and effective tax rate explanation.
*     Also, see segment discussions which follow.
NM - Not meaningful.
The Company’s effective tax rates for the second quarter and first six months of 2024 were 26% tax benefit and for the second quarter and first six months of 2023 were 21% tax expense. The effective tax rates for the second quarter and for the first six months of 2024 was higher than the comparable period due to the substantial pre-tax loss resulting from the Utilities’ accrual of the loss contingencies related to the tort-related claims because the impact of permanent items had a smaller impact on the effective rate.
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For the three and six months ended June 30, 2024, the Company’s incremental expenses related to the Maui windstorm and wildfires described in Note 2 of the Condensed Consolidated Financial Statements, were as follows:
Three months ended June 30, 2024
(in thousands)
Electric utility
Bank
Other segment
HEI Consolidated
Maui windstorm and wildfires related expenses:
Legal expenses$17,613 $819 $6,568 $25,000 
Outside services expense
997 382 399 1,778 
Provision for credit losses
— (800)— (800)
Wildfire tort-related claims1,712,000 
2
— — 1,712,000 
Other expense
5,741 
3
51 1,139 6,931 
Interest expense2,524 — 862 3,386 
Total Maui windstorm and wildfires related expenses
1,738,875 452 8,968 1,748,295 
Insurance recoveries
(16,379)— (2,496)(18,875)
Deferral treatment approved by the PUC1
(7,656)— 

— (7,656)
Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment
$1,714,840 $452 $6,472 $1,721,764 
Six months ended June 30, 2024
(in thousands)
Electric utility
Bank
Other segment
HEI Consolidated
Maui windstorm and wildfires related expenses:
Legal expenses$28,348 $902 $10,777 $40,027 
Outside services expense
1,781 2,007 737 4,525 
Provision for credit losses
— (2,300)— (2,300)
Wildfire tort-related claims1,712,000 
2
— — 1,712,000 
Other expense
14,882 
3
(266)1,334 15,950 
Interest expense6,431 — 1,780 8,211 
Total Maui windstorm and wildfires related expenses
1,763,442 343 14,628 1,778,413 
Insurance recoveries
(26,348)— (5,104)(31,452)
Deferral treatment approved by the PUC1
(15,554)— 

— (15,554)
Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment
$1,721,540 $343 $9,524 $1,731,407 
1    Related to the PUC’s order, received on December 27, 2023, approving deferred accounting treatment for the Utilities’ incremental non-labor expenses related to the August 2023 Maui windstorm and wildfires. Amounts were reclassified to a regulatory asset. See Note 2 of the Condensed Consolidated Financial Statements.
2    Represents the Utilities’ best estimate of the losses related to a proposed settlement of all wildfire tort-related legal claims and cross claims as of June 30, 2024. See Note 2 of the Condensed Consolidated Financial Statements.
3    Includes $2.8 million and $9.5 million pursuant to an agreement to settle indemnification claims asserted by the State of Hawaii, for the three and six months ended June 30, 2024, respectively. See Note 2 of the Condensed Consolidated Financial Statements.
Note: Other segment Maui windstorm and wildfires related expenses - legal, outside services and other are included in “Expenses-Other” and interest expense is included “Interest expense, net—other than on deposit liabilities and other bank borrowings” on the HEI and subsidiaries Condensed Consolidated Statements of Income. See Electric utility and Bank sections below for more detail.
Since the Maui windstorm and wildfires on August 8, 2023 through June 30, 2024, HEI and its subsidiaries have incurred approximately $1.9 billion of Maui windstorm and wildfires expenses, including the Utilities’ best estimate of the losses related to a proposed settlement of all wildfire tort-related legal claims and cross claims and the One ‘Ohana Initiative contribution. Certain of these costs are reimbursable under excess liability insurance, professional liability and directors and officers liability insurance policies. As of June 30, 2024, HEI and its subsidiaries have approximately $41 million, $25 million and $133 million of insurance coverage remaining under the excess liability, professional liability and directors and officers liability policies, respectively, after deducting applicable retention amounts and estimated insurance recoveries, including the One ‘Ohana
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Initiative contribution.
With the Company accruing its best estimate of the losses related to a proposed settlement of all wildfire tort-related legal claims and cross claims as of June 30, 2024, the Company still expects the Electric utility and HEI to continue to incur primarily legal expenditures in connection with the Maui windstorm and wildfires; however, the Company has partially mitigated the financial impact through insurance recoveries as well as the Utilities obtaining deferral treatment for incremental non-labor expense. At ASB, the lessening of loss uncertainties related to the Maui windstorm and wildfires have had a positive impact on its provision for credit losses, improving loss rates and lower loan portfolio balances.
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 second quarter, the average daily passenger count was 1.7% lower than the comparable period in the prior year. The recovery in total passenger counts from the low levels in 2020, which occurred under COVID-19 restrictions, thus far has been driven by domestic travelers, with international travelers, primarily Japan, remaining at lower levels. In the second quarter, international visitor arrivals (excluding Japan) have continued to increase at a modest pace, but is still 23.9% below 2019 levels. Due to the weak yen, Japanese visitors are 44% below 2019 levels.
Hawaii’s seasonally adjusted unemployment rate in June 2024 was 2.9%, which was higher compared to the June 2023 rate of 2.8%. The national unemployment rate in June 2024 was 4.1% compared to 3.6% in June 2023. According to the most recent forecast by UHERO, issued on May 10, 2024, job growth in the state will decrease to 0.8% for 2024 and 1.0% for 2025. The Maui windstorm and wildfires destroyed a majority of the businesses in Lahaina, but initial visitor recovery after the wildfires has proven to be somewhat stronger than initially expected. The labor market recovery on Maui was also stronger than expected, reflecting faster employment recovery and anticipated outflows from the labor force as some residents relocate off island. Accordingly, unemployment on Maui is predicted to average 5.6% in 2024, slightly receding to 4.6% by 2026.
Hawaii real estate activity through June 2024, as indicated by Oahu’s home resale market, resulted in an increase in the median sales price of 3.9% for condominiums and an increase of 6.7% for single-family homes compared to the same period in 2023, with the June median single-family home price of $1,120,000, below the record $1,153,500 set in May 2022. The number of closed sales decreased 24.5% for condominiums and increased 4.0% for single-family residential homes through the second quarter of 2024 compared to 2023.
Hawaii’s petroleum product prices relate to the crude oil in international markets. The price of crude oil has decreased about 6% over the same quarter in the prior year. While the fuel costs are below 2023’s peak, they remain elevated.
At its June 12, 2024 meeting, the Federal Open Market Committee (FOMC) decided to maintain the federal funds rate target range of 5.25% - 5.50%. The FOMC is still assessing plans to adjust its stance on monetary policy depending on the economic outlook to achieve maximum employment and inflation at the rate of 2 percent over the long run. The Federal Reserve stated that it will continue to reduce its holdings of Treasury securities and agency mortgage-backed securities.
UHERO forecasts full year 2024 real GDP growth of 1.5%, an increase in total visitor arrivals of 1.9%, an increase in real personal income of 0.9%, and an unemployment rate of 3.1%. The Maui visitor industry has been recovering faster than anticipated and international visitors to the state are gradually returning. Hawaii has seen strong visitor spending at the end of 2023, however real visitor spending is expected to soften, before stabilizing in 2025. The 2024 U.S. economy continues to expand supported by strong consumer spending, healthy job markets and progress on reducing inflation, which will help bring inflation into the Fed’s target range and achieve a “soft landing”.
See also “Recent Developments” in the “Electric utility” and “Bank” sections below for further discussion of the economic impact of recent events.
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“Other” segment.
 Three months ended June 30,
(in thousands)20242023Primary reason(s)
Revenues$3,086 $4,609 
The revenues for the second quarter of 2024 were lower than the comparable period in 2023 primarily due to lower sales at Pacific Current1 subsidiaries.
Operating loss(17,149)(5,514)
The second quarters of 2024 and 2023 include $4.0 million of operating loss and $0.6 million of operating income, respectively, from Pacific Current1. The higher operating loss is primarily due to lower Pacific Current asset performances mainly at Hamakua Energy and Mahipapa due to unexpected plant shut downs in the first quarter of 2024 as compared to the prior year period. Corporate expenses for the second quarter of 2024 were $7.1 million higher than the same period in 2023, primarily due to $5.6 million of Maui windstorm and wildfires related costs, net of insurance recovery for the second quarter of 2024.
Net loss (20,303)(10,893)
The net loss for the second quarter of 2024 was higher than the net loss for the second quarter of 2023 due to $0.3 million higher interest expense, net of interest income, primarily related to HEI’s August 2023 draw on the revolving credit facility as compared to the prior year period, and the same factors cited for the change in operating loss above. Also see effective tax rate explanations above.
 Six months ended June 30
(in thousands)20242023Primary reason(s)
Revenues$6,522 $8,628 
The revenues for the first six months of 2024 were lower than the comparable period in 2023 primarily due to lower sales at Pacific Current1 subsidiaries.
Operating loss(29,617)(11,391)
The first six months of 2024 and 2023 include $9.5 million and $0.5 million of operating loss, respectively, from Pacific Current1. The higher operating loss is primarily due to a $3.5 million impairment loss on assets damaged in a March 2024 fire at Mahipapa and lower Pacific Current asset performances mainly at Hamakua Energy and Mahipapa due to unexpected plant shut downs in the first quarter of 2024 as compared to the prior year period. Corporate expenses for the first six months of 2024 were $9.3 million higher than the same period in 2023, primarily due to $7.7 million of Maui windstorm and wildfires related costs, net of insurance recovery for the first six months of 2024.
Net loss (38,336)(21,743)
The net loss for the first six months of 2024 was higher than the net loss for the first six months of 2023 due to $1.7 million higher interest expense, net of interest income, primarily related to HEI’s August 2023 draw on the revolving credit facility as compared to the prior year period, and the same factors cited for the change in operating loss above. Also see effective tax rate explanations above.
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 on Hawaii Island 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 on Oahu and Kauai, 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.
In late February 2024, Hamakua Energy’s first combustion turbine (CT1) and its leased combustion turbine (leased CT) unexpectedly sustained damages resulting in a plant shut down on Hawaii Island. The Company is currently conducting an investigation into the root cause of the damages. Upon inspection of CT1, it was determined that the unit was not serviceable. Due to the generation capacity shortfall on Hawaii Island (refer to “System reliability” in “Recent developments” of the
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Hawaiian Electric’s MD&A below), and the extensive timeline and cost to overhaul CT1, management decided to retire and replace CT1. Due to the age of the unit, the net book value is immaterial. In April 2024, Hamakua Energy purchased a new combustion turbine and installed the unit in May 2024 at a total cost of approximately $8.3 million. The new CT1 was placed into service in June 2024. Pursuant to the lease pool program agreement, the leased CT was returned to the lessor. A new leased CT has been delivered and is expected to be placed into service in the third quarter of 2024. Hamakua Energy’s second combustion turbine (CT2) is currently in a scheduled overhaul which has incurred delays due to supply shortages. The CT2 overhaul is expected to be completed and the unit placed back into service in the fourth quarter of 2024.
In March 2024, a fire destroyed the cooling tower at the Mahipapa facility on Kauai. The fire was ignited from a vendor’s welding activities being performed on the cooling tower during its scheduled maintenance. As a result, the plant is currently shut down while repairs are being performed. Mahipapa recorded an impairment loss of $3.5 million in March 2024. The Company expects to complete its repairs and bring the facility back online in the third quarter of 2024. Mahipapa is currently working with its legal counsel and insurance company on seeking reimbursement of its losses related to damages sustained to its plant facilities.
FINANCIAL CONDITION
Liquidity and capital resources.  See “Credit and Capital Market Risk” in Item 1A. Risk Factors in HEI’s and Hawaiian Electric’s 2023 Form 10-K and in Item 1A. Risk Factors below.
In June 2024, the Utilities accrued estimated wildfire liabilities totaling approximately $1.71 billion (pre-tax) that are considered probable, related to the settlement of the Maui windstorm and wildfire tort-related legal claims (see Note 2 of the Condensed Consolidated Financial Statements). For the three and six months ended June 30, 2024, HEI and its subsidiaries incurred net losses of approximately $1.30 billion and $1.25 billion, respectively.
HEI and the Utilities’ future results of operations involve significant risks and uncertainties. Factors that could affect HEI’s and the Utilities’ future operating results and could cause actual results to vary materially from expectations include, but are not limited to, access to capital, ability to attract and retain key personnel, and pending or threatened litigation (including recent litigation noted above).
Management believes HEI and the Utilities’ current combined cash balance at June 30, 2024 of $213.1 million and the available capacity on the Utilities’ ABL facility will not be sufficient to fund its planned expenditures, which includes estimated payments to settle wildfire claims, through at least August 2025.
These conditions raise substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern within one year after the date that financial statements are issued. The ability to continue as a going concern is dependent primarily upon the Company’s ability to raise the capital necessary to fund the contribution to the settlement of wildfire tort claims while also meeting their obligations to repay their liabilities arising from normal business operations when they become due. The accompanying consolidated financial statements have been prepared on a basis which assumes HEI and the Utilities are a going concern and do not include any adjustments to reflect the possible future effects on the recoverability and classification of assets or the amounts and classifications of liabilities that may result from any uncertainty related to HEI’s and the Utilities’ ability to continue as a going concern. Such adjustments could be material.
HEI and the Utilities are currently working with their financial advisors on a financing plan to raise the capital necessary to fund the contribution to the settlement of wildfire tort claims. The Company expects to finance the settlement payments over time through a mix of debt, common equity, equity-linked securities or other potential options. While management believes the Company will be able to raise the necessary capital, there is no assurance that management’s plans will be successful. If the financing plans are unsuccessful, the Company may need to consider other strategic alternatives. See further discussion in Part II. Other Information—Item 1A. Risk Factors.
At the end of the quarter, HEI and Hawaiian Electric had no commercial paper outstanding. As of June 30, 2024, ASB’s unused FHLB borrowing capacity was approximately $1.5 billion and ASB had unpledged investment securities of $1.0 billion that were available to be used as collateral for additional borrowing capacity. At both June 30, 2024 and December 31, 2023, the total amount of available borrowing capacity (net of commercial paper outstanding) under the Company’s committed lines of credit was nil. As of June 30, 2024, HEI consolidated has $2.8 billion of long-term debt, net - other than bank, of which $59 million is due within 12 months and $284 million is due within 24 months.
As of June 30, 2024, HEI’s cash and cash equivalents balance, excluding its subsidiaries, was $124 million, compared to $127 million as of March 31, 2024 and $137 million as of December 31, 2023. The Company believes that its cash and cash equivalents and expected operating cash flow from operations would not be sufficient to meet the Company’s cash requirements in the next 12 months following the issuance of the financial statements. This is primarily due to the estimated liability to settle wildfire claims; the result of the August 2023 downgrades of their credit ratings to below investment grade which prevents the Company from accessing unsecured, short-term borrowings and continues to restrict access to the capital
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markets and other sources of debt and equity financing in a timely manner and on acceptable terms; extended plant shutdowns at Pacific Current’s Mahipapa facility; and higher working capital requirements resulting from inflation and elevated fuel prices. The Company is currently working with its financial advisors on a financing plan to raise the capital necessary to fund the contribution to the settlement of wildfire tort claims. While management believes the Company will be able to raise the necessary capital, there is no assurance that management’s plans will be successful.
For the Utilities, while fuel prices have moderated from their highs in 2022, they remain elevated and have increased the cost of carrying fuel inventory and higher customer accounts receivable balances as fuel is consumed and billed to customers. While the accounts receivable balance has decreased since December 2023, it remains elevated coming out of the pandemic and has led to higher bad debt expense and higher write-offs in 2023 and year-to-date 2024, following the end of the moratorium on disconnections. The higher bad debt expense is expected to continue until the Utilities return to pre-pandemic collection practices, along with a decrease in volume, for delinquent accounts. The Maui windstorm and wildfires have not and are not anticipated to materially impact accounts receivable, however, it will lead to higher bad debt expense. As of June 30, 2024, approximately $13.8 million of the Utilities’ accounts receivables were over 30 days past due. Of the over 30 days past due amounts, approximately 36% 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).
If further liquidity is deemed necessary in the short term, the Utilities could also reduce the pace of capital spending related to non-essential projects, manage O&M expenses, seek borrowings on a secured basis, and explore asset sales.
At ASB, liquidity remains at satisfactory levels. ASB’s cash and cash equivalents was $335 million as of June 30, 2024, compared to $435 million as of December 31, 2023. 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, higher interest rates 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).
HEI Consolidated material cash requirements. Material cash requirements of HEI Consolidated include: payments related to settlement of tort-related legal claims and cross claims, Utility related capital expenditures (including capital expenditures related to wildfires and wildfire mitigations), labor and benefit costs, O&M expenses, legal and consulting costs related to the Maui windstorm and wildfires, fuel and purchase power costs, and debt and interest payments; Bank related investments in loans; HEI related labor and benefits costs, debt and interest payments and legal and consulting costs related to the Maui windstorm and wildfires and HEI equity contributions to support Pacific Current’s sustainable infrastructure investments.
The substantial doubt about the Company’s ability to continue as a going concern and the Company’s credit rating downgrades related to the Maui windstorm and wildfires will continue to adversely impact its ability to access capital markets and other sources of debt and equity financing, if at all, in a timely manner and on acceptable terms The Company is currently working with its financial advisors on a financing plan to raise the capital required to settle its wildfire claims. While management believes the Company will be able to raise the necessary capital, there is no assurance that management’s plans will be successful. Further, the suspension of dividends from its subsidiaries, the economic impact of higher fuel prices, inflation, higher interest rates, tightening of monetary policy and geopolitical situations, create significant uncertainty, and the Company cannot predict the extent or duration of these conditions, the future effects that these conditions will have on the Company’s financing plan, 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)June 30, 2024December 31, 2023
Long-term debt, net—other than bank$2,838 72 %$2,842 54 %
Preferred stock of subsidiaries34 1 34 1 
Common stock equity1,085 27 2,345 45 
 $3,957 100 %$5,221 100 %
On March 12, 2024, S&P revised HEI’s outlook to “Negative” from “Watch Negative” and affirmed the “B-” issuer credit rating. The downgrades of HEI’s credit ratings will continue to adversely impact its ability to access capital markets and other sources of debt financing, if at all, in a timely manner and on acceptable terms.
There were no new issuances of common stock through the Dividend Reinvestment Program (DRIP), HEIRSP or the ASB 401(k) Plan in the six months ended June 30, 2024 and 2023.
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For the first six months of 2024, net cash provided by operating activities of HEI consolidated was $193 million. Net cash provided by investing activities for the same period was $34 million, primarily due to ASB’s net decrease in loans held for investment, proceeds of sale of commercial loans and ASB’s receipt of investment security repayments and maturities, partly offset by capital expenditures and purchase of FHLB stock, net of redemption. Net cash used in financing activities during this period was $355 million primarily due to net decreases in ASB’s other bank borrowings and deposit liabilities.
Dividends.  The payout ratios for the first six months of 2024 and full year 2023 were nil and 59%, respectively. 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. In August 2023, due to the potential impact from the Maui windstorm and wildfires, the HEI Board of Directors voted to suspend the quarterly cash dividend, starting after the second quarter dividend. This action is intended to allow the Company to provide additional liquidity and allocate cash to rebuilding and restoring power and help ensure a strong future for the Utilities and Bank. The ASB Board of Directors determined to suspend its quarterly cash dividends to HEI, starting after the second quarter 2023 dividend, to help ensure maximum possible Bank liquidity and capital. The Hawaiian Electric Board of Directors determined it would suspend its quarterly dividends to HEI, starting with the second quarter 2024 dividend, which would have been paid in the third quarter of 2024. The decision of the Hawaiian Electric Board of Directors to suspend its dividend to HEI was based upon the size of the proposed settlement of wildfire tort litigation and the fact that, although HEI and the Utilities are working with their financial advisors on a plan to fund the settlement, no definitive funding plan currently exists, all of which raise substantial doubt as to Hawaiian Electric’s and HEI’s ability to continue as a going concern.
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 48 to 50, 67, and 80 to 81 of the MD&A included in Part II, Item 7 of HEI’s and Hawaiian Electric’s 2023 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,” which includes disclosures relating to Maui windstorm and wildfires in HEI’s MD&A.
In June 2024, the Utilities accrued estimated wildfire liabilities of approximately $1.71 billion (pre-tax) related to the settlement of the Maui windstorm and wildfire tort-related legal claims (see Note 2 of the Condensed Consolidated Financial Statements). For the three and six months ended June 30, 2024, the Utilities incurred net losses of approximately $1.23 billion and $1.19 billion, respectively.
In the second quarter of 2024, operation and maintenance expenses were higher by approximately $11 million, or 8%, as compared to the same period in 2023. The increase was mainly due to wildfire mitigation program expenditures related to inspections, an agreement to settle indemnification claims asserted by the State of Hawaii, higher property and general liability insurance costs, and higher transmission and distribution corrective and preventive maintenance.
In the second quarter of 2024, kWh sales volume decreased 1.2% compared to the same period in 2023. The decrease is primarily due to a decrease in Maui sales from the Maui windstorm and wildfires as Maui consumption decreased 5.8% in the second quarter of 2024 compared to the same period in 2023. Additionally, cooler weather in 2024 and the continued adoption of energy efficiency measures and distributed energy resources further contributed to the reduction of kWh sales.
Fuel prices have decreased about 6% over the same quarter in the prior year. While the fuel costs are below 2023’s peak, they remain elevated. 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), 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.
In June 2024, the consumer price index increased 3.0% over the last 12 months. In Hawaii, the June 2024 Urban Hawaii (Honolulu) Consumer Price Index (CPI) increased 5.2% over the last 12 months. Under the PBR framework, inflation risk for the Utilities is partially 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 the annual change in 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 inflation factor percentage is the consensus projection of annual percentage change in GDPPI for the following calendar year published by Blue Chip Economic Indicators each October. 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. For the 2024 calendar year, the forecasted 2024 GDPPI was 2.18% (net of the 0.22% customer dividend), measured in October 2023, and became effective in rates on January 1, 2024.
•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.
Customer accounts receivable decreased in 2024 by $33 million, or 14% with the number of accounts past due greater than 90 days decreasing by 8% since December 31, 2023. The decrease in accounts receivables was primarily driven by receipt of government and other program assistance, higher cash receipts associated with increased disconnection efforts and a change in bill due date from 19 days to 15 days in March 2024, along with lower customer bills resulting from lower fuel prices. At this time, while accounts receivable balances continue to remain elevated compared to pre-pandemic levels, the decrease in accounts receivable balances since the beginning of the year has reduced working capital requirements and benefited the Utilities’ liquidity. See “Financial Condition—Liquidity and capital resources” for additional information.
System reliability. On March 25, 2024, the Utilities called on Hawaii Island customers to reduce or shift their electricity usage, and in certain instances initiated rolling outages due to a generation capacity shortfall. The situation was due to Hamakua Energy’s unexpected plant shutdown in late February 2024 and also due to the unavailability of generators that have experienced mechanical problems, were at reduced output, or were undergoing maintenance. During that time, generation margins were below targeted levels, especially when wind, solar and hydroelectric output were lower than forecasted. On April 24, 2024, the Utilities lifted their request to conserve electricity as several of the Utilities’ large generators returned to service and on June 3, 2024 Hamakua Energy completed replacement of one combustion turbine and returned to service. See above in “HEI MD&A-“Other” segment” for discussion relating to Hamakua Energy’s unexpected plant shutdown.
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Since the August 2023 Maui windstorm and wildfires, the Utilities have developed a set of Interim Wildfire Safety Measures (IWSM) to mitigate the risk of wildfires in areas identified as having higher risk of wildfire in all service territories (Oahu, Maui County, and Hawaii Island). These interim measures represent actions the Utilities either have already started, or will start in 2024, while the Utilities simultaneously work to develop a more comprehensive Wildfire Safety Strategy. In the near term, it is anticipated that these measures will result in disruptions to service and negatively impact T&D SAIDI and SAIFI. While the Utilities work to refine these measures over time to mitigate customer impacts, the Utilities are currently focused on taking immediate steps to keep island communities safe during extreme weather events. For a discussion regarding the launch of the Public Safety Power Shutoff (PSPS) program, see discussion below under “Interim Wildfire Safety Measures.”
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 the State of Hawaii achieve its sustainability goals, including renewable energy, resilience, and decarbonization, while also prioritizing economic development, equity and affordability. The Utilities are pursuing potential grant funding of projects under various programs as primary applicant as well as in partnership with other organizations. On August 7, 2024, the Utilities received a notification from the U.S. Department of Energy that its application for $95 million in federal funds under IIJA has been awarded. The Utilities have one full application that is pending federal government agency decision. If awarded, it would allow for reduction up to $238 million in the Utilities’ recovery under the Exceptional Project Recovery Mechanism (EPRM) and cost to customers. See “Regulatory proceedings” in Note 4 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 and cost to customers.
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 Maui windstorm and wildfires on the Utilities’ liquidity and capital resources, see discussion under “Financial Condition–Liquidity and capital resources.”
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RESULTS OF OPERATIONS
Three months ended June 30Increase 
20242023(decrease)(dollars in millions, except per barrel amounts)
$792 $794 $(2)
Revenues. Net decrease largely due to:
$(26)
lower kWh generated and lower fuel oil prices1
2 
higher DSM revenue
2 
higher MPIR revenue
6 
higher revenue from ARA adjustments
14 
higher kWh purchased and higher PPAC revenues, partially offset by lower purchased power energy prices2
259 280 (21)
Fuel oil expense1. Net decrease largely due to lower kWh generated and lower fuel oil prices, offset in part by worse heat rate performance, impacted by battery storage round trip efficiency loss
181 168 13 
Purchased power expense1, 2. Net increase largely due to higher kWh purchased, along with the addition of Stage 1 and Stage 2 renewable projects, offset in part by lower purchased power energy prices and the recovery of compensable curtailment energy payments in 2023
148 136 12 
Operation and maintenance expenses. Net increase largely due to:
3 
wildfire mitigation program related to inspections
3 
the settlement of indemnification claims asserted by the State of Hawaii3
3 
higher property and general liability insurance costs
2 
higher transmission and distribution operation and maintenance expense
1 
higher Demand Response cost
1 
amortization of Honolulu generating units 8 and 9 net book value at retirement
1 
higher employee benefits costs
(2)
less station maintenance work performed
(2)
higher storm costs incurred in 2023 due to inclement weather
1,712 — 1,712 
Wildfire tort-related claims. Increase due to the accrual of estimated wildfire liabilities related to the settlement of the Maui windstorm and wildfire tort-related legal claims
137 136 1 
Other expenses. Increase due to higher depreciation expense due to increasing investments to integrate more renewable energy and improve customer reliability and system efficiency, partially offset by lower revenue and payroll taxes
(1,644)74 (1,718)
Operating income (loss). Decrease largely due to wildfire tort-related claims, higher operation and maintenance expenses along with higher depreciation expenses, offset in part by higher ARA and MPIR revenue
(1,659)59 (1,718)
Income (loss) before income taxes. Decrease largely due to operating loss, partially offset by higher interest income earned on higher cash balances
(1,229)45 (1,274)
Net income (loss) for common stock. Decrease due to loss before income taxes. See below for effective tax rate explanation
1,971 1,994 (23)
Kilowatthour sales (millions)3
$120.12 $122.69 $(2.57)Average fuel oil cost per barrel
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Six months ended June 30Increase 
20242023(decrease)(dollars in millions, except per barrel amounts)
$1,581 $1,625 $(44)
Revenues. Net decrease largely due to:
$(84)
lower fuel oil prices and lower kWh generated1
3 higher DSM revenue
3 
higher MPIR revenue
12 higher revenue from ARA adjustments
22 
higher kWh purchased and higher PPAC revenues, partially offset by lower purchased power energy prices2
543 614 (71)
Fuel oil expense2. Net decrease largely due to lower fuel oil prices and lower kWh generated, offset in part by worse heat rate performance, impacted by battery storage round trip efficiency loss and the loss of more efficient generator units on Oahu and Hawaii Island
341 321 20 
Purchased power expense1, 2. Net increase largely due to higher kWh purchased, along with the addition of Stage 1 and Stage 2 renewable projects, offset in part by lower purchased power energy prices and the recovery of compensable curtailment energy payments in 2023
291 265 26 
Operation and maintenance expenses. Net increase largely due to:
10 
the settlement of indemnification claims asserted by the State of Hawaii3
6 
wildfire mitigation program related to inspections
5 
higher property and general liability insurance costs
4 
higher transmission and distribution operation and maintenance expense
3 
higher Demand Response cost
2 
amortization of Honolulu generating units 8 and 9 net book value at retirement
2 
higher employee benefits costs
(2)
less station maintenance work performed
(3)
higher storm costs incurred in 2023 due to inclement weather
1,712 — 1,712 
Wildfire tort-related claims. Increase due to the accrual of estimated wildfire liabilities related to the settlement of the Maui windstorm and wildfire tort-related legal claims
274 275 (1)
Other expenses. Decrease due to lower revenue and payroll taxes, offset by higher depreciation expense due to increasing investments to integrate more renewable energy and improve customer reliability and system efficiency
(1,581)150 (1,731)
Operating income (loss). Decrease largely due to wildfire tort-related claims, higher operation and maintenance expenses along with higher depreciation expenses, offset in part by higher ARA and MPIR revenue
(1,608)120 (1,728)
Income (loss) before income taxes. Decrease largely due to operating loss, partially offset by higher interest income earned on higher cash balances
(1,190)92 (1,282)
Net income (loss) for common stock. Decrease due to loss before income taxes. See below for effective tax rate explanation
3,877 3,930 (53)
Kilowatthour sales (millions)4
$121.01 $131.48 $(10.47)Average fuel oil cost per barrel
470,532 472,482 (1,950)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.
3Pursuant to an agreement to settle indemnification claims with the State of Hawaii. See Note 2 of the Condensed Consolidated Financial Statements.
4 kWh sales were lower compared to the same quarter in prior year. The decrease in sales can be attributed to generally cooler weather in 2024 and ongoing impacts from the Maui windstorm and wildfires. In addition, the continued adoption of energy efficiency measures and distributed energy resources contributed to the reduction in kWh sales.
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The Utilities’ effective tax rates for the second quarter and the first six months of 2024 were 26% tax benefit and for the second quarter and the first six months of 2023 were 22% tax expense. The effective rates for the current quarter and six months ended June 30, 2024 was higher than the comparable period due to the substantial pre-tax loss resulting from the accrual of the loss contingencies related to the wildfire tort-related claims because the impact of permanent items had a smaller impact on the effective rate.
Hawaiian Electric’s consolidated ROACE was not meaningful and 8.2% for the twelve months ended June 30, 2024 and June 30, 2023, respectively.
For more information of the Utilities’ incremental expenses related to the Maui windstorm and wildfires for the year ended June 30, 2024, see “Results of operations—Maui windstorm and wildfires related expenses” in HEI’s MD&A.
The net book value (cost less accumulated depreciation) of utility property, plant and equipment (PPE) as of June 30, 2024 amounted to $5.6 billion, of which approximately 20% related to generation PPE, 65% related to transmission and distribution PPE, and 15% related to other PPE. Approximately 6% of the total net book value relates to generation PPE that has been deactivated or that the Utilities plan to deactivate or decommission by 2046.
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 safe, modern, resilient, flexible, and dynamic electric grid that protects Hawaii from impacts of climate change and 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 4 of the Condensed Consolidated Financial Statements.
Interim Wildfire Safety Measures. The Utilities first began developing a Wildfire Safety Strategy in 2019 and continue to adapt the plan to address the elevated risks in Hawaii. Since the Maui windstorm and wildfires, the Utilities have developed a set of Interim Wildfire Safety Measures to reduce the risk of wildfires associated with utility infrastructure in service territory areas identified as posing a higher wildfire risk. These interim measures represent actions the Utilities have either already started, or will start in 2024, while simultaneously working to develop a more comprehensive strategy. These actions include wildfire risk analysis, operation procedures and grid design changes, enhanced inspection and vegetation management plans, and system hardening.
One of the interim measures is the Public Safety Power Shutoff (PSPS) program, which calls for the Utilities to preventatively de-energize circuits in areas identified as high fire risk during certain weather conditions. The PSPS program launched on July 1, 2024 and is ready to use, if and when it is needed, and as the last line of defense to protect customers, communities and employees. The initial PSPS protocols and operational procedures represent an early-stage iteration, which will evolve over time as more analytical, forecast, and situational awareness capabilities and wildfire mitigations are deployed. De-energizing circuits in high wildfire risk areas will lead to extended interruptions for many customers, even if not in a high wildfire risk area. The Utilities will continue to work with key stakeholders in balancing the risk of utility-related wildfires with the public consequences of not having electricity.
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. A sustainable energy future is one that focuses on delivering electricity safely, reliably and affordably, strengthening resilience and shifting away from fossil-fueled resources. The Utilities believe that a holistic approach to climate change is needed, working on both climate mitigation efforts along with climate adaptation efforts. Climate mitigation 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. Since that time, delays and cancellations in the commercial operation of new renewable third-party generation resources and higher costs as a result of supply chain disruptions and inflationary pressures, as well as federal policies related to solar panel imports have slowed the pace of progress toward reducing GHG emissions. Also, see the “Developments in renewable energy efforts—New renewable PPAs” section below. The downgrade of Hawaiian Electric’s credit ratings after the Maui windstorm and wildfires is anticipated to be an
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additional impediment to completion of new renewable energy and storage projects. As a result of these challenges, the Utilities expect the planned 70% reduction in carbon emissions to be achieved later than the original 2030 target date. However, the Utilities will continue to replace significant amounts of fossil fuel generation with renewable energy between now and 2030 and expect to meet or exceed the State of Hawaii’s RPS goals.
Hawaiian Electric has also committed to achieving net zero carbon emissions from power generation by 2045 or sooner. While the timing of the Utilities’ carbon reduction goals will be adjusted, key elements of the 2030 plan have already been completed or remain on track to be completed by 2030, including 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, 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 is consistent with state policy and supported by Hawaii State law.
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, in 2024, the first solar-plus storage project on Maui, a 60 megawatt (MW) Stage 1 project which is the largest solar-plus storage project in the State of Hawaii, reached commercial operations on May 31, 2024. Additionally, a 12.5 MW Stage 1 solar-plus storage project on Oahu reached commercial operations on March 28, 2024. The first Stage 2 solar-plus storage project, a 42 MW project on Oahu, reached commercial operations on June 7, 2024.
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 (see also “Integrated Grid Planning” below).
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 latest milestone RPS target of 30% for 2020, where it achieved an RPS of 34.5%. In July 2022, former 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 was 31.8% versus 39.1% under the prior method. The change in the definition is effective from July 2022 forward 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 megawatt-hour (MWh) that an electric utility is deficient. Based on the level of total generation in 2023, 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. In 2023, the Utilities achieved a 33.3% RPS earning a reward of $444,116 based on $15/MWh in exceedance of 33.0% RPS. In 2024, the Utilities are eligible for a reward of $10/MWh in exceedance of 34.0% RPS.
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.
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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 4 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) process utilizes an inclusive and transparent stakeholder engagement model to provide an avenue for interested parties to engage with the Utilities and contribute meaningful input throughout the IGP process. The IGP Stakeholder Council, Technical Advisory Panel and Working groups have been established and meet regularly to provide feedback and input on specific issues and process steps in the IGP. On March 7, 2024, the PUC accepted the Utilities’ final Integrated Grid Plan. 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.
On June 28, 2024, the Utilities filed its annual update of the Action Plan described in its 2023 final Integrated Grid Plan.
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 8, 2021, the PUC approved the new program, Emergency Demand Response Program (EDRP), a battery storage incentive program to dispatch electricity between 6 p.m. to 8 p.m. daily from participating residential and commercial customers, to address the potential reserve shortfalls following the AES coal plant retirement. The Battery Bonus on Oahu is officially closed to new applications. As of June 30, 2024, the Utilities have received and approved applications totaling 46.79 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 June 30, 2024, the Battery Bonus program on Maui has officially closed to new applications, and the Utilities have received and approved the applications totaling approximately 9.9 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. Hawaiian Electric issued the RFP on February 1, 2023 and bids were due on February 1, 2024. On February 23, 2024, Hawaiian Electric filed a letter to the PUC recommending to close the RFP as no bids were received. On April 3, 2024, the PUC terminated the RFP as recommended by the Utilities.
Grid modernization. The overall goal of the Grid Modernization Strategy (GMS) 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. On March 25, 2019, the PUC approved a plan for the Utilities to implement GMS Phase 1, 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 June 30, 2024, approximately $125 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. As of June 30, 2024, the Utilities have deployed about 440,000 advanced meters, servicing approximately 93% of total customers.
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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 GMS implementation. On March 31, 2021, the Utilities filed a supplement and update to the GMS Phase 2 ADMS application to include broad deployment of field devices, which the PUC suspended on November 16, 2021, to focus the Utilities’ attention on completing Phase 1. 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 and expansion of the Phase 2 scope to also include Operational Technology Cybersecurity Monitoring. On May 31, 2024, the Utilities filed another updated and supplemented application for updated project costs, as well as the addition of Private Long-Term Evolution expansion and Supervisory Control and Data Acquisition expansion to the prior GMS Phase 2 scope (ADMS, Field Devices, and Operational Technology Cybersecurity Monitoring). The estimated cost for the implementation of GMS Phase 2 over seven years, which includes capital, deferred software costs and O&M costs, is $215 million. The Utilities have requested PUC approval by the end of 2024.
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 three years and one Phase 1 project (3,000 kW on Oahu) achieved commercial operations on October 1, 2023. Two additional phase 1 projects achieved commercial operations on April 1, 2024 (Hawaii Island: 750kW and Molokai: 250kW).
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. One project has since been withdrawn by the selected CBRE developer and the remaining 20 MW of dedicated-LMI projects are expected to become operational in 2026.
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. Two projects on Hawaii Island were subsequently withdrawn by the developer on October 18, 2023. Two additional Hawaii Island projects were disqualified on May 13, 2024. On June 14, 2024, a project on Oahu was withdrawn by the developer. There are no remaining Tranche 1 projects in development.
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 would continue, but the Utilities did not execute a PPA at this time given the uncertainty due to the Pulama Lanai notification. The parties are currently exploring options to move forward with the project. 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. After successful negotiations, two contracts for solar plus storage facilities were executed and on September 29, 2023, the Utilities filed two applications with the PUC requesting approval of the contracts. On January 8, 2024, the PUC approved the two contracts.
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 subscription quotes, compare, and subscribe to a project once the Subscriber Organization has added their project to the portal.
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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 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 4 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 and 2021 did not trigger the earnings sharing mechanism for the Utilities.
On August 31, 2023, the PUC issued an order temporarily suspending the ESM until further notice. The intent of the order is to address the unintended consequence of customers potentially bearing the costs associated with the Maui windstorm and wildfires through the operation of the ESM without prior PUC review. In accordance with the order, the earnings sharing adjustment for 2023 is zero until the PUC lifts the suspension.
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Actual and PUC-allowed returns, as of June 30, 2024, were as follows:
%Rate-making Return on rate base (RORB)*ROACE**Rate-making ROACE***
Twelve months ended 
June 30, 2024
Hawaiian ElectricHawaii Electric LightMaui ElectricHawaiian ElectricHawaii Electric LightMaui ElectricHawaiian ElectricHawaii Electric LightMaui Electric
Utility returnsNMNMNMNMNMNMNMNMNM
PUC-allowed returns7.37 7.52 7.43 9.50 9.50 9.50 9.50 9.50 9.50 
*      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.
NM - Not meaningful.
The Utility’s actual and allowed rates of return are not meaningful due to the accrual of estimated wildfire liabilities of approximately $1.71 billion (see Note 2 of the Condensed Consolidated Financial Statements).
The gap between PUC-allowed ROACEs and the ROACEs achieved is generally 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 multi-year rate period (MRP), during which there will be no general rate case applications. In the fourth year of the MRP, the PUC will comprehensively review the PBR Framework to determine if any modifications or revisions are appropriate. See also “Regulatory proceedings” in Note 4 of the Condensed Consolidated Financial Statements.
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 projects 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 1 project and one Stage 2 project mutually terminating their PPAs 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 regard 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 have negotiated amendments 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. All of these amendments have been approved. 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 4 of the Condensed Consolidated Financial Statements and the following:
New renewable PPAs.
•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
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the PGV ARPPA was filed on April 4, 2023. On June 13, 2023, PGV notified the Utilities of concerns of its ability to timely deliver on the terms of the ARPPA. PGV has been working to re-establish its capacity generation and has continued drilling and plans to drill additional wells, however, this process has taken longer than anticipated and PGV has become increasingly concerned about timely achieving the Contract Firm Capacity of 46 MW. In light of receiving this information and to allow the Utilities and PGV to determine the best path forward, on July 6, 2023 the Utilities asked the PUC to put the procedural schedule on hold for approval of the First Amendment to the PGV ARPPA. In order to address PGV’s concerns, the parties executed a Second Amendment to the PGV ARPPA, which among other things lowered the capacity needed to reach commercial operations and preserves the full contract capacity, effectuating a partial commissioning. On October 2, 2023 the Utilities filed a letter requesting the docket be reopened and seeking approval of the First and Second Amendments to the PGV ARPPA by the end of 2023. On December 29, 2023, the PUC issued a D&O conditionally approving the First and Second Amendments to the PGV ARPPA. As directed, on January 12, 2024, the Utilities filed a supplemental brief explaining its request for cost recovery. A response from the PUC is still pending.
•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, the Utilities filed seven 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 all seven amendments. AES West Oahu Solar project on Oahu and AES Kuihelani Solar project on Maui reached commercial operations on March 28, 2024 and May 31, 2024, respectively. See also “Purchase commitments” in Note 4 of the Condensed Consolidated Financial Statements. To date, five projects reached commercial operations.
A summary of the remaining seven PPAs is as follows:
UtilitiesNumber of contractsTotal photovoltaic size (MW)BESS Size (MW/MWh)Guaranteed commercial operation datesContract term (years)Total projected annual payment (in millions)
Hawaiian Electric4139.5139.5/558
7/31/22, 1/11/23, 3/28/24 & 10/31/24
20 & 25$34.0 
Hawaii Electric Light26060/240
 4/21/23 & 1/28/25
2519.2 
Maui Electric16060/2405/31/242513.2 
Total7259.5259.5/1038$66.4 
The Utilities have received PUC approvals to recover the total projected annual payment of $66.4 million for the seven PPAs through the PPAC to the extent such costs are not included in base rates.
•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 four remaining projects have received PUC approval. To date, the Utilities filed three 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 all three amendments. The Kupono Solar project on Oahu reached commercial operations on June 7, 2024. See also “Purchase commitments” in Note 4 of the Condensed Consolidated Financial Statements. The two GSPAs were approved by the PUC in December 2020. As of June 30, 2024, while the GSPA contracts have not yet achieved its contractual target, the aggregators continue to enroll customers every month. To date, two projects reached commercial operations.
A summary of the remaining four approved Stage 2 PPAs, is as follows:
UtilitiesNumber of contractsTotal photovoltaic size (MW)BESS Size (MW/MWh)Guaranteed commercial operation datesContract term (years)Total projected annual payment (in millions)
Hawaiian Electric37979/443
5/17/24*, 6/7/24 & 9/1/24
20 & 25$31.4 
Hawaiian Electric1N/A185/56512/19/232024.0 
Total479264/1,008$55.4 
* Project delays have resulted in Guaranteed Commercial Operations Date being missed.
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The total projected annual payment of $55.4 million for these PPAs will be recovered through the PPAC to the extent such costs are not included in base rates.
A summary of the GSPAs that were approved by PUC in December 2020 is as follows:
UtilitiesFast Frequency Response - 1
(MW)		Fast Frequency Response - 2
(MW)		Capacity -
Load Build
(MW)		Capacity -
Load Reduction
(MW)
Hawaiian Electric—26.714.519.4
Hawaii Electric Light6.0—3.24.0
Maui Electric6.1—1.94.7
Total12.126.719.628.1
A summary of the utility self-build projects is as follows:
UtilitiesNumber of contractsBESS Size (MW/MWh)Guaranteed commercial operation dates
Hawaii Electric Light1*12/1212/30/22
Maui Electric140/16011/30/26
Total252/172
* The utility Self-Build project was denied by the PUC on May 25, 2022 and the Utilities filed a motion for reconsideration with the PUC. On January 26, 2024, the PUC granted the Utilities’ November 15, 2023 request to suspend the docket to focus on identified priorities. The Utilities provided the PUC with an updated assessment of the project on April 30, 2024 and requested to withdraw the application because the need that was to be served by the project can now be met by Stage 3 RFP resources. On July 8, 2024, the Utilities received approval from the PUC to withdraw the project.
Tariffed renewable resources.
•As of June 30, 2024, there were approximately 631 MW, 143 MW and 151 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 June 30, 2024, an estimated 41% of single family homes on the islands of Oahu, Hawaii and Maui have installed private rooftop solar systems, and approximately 23% of the Utilities’ total customers have solar systems.   
•The Utilities began accepting energy from feed-in tariff projects in 2011. As of June 30, 2024, 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 2025.
•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 worked with the lone bidder outside of the RFP process and filed two PPAs with a total of 2.45 MW of PV paired with 11.1 MWh of battery
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energy storage on September 29, 2023.The PUC approved both PPAs on January 8, 2024. See “Transition to a decarbonized and sustainable energy future—Community-based renewable energy” for additional information.
•On March 17, 2022, the CBRE LMI RFPs for Oahu, Maui and Hawaii Island 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. One project on Maui was subsequently withdrawn by the developer on April 11, 2024. The Utilities opened the CBRE Tranche 1 RFPs for Oahu, Maui and Hawaii Island 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. Two projects on Hawaii Island were subsequently withdrawn by the developer on October 18, 2023 and an additional project on Oahu was subsequently withdrawn by the developer on June 14, 2024. Two projects on Hawaii Island were disqualified on May 13, 2024. See “Transition to a decarbonized and sustainable energy future—Community-based renewable energy” for additional information.
•The Hawaii Island Stage 3 RFP, seeking 325 gigawatt-hours (GWh) per year of energy and 65 MW of renewable firm capacity, was issued on November 21, 2022. Proposals were received on April 20, 2023. The Stage 3 RFPs for Oahu and Maui opened for bids on January 20, 2023. For Oahu, the Utilities sought 500 to 700 MW of renewable firm capacity, and at least 965 GWh of renewable dispatchable energy annually. For Maui, the Utilities sought at least 40 MW of renewable firm capacity, and at least 425 GWh of renewable dispatchable energy annually. For the Oahu and Hawaii Island RFPs, as well as for the variable generation portion of the Maui RFP. Proposals for the firm generation portion of the Maui Stage 3 RFP were received on August 17, 2023, and Priority List selections were announced on October 9, 2023. 15 proposals were selected to the Final Award Group on December 8, 2023. Seven projects were selected on Oahu (three solar plus storage and four firm renewable) totaling 413 GWh of variable generation, 594 MW of firm generation, and 990 MWh of storage; four projects were selected on Maui (three solar plus storage and one wind) totaling 324 GWh of variable generation, and 320 MWh of storage; and four projects were selected on Hawaii Island (three solar plus storage and one firm renewable) totaling 512 GWh of variable generation, 60 MW of firm generation, and 834 MWh of storage. One project totaling 40 MW of firm renewable generation was selected to the Maui Firm Final Award Group on February 2, 2024. On May 24, 2024, a 20 MW / 80 MWh solar-plus storage project on Maui was withdrawn by the developer. Negotiations for the remaining projects are ongoing.
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 4 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 was suspending all purchases of Russian crude oil, which accounts for at least 25% of Hawaii’s supply. 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, 2025 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.
In June 2024, the Utilities accrued estimated wildfire liabilities of approximately $1.71 billion (pre-tax) related to the settlement of the Maui windstorm and wildfire tort-related legal claims (see Note 2 of the Condensed Consolidated Financial Statements). For the three and six months ended June 30, 2024, the Utilities incurred net losses of approximately $1.23 billion and $1.19 billion, respectively.
When preparing financial statements for each annual and interim reporting period, management has the responsibility to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the Utilities’ ability to continue as a going concern within one year after the date that the financial statements are issued. In making its evaluation, the Utilities consider, among other things, risks and/or uncertainties related to its results of operations, contractual obligations, including near-term debt maturities, dividend requirements, debt covenant compliance, or other factors impacting the Utilities’ liquidity and capital resources. As of the date of filing of this Form 10-Q, management has not yet implemented a capital financing plan to address expected wildfire settlement payments. If the conditions resulting in the substantial doubt are not resolved prior to the issuance of the Utilities’ annual financial statements, or it is not yet probable that management's plans
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can be effectively implemented to address those conditions, the Utilities would be in default on certain terms of its taxable debt agreements and syndicated credit facility agreement, and lenders would have the option to call the outstanding debt. Management believes the Utilities’ current cash balance at June 30, 2024 of $88.6 million, and available capacity on the asset-based lending facility (ABL Facility) would not be sufficient to fund the Utilities’ planned expenditures and operational needs, which include potential payments to settle wildfire claims.
The Utilities are currently working with their financial advisors on a financing plan to raise the capital necessary to fund their contribution to the settlement of wildfire tort claims. The Utilities expect to finance the settlement payments over time through a mix of debt, common equity, equity-linked securities or other potential options. While management believes the Utilities will be able to raise the necessary capital, there is no assurance that management’s plans will be successful. If the financing plans are unsuccessful, the Utilities may need to consider other strategic alternatives. See further discussion in Part II. Other Information—Item 1A. Risk Factors.
The Utilities’ future results of operations involve significant risks and uncertainties. Factors that could affect the Utilities’ future operating results and could cause actual results to vary materially from expectations include, but are not limited to, access to capital, ability to attract and retain key personnel, and pending or threatened litigation (including recent litigation noted above).
As of June 30, 2024, Hawaiian Electric had no commercial paper outstanding, $200 million outstanding on its revolving credit facility and no remaining available borrowing capacity under the Utilities’ committed line of credit. The cash proceeds were invested in highly liquid short-term investments, and as of June 30, 2024, the Utilities’ cash and cash equivalents balance was $88.6 million, compared to $106.1 million as of December 31, 2023.
Additionally, at June 30, 2024, Hawaii Electric had no borrowing from HEI with remaining available borrowing capacity of $75 million, pursuant to a standing commitment letter from HEI. See Note 6 of the Condensed Consolidated Financial Statements for additional information. At June 30, 2024, Hawaii Electric Light and Maui Electric had short-term borrowings from Hawaiian Electric of nil and $110.0 million, respectively, which intercompany borrowings are eliminated in consolidation.
Hawaiian Electric’s objective continues to be to operate a strong, financially healthy enterprise to empower a thriving future for Hawaii. While the fundamentals of its business remain strong, the Utilities took prudent and measured actions to strengthen their financial position while continuing to provide reliable service to its customers and reinforcing its commitment to serving the community for the long term. In August 2023, Hawaiian Electric fully drew down $200 million on its existing revolving credit facilities. The cash proceeds were primarily invested in highly liquid short-term investments and used for general corporate purposes. Longer term, the Utilities are evaluating other sources of liquidity that could include securitization, re-prioritizing capital spending and reducing O&M, issuing secured debt, and conducting asset sales, among others.
Accounts receivable balances remain elevated coming out of the pandemic and has led to higher bad debt expense and higher write-offs in 2023 and year-to-date June 2024, following the end of the moratorium on disconnections. The higher bad debt expense is expected to continue until the Utilities return to pre-pandemic collection practices, along with a decrease in volume, for delinquent accounts. The Maui windstorm and wildfires have not and are not anticipated to materially impact accounts receivable, however, it will lead to higher bad debt expense. As of June 30, 2024, approximately $13.8 million of the accounts receivables were over 30 days past due. Of the over 30 days past due amounts, approximately 36% 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.
With the exception of Maui, the Utilities are continuing the disconnection process on a tiered basis, expanding the targeted balances, which is expected to reduce delinquent accounts receivable balances and accelerate cash collections. Service disconnections on Maui have been suspended through at least August 31, 2024, in accordance with the extension of Governor Josh Green’s emergency proclamation; however, efforts are ongoing to educate and inform customers impacted by the Maui windstorm and wildfires on the availability of financial assistance to manage delinquencies accordingly. See also “Regulatory assets and liabilities” in Note 4 of the Condensed Consolidated Financial Statements.
The rebuilding of Lahaina will be a community-led effort and will occur over an extended period of time. The cost of rebuilding the electric utility infrastructure is not yet known, but could be significant because the infrastructure that may be required is expected to be different than what previously existed. For example, to mitigate wildfire risk, grid hardening strategies, such as undergrounding lines in high-risk locations, are expected to be employed.
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Hawaiian Electric’s consolidated capital structure was as follows:
(dollars in millions)June 30, 2024December 31, 2023
Long-term debt, net$1,935 61 %$1,934 44 %
Preferred stock34 1 34 1 
Common stock equity1,193 38 2,409 55 
$3,162 100 %$4,377 100 %
Prior to the Maui windstorm and wildfires, Hawaiian Electric utilized short-term debt, typically commercial paper, to support normal operations, to refinance short-term debt and for other temporary requirements. Hawaiian Electric may also borrow 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 also historically utilized 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 downgrades of Hawaiian Electric’s credit ratings will continue to adversely impact the Utilities’ ability to access capital markets and other sources of debt and equity financing, if at all, in a timely manner and on acceptable terms.
Credit ratings. On March 12, 2024, S&P revised Hawaiian Electric’s outlook to “Negative” from “Watch Negative” and affirmed the “B-” issuer credit rating.
See “Credit and Capital Market Risk” in Item 1A. Risk Factors in HEI’s and Hawaiian Electric’s 2023 Form 10-K. The downgrades of Hawaiian Electric’s credit ratings will continue to adversely impact the Utilities’ ability to access capital markets and other sources of debt financing, if at all, in a timely manner and on acceptable terms. In addition, the downgrades of Hawaiian Electric’s credit ratings triggered certain cash or payment requirements with the Utilities’ vendors. However, the Utilities believe additional vendor collateral or payment requirements will not have a material impact on the Utilities’ liquidity.
Asset-based lending facility credit agreement. On May 17, 2024, Hawaiian Electric, through a special-purpose subsidiary, entered into an asset-based lending facility (ABL Facility) credit agreement (ABL Credit Facility Agreement) with several banks, which, subject to the limitations and conditions set forth in such agreement, including approval by the PUC, allows borrowings of up to $250 million on a revolving basis using certain accounts receivable as collateral. Hawaiian Electric filed an application with the PUC for approval to (i) sell accounts receivable, and (ii) establish a long-term credit facility. The first approval would allow the ABL Credit Facility Agreement to become effective for 364 days and the second approval would extend the term of the ABL Credit Facility Agreement from 364 days to three years. The ABL Credit Facility Agreement has an initial term of 364 days, with an automatic extension to three years upon receipt of the second PUC approval, with three separate options to extend one additional year, subject to the consent of the lenders. On June 27, 2024, Hawaiian Electric received the first approval from the PUC for the ABL Credit Facility Agreement that allows short-term borrowings of up to $250 million, subject to the availability of a sufficient borrowing base of eligible receivables. Per the parties’ proposed stipulated procedural schedule, the second PUC decision is expected on October 30, 2024. The ABL Facility became effective on July 24, 2024.
Credit agreement. On August 23, 2023, Hawaiian Electric fully drew down $200 million on its existing revolving credit facilities. The cash proceeds were invested in highly liquid short-term investments and will be used for general corporate purposes. The $200 million line of credit facility remained fully drawn as of June 30, 2024. See Note 6 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). The Utilities did not issue SPRBs under the 2019 Legislative Authorization which lapsed on June 30, 2024.
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
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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 summary table below for remaining authorized amounts as of June 30, 2024 for each respective utility.
(in millions)Hawaiian ElectricHawaii Electric LightMaui Electric
Total “up to” amounts of taxable debt authorized from 2023 through 2026$230 $65 $105 
Less: taxable debt executed on January 10, 2023, but issued on February 9, 2023
100 25 25 
Remaining authorized amounts$130 $40 $80 
As of June 30, 2024, the Utilities have $1.9 billion of long-term debt, net, of which $47.0 million and $145.3 million are due within 12 and 24 months, respectively.
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 June 30, 2024, 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 six months ended June 30, 2024 compared to the six months ended June 30, 2023:
Six months ended June 30
(in thousands)20242023Change
Net cash provided by operating activities$185,473 $336,145 $(150,672)
Net cash used in investing activities(166,657)(226,093)59,436 
Net cash used in financing activities
(36,273)(5,647)(30,626)
Net cash provided by operating activities. The decrease in net cash provided by operating activities was primarily driven by an increase in fuel oil stock due to less consumption, as well as lower cash from an increase in customer accounts receivable due to payment on a large delinquent commercial customer account in 2023.
Net cash used in investing activities. The decrease in net cash used in investing activities was primarily driven by a decrease in capital expenditures related to construction activities.
Net cash used in financing activities. The increase in net cash used in financing activities was driven by lower net cash from long-term and short-term borrowings.
For a discussion of 2023 operating, investing and financing activities, please refer to the “Liquidity and capital resources” section in Item 7, “Management Discussion and Analysis of Financial Condition and Results of Operations—Electric utility,” in the Company’s 2023 Form 10-K.
Material cash requirements. Material cash requirements of the Utilities include payments related to settlement of tort-related legal claims and cross claims, legal and consulting costs related to the Maui windstorm and wildfires (see further information in Note 2 of the Condensed Consolidated Financial Statements), O&M expenses, labor and benefit costs, fuel and purchase power costs, debt and interest payments, operating and finance lease obligations, their forecasted capital expenditures (including capital expenditures related to wildfires and wildfire mitigations) and investments, their 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 and finance 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 operating cash flows, 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 substantial doubt about the Utilities’ ability to continue as a going concern and the Utilities’ credit rating downgrades related to the Maui windstorm and wildfires will continue to adversely impact its ability to access capital markets and other sources of debt financing, if at all, in a timely manner and on acceptable terms. The Utilities are currently working with their financial advisors on a financing plan to raise the capital required to settle its wildfire claims. While management believes that the Utilities will be able to raise the necessary capital, there is no assurance that management’s plans will be successful. The potential damages and losses related to the Maui windstorm and wildfires and related lawsuits (see further information in Note 2 of the Condensed Consolidated Financial Statements), the economic impact of higher fuel prices, inflation, higher
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interest rates, tightening of monetary policy, and geopolitical situations, create significant uncertainty, and the Utilities cannot predict the extent or duration of these conditions, the future effects that these conditions will have on the Utilities’ financing plan, cost of capital and their ability to access additional capital, or the future impacts on the Utilities’ financial position, results of operations, and cash flows.
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Bank
Recent Developments. See also “Recent developments” in HEI’s MD&A.
In June 2024, ASB recorded a pretax goodwill impairment charge of $82.2 million after determining it was more-likely-than-not that the fair value of ASB was less than its carrying value. The impairment charge was non-cash in nature and did not affect the Company’s current liquidity, cash flows or any debt covenants under the Company’s existing credit agreements. See “Goodwill” in Note 5 of the Condensed Consolidated Financial Statements for additional discussion.
In August 2023, ASB was impacted by wildfires on Maui which caused widespread property damage and fatalities. ASB’s outstanding credit exposure in Maui and the fire impacted zone of Lahaina as of June 30, 2024 was 12.3% and 0.6%, respectively, of the Bank’s total loan portfolio.
For the quarter ended June 30, 2024, ASB incurred additional expenses as a result of the Maui wildfires of $0.5 million, pretax, primarily consisting of professional services offset by negative provision for credit losses of $0.8 million.
The Hawaii economy remained stable in the second quarter of 2024 with average daily passenger counts 1.7% lower than the comparable period in the prior year. The recovery in total passenger counts from the low levels in 2020 is largely due to domestic travelers. International visitors (excluding Japan) have gradually increased although still below pre-pandemic levels. The weak yen continues to be a key contributing factor to the low Japan visitor counts as compared to other international visitors. Hawaii’s seasonally adjusted unemployment rate of 2.9% in June 2024 was higher compared to the June 2023 rate of 2.8%. Despite higher interest rates, Hawaii’s real estate market, as indicated by Oahu’s residential real estate market, has remained relatively stable. Single-family home sales grew 6.7% in the first half of 2024 compared to the same period in 2023, while condo sales declined 5.8%.
As of June 30, 2024, the Federal Open Market Committee federal funds rate target range remained unchanged at 5.25% - 5.50% in response to continued inflationary pressures in the economy. The interest rate environment has impacted ASB’s net interest margin as higher yields on earning assets were offset by an increase in yields on deposits and other borrowings. The higher interest rate environment has 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.
ASB’s loan portfolio decreased $152 million in 2024 as compared to the end of 2023 primarily due to payoffs and sale of commercial loans as well as reduced demand for home equity line of credit and consumer loan products.
For the quarter ended June 30, 2024, ASB recorded a negative provision for credit losses of $1.9 million primarily due to improving loss rates, lower loan portfolio balances and the release of $0.8 million of credit loss reserves for loans that were impacted by Maui wildfires. 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 June 30, 2024, the investment securities portfolio balance decreased approximately $97 million from year end 2023 due to repayments and no purchases of investment securities in 2024. The change in interest rates in the first half of 2024 resulted in higher unrealized losses in the available-for-sale investment securities portfolio, which also decreased the investment portfolio balance.
At June 30, 2024, ASB’s regulatory capital ratios were above the “well-capitalized” and regulatory requirements, including the conservation buffers. Approximately 83% of the Bank’s deposits are FDIC insured or fully collateralized. 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 June 30Increase 
(in millions)20242023(decrease)Primary reason(s)
Interest and dividend income$86 $82 $4 
Average loan portfolio yields were 35 basis points higher—yield benefited from the rising interest rate environment as adjustable rate yields repriced upward and new loan production yields were higher than the portfolio yields.
Average loan portfolio balances decreased $14 million—commercial, home equity line of credit and consumer loan portfolio average balances decreased $104 million, $45 million and $28 million, respectively, due to decreased demand for these loan products. Residential and commercial real estate loan average balances increased $97 million and $68 million, respectively.
Average investment securities portfolio balances decreased $390 million—investment security portfolio repayments were used to pay down maturing higher costing liabilities. Average investment securities portfolio yields were 5 basis points lower due to higher investment portfolio premium amortizations.
Average other investments increased $69 million—increase due to higher interest-earning deposits being held.
Noninterest income16 16 — 
Revenues102 98 4 
The increase in revenues for the three months ended June 30, 2024 compared to the same period in 2023 was primarily due to higher interest and dividend income.
Interest expense24 19 5 
Increase in interest expense due to an increase in interest expense on deposits offset by a decrease in interest expense on other borrowings due to the increase in the interest rate environment and a shift in costing liability mix.
Average core deposit balances decreased $293 million; average term certificate balances increased $214 million.
Average deposit yields increased from 48 basis points to 90 basis points due to a shift in mix of deposits and higher yields from the increase in the interest rate environment.
Average other borrowings decreased $285 million and average yields increased 49 basis points.
Average cost of funds increased from 83 basis points to 115 basis points due to a shift in funding from low cost core deposits to higher costing term certificates and other borrowings.
Provision for credit losses(2)— (2)
2024 negative provision for credit losses included reversal of $0.8 million credit loss reserves for loans impacted by the Maui wildfires, improving loan loss rates and lower loan portfolio balances.
Delinquency rates have increased—from 0.17% at June 30, 2023 to 0.47% at June 30, 2024 primarily due to Maui-related loan accommodations and one commercial real estate loan in foreclosure.
Net charge-off to average loans increased 1 basis point from 0.14% at June 30, 2023 to 0.15% at June 30, 2024 primarily due to an increase in consumer loan net charge-offs.
Noninterest expense136 54 82 
Increase in noninterest expense is due to a goodwill impairment charge of $82.2 million as a result of HEI’s comprehensive review of strategic options for ASB.
Expenses158 73 85 
The increase in expenses for the three months ended June 30, 2024 compared to the same period in 2023 was due to an increase in noninterest expense and interest expense, partially offset by a decrease in provision for credit losses.
Operating income (loss)
(56)25 (81)
The decrease in operating income (loss) for the three months ended June 30, 2024 compared to the same period in 2023 was primarily due to higher noninterest expense and interest expense, partly offset by higher interest and dividend income and lower provision for credit losses.
Net income (loss)
$(46)$20 $(66)
Net income (loss) for the three months ended June 30, 2024 was lower as compared to the same period in 2023 due to lower operating income.

.
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 Six months ended June 30Increase 
(in millions)20242023(decrease)Primary reason(s)
Interest and dividend income$174 $161 $13 
Average loan portfolio yields were 38 basis points higher—loan yields continued to increase in 2024 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 $64 million—residential and commercial real estate loan portfolio average balances increased $108 million and $76 million, respectively, due to demand for these loan types. Commercial loan portfolio average balances decreased $75 million due to the payoffs and sale of commercial loans.
Average investment securities portfolio balances decreased $396 million primarily due to repayments, no purchases in 2024 and sale of investment securities in the quarter ended December 31, 2023.
Average investment securities portfolio yields decreased 5 basis points.
Noninterest income33 30 3 
Higher bank-owned life insurance income—higher returns from insurance policies.
Revenues207 191 16 
The increase in revenues for the six months ended June 30, 2024 compared to the same period in 2023 was primarily due to higher interest and dividend income and higher noninterest income.
Interest expense50 33 17 
Increase in interest expense due to an increase in core deposit and term certificate yields, partially offset by lower other borrowing balances.
Average core deposit balances decreased $379 million; average term certificate balances increased $264 million.
Average deposit yields increased from 41 to 89 basis points primarily due to the increase in term certificate yields of 73 basis points and the shift in mix of deposits from low cost core deposits to term certificates.
Average other borrowings decreased $133 million and average yields increased 26 basis points.
Provision for credit losses(4)1 (5)
2024 negative provision for credit losses included reversal of $2.3 million credit loss reserves for loans impacted by the Maui wildfires, improving loan loss rates and lower loan portfolio balances.
2024 negative provision for credit losses also included the release of $0.9 million of credit loss reserves for unfunded loan commitments.
Delinquency rates have increased—from 0.17% at June 30, 2023 to 0.47% at June 30, 2024 primarily due to Maui-related loan accommodations and one commercial real estate loan in foreclosure.
Net charge-off to average loans of 0.14% at June 30, 2024 remained the same as compared to the same period in 2023.
Noninterest expense192 108 84 
The increase in noninterest expenses was primarily due to a goodwill impairment charge of $82.2 million as a result of HEI’s comprehensive review of strategic options for ASB, expenses related to the Maui wildfires and higher compensation and benefits expenses.
Higher compensation and benefits expenses primarily due to fair value adjustments related to the deferred compensation plan.
Expenses238 142 96 
The increase in expenses for the six months ended June 30, 2024 compared to the same period in 2023 was due to higher noninterest expense and interest expense, partially offset by lower provision for credit losses.
Operating income (loss)
(31)49 (80)
The decrease in operating income (loss) for the six months ended June 30, 2024 compared to the same period in 2023 was primarily due to higher noninterest expense and interest expense, partially offset by higher interest and dividend income, higher noninterest income and lower provision for credit losses.
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 Six months ended June 30Increase 
(in millions)20242023(decrease)Primary reason(s)
Net income (loss)
$(25)$39 $(64)
Net income (loss) for the six months ended June 30, 2024 was lower than the same period in 2023 due to lower operating income.

ASB’s return on average assets, return on average equity and net interest margin were as follows:
Three months ended June 30Six months ended June 30
(Annualized %)2024202320242023
Return on average assets(1.97)0.84 (0.53)0.81 
Return on average equity(33.97)16.20 (9.25)15.87 
Net interest margin2.79 2.75 2.77 2.80 
For the three and six months ended June 30, 2024 the Bank’s costs related to the Maui wildfires is as follows:
(in thousands)Three months ended June 30, 2024Six months ended June 30, 2024
Bank Maui wildfires related cost:
Provision for credit losses$(800)$(2,300)
Professional services expenses1,201 2,909 
Other expenses1
51 (266)
Total Bank Maui wildfires related cost
$452 $343 
1 Other expenses includes recovery of destroyed/loss cash of $0.4 million in the first three months ended March 31, 2024.

Note: Bank Maui wildfires related expenses - provision for credit losses is included in Provision for credit losses, professional services expenses are included in Noninterest expense-Services and other expenses are included in Noninterest expense-Other expense on the ASB Statements of Income and Comprehensive Income Data.
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Three months ended June 30
20242023
(dollars in thousands)Average
balance		Interest
income/
expense		Yield/
rate (%)		Average
balance		Interest
 income/
expense		Yield/
rate (%)
Assets:
Interest-earning deposits$106,177 $1,449 5.40 $36,891 $488 5.23 
FHLB stock29,639 743 10.10 15,660 237 6.07 
Investment securities
Taxable2,600,103 10,619 1.63 2,988,483 12,645 1.69 
Non-taxable66,486 515 3.08 67,912 513 3.01 
Total investment securities2,666,589 11,134 1.67 3,056,395 13,158 1.72 
Loans
Residential 1-4 family2,612,420 25,752 3.94 2,515,753 23,111 3.67 
Commercial real estate1,551,309 20,449 5.23 1,483,566 18,373 4.91 
Home equity line of credit989,972 11,090 4.51 1,034,785 9,657 3.74 
Residential land19,575 305 6.23 20,235 269 5.32 
Commercial672,728 10,033 5.96 777,028 10,854 5.56 
Consumer231,962 5,557 9.62 260,437 5,843 8.99 
Total loans 1,2
6,077,966 73,186 4.81 6,091,804 68,107 4.46 
Total interest-earning assets 3
8,880,371 86,512 3.89 9,200,750 81,990 3.56 
Allowance for credit losses(70,669)(71,191)
Noninterest-earning assets479,235 471,600 
Total assets$9,288,937 $9,601,159 
Liabilities and shareholder’s equity:
Savings$2,674,087 $1,354 0.20 $3,006,949 $313 0.04 
Interest-bearing checking1,392,408 2,937 0.85 1,298,399 769 0.24 
Money market391,780 3,788 3.88 268,744 1,738 2.59 
Time certificates1,030,314 9,936 3.87 816,772 6,841 3.36 
Total interest-bearing deposits5,488,589 18,015 1.32 5,390,864 9,661 0.72 
Advances from Federal Home Loan Bank529,670 6,479 4.84 141,506 1,605 4.49 
Borrowings from Federal Reserve Bank— — — 567,857 6,207 4.38 
Securities sold under agreements to repurchase and federal funds purchased— — — 105,691 1,040 3.95 
Total interest-bearing liabilities6,018,259 24,494 1.63 6,205,918 18,513 1.20 
Noninterest bearing liabilities:
Deposits2,508,658 2,685,828 
Other222,876 210,698 
Shareholder’s equity539,144 498,715 
Total liabilities and shareholder’s equity$9,288,937 $9,601,159 
Net interest income$62,018 $63,477 
Net interest margin (%) 4
2.79 2.75 
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Six months ended June 30
20242023
(dollars in thousands)Average
balance		Interest
income/
expense		Yield/
rate (%)		Average
balance
Interest
 income/
expense
Yield/
rate (%)
Assets:      
Interest-earning deposits$157,466 $4,296 5.40 $23,626 $609 5.13 
FHLB stock23,521 1,010 8.64 22,835 663 5.85 
Investment securities
Taxable2,620,463 22,060 1.68 3,015,220 26,341 1.75 
Non-taxable66,668 1,033 3.08 68,094 1,011 2.96 
Total investment securities2,687,131 23,093 1.72 3,083,314 27,352 1.77 
Loans   
Residential 1-4 family2,610,172 51,084 3.91 2,502,551 45,726 3.65 
Commercial real estate1,547,233 40,642 5.21 1,471,079 35,620 4.83 
Home equity line of credit1,000,665 21,844 4.39 1,028,076 18,685 3.67 
Residential land18,811 564 6.00 20,266 546 5.39 
Commercial705,433 20,998 5.94 780,859 21,251 5.45 
Consumer237,686 11,248 9.50 252,883 11,236 8.94 
Total loans 1,2
6,120,000 146,380 4.78 6,055,714 133,064 4.40 
Total interest-earning assets 3
8,988,118 174,779 3.88 9,185,489 161,688 3.52 
Allowance for credit losses(72,480)  (71,649)  
Noninterest-earning assets489,041   468,958   
Total assets$9,404,679   $9,582,798   
Liabilities and shareholder’s equity:      
Savings$2,699,446 $2,482 0.18 $3,074,650 $535 0.04 
Interest-bearing checking1,395,090 6,053 0.87 1,315,213 1,399 0.21 
Money market352,588 6,609 3.76 233,083 2,324 2.01 
Time certificates1,042,747 20,303 3.90 778,441 12,240 3.17 
Total interest-bearing deposits5,489,871 35,447 1.29 5,401,387 16,498 0.62 
Advances from Federal Home Loan Bank394,538 9,440 4.73 320,867 7,475 4.63 
Borrowings from Federal Reserve Bank238,187 5,193 4.37 318,674 6,926 4.38 
Securities sold under agreements to repurchase— — — 125,917 2,172 3.48 
Total interest-bearing liabilities6,122,596 50,080 1.64 6,166,845 33,071 1.08 
Noninterest bearing liabilities:      
Deposits2,511,954   2,715,408   
Other232,899   211,852   
Shareholder’s equity537,230   488,693   
Total liabilities and shareholder’s equity$9,404,679   $9,582,798   
Net interest income $124,699   $128,617  
Net interest margin (%) 4
  2.77   2.80 
1   Includes loans held for sale, at lower of cost or fair value.
2   Includes recognition of net deferred loan fees of $0.6 million and $0.7 million for the three months ended June 30, 2024 and 2023, respectively, and $1.2 million and $1.4 million for the six months ended June 30, 2024 and 2023, respectively, together with interest accrued prior to suspension of interest accrual on nonaccrual loans. Includes nonaccrual loans.
3   For the six months ended June 30, 2024 and 2023, 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 Federal Open Market Committee federal funds rate target range of 5.25% - 5.50% has been maintained at June 30, 2024 to combat
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inflation. ASB’s net interest income and net interest margin has been impacted by the higher interest rates as the Bank has used higher costing other borrowings and term certificates to fund its loan growth.
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 5 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 16% 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 June 30, 2024, approximately 36% 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 51% of ASB’s HELOC loan portfolio is in a first lien position.
Loan portfolio risk elements.  See Note 5 of the Condensed Consolidated Financial Statements.
Investment securities.  ASB’s investment portfolio was comprised as follows:
 June 30, 2024December 31, 2023
(dollars in thousands)Balance% of totalBalance% of total
U.S. Treasury and federal agency obligations$68,812 3 %$71,927 3 %
Mortgage-backed securities — issued or guaranteed by U.S. Government agencies or sponsored agencies2,125,054 95 2,218,565 95 
Corporate bonds32,927 1 32,903 1 
Mortgage revenue bonds14,076 1 14,358 1 
Total investment securities$2,240,869 100 %$2,337,753 100 %
Currently, ASB’s investment portfolio consists of U.S. Treasury and federal agency obligations, mortgage-backed securities, corporate bonds and mortgage revenue bonds. ASB owns mortgage-backed securities issued or guaranteed by the U.S. government agencies or sponsored agencies, including the Federal National Mortgage Association (FNMA), Federal Home Loan Mortgage Corporation (FHLMC), Government National Mortgage Association (GNMA) and Small Business Administration (SBA). Principal and interest on mortgage-backed securities issued by FNMA, FHLMC, GNMA and SBA are guaranteed by the issuer and, in the case of GNMA and SBA, backed by the full faith and credit of the U.S. government. U.S. Treasury securities are also backed by the full faith of the U.S. government.
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 2024, deposits decreased by $109 million, as an outflow of core deposits was replaced with time certificates. Core deposit retention 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 June 30, 2024 ASB’s costing liabilities consisted of 94% deposits and 6% borrowings as compared to 92% deposits and 8% borrowings as of December 31, 2023. The weighted average cost of interest-bearing deposits for the first six months of 2024 and 2023 was 1.29% and 0.62%, respectively. As of June 30, 2024 and December 31, 2023, ASB had approximately $1.7 billion and $1.6 billion of deposits that were uninsured or not collateralized, respectively.
Federal Home Loan Bank of Des Moines and Federal Reserve Bank. As of June 30, 2024 and December 31, 2023, ASB had $520 million and $200 million of advances outstanding at the FHLB of Des Moines, respectively. As of June 30, 2024, the unused borrowing capacity with the FHLB of Des Moines was $1.5 billion. As of June 30, 2024 and December 31, 2023, ASB had nil and $550 million of 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.
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
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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 June 30, 2024, ASB had an unrealized loss, net of taxes, on available-for-sale investment securities in AOCI of $165.7 million compared to an unrealized loss, net of taxes, of $150.4 million as of December 31, 2023. See “Item 3. Quantitative and qualitative disclosures about market risk” for a discussion of ASB’s interest rate risk sensitivity.
During the first six months of 2024, ASB recorded a negative provision for credit losses of $3.2 million in the allowance for credit losses primarily due to the release of $2.3 million of credit loss reserves related to the Maui wildfires, improving credit loss rates and lower loan balances. During the first six months of 2023, ASB recorded a provision for credit losses of $1.0 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.
 Six months ended June 30
Year ended
December 31, 2023
(in thousands)20242023
Allowance for credit losses, beginning of period$74,372 $72,216 $72,216 
Provision for credit losses(3,169)1,018 9,657 
Less: net charge-offs4,390 4,166 7,501 
Allowance for credit losses, end of period$66,813 $69,068 $74,372 
Ratio of net charge-offs during the period to average loans outstanding (annualized)0.14 %0.14 %0.12 %
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 six months ended June 30, 2024, ASB recorded a negative provision for credit losses for unfunded commitments of $0.9 million as compared to a provision for credit losses for unfunded commitments of $0.2 million for the six months ended June 30, 2023. As of June 30, 2024 and December 31, 2023, the reserve for unfunded loan commitments was $4.2 million and $5.1 million, respectively.
Legislation and regulation.  ASB is subject to extensive regulation, principally by the OCC and the FDIC. Depending on ASB’s level of regulatory capital and other considerations, these regulations could restrict the ability of ASB to compete with other institutions and to pay dividends to its shareholder. See the discussion below under “Liquidity and capital resources.”
FINANCIAL CONDITION
Liquidity and capital resources.
(dollars in millions)June 30, 2024December 31, 2023% change
Total assets$9,281 $9,673 (4)
Investment securities2,241 2,338 (4)
Loans held for investment, net5,963 6,106 (2)
Deposit liabilities8,036 8,146 (1)
Other bank borrowings520 750 (31)
As of June 30, 2024, ASB was one of Hawaii’s largest financial institutions based on assets of $9.3 billion and deposits of $8.0 billion.
As of June 30, 2024, ASB’s unused FHLB borrowing capacity was approximately $1.5 billion. As of June 30, 2024, ASB had commitments to borrowers for loans and unused lines and letters of credit of $1.9 billion, of which, commitments to lend to borrowers experiencing financial difficulty whose loan terms have been modified 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 six months ended June 30, 2024, net cash provided by ASB’s operating activities was $25 million. Net cash provided by ASB’s investing activities during the same period was $212 million, primarily due to a net decrease in loans receivable of $119 million, receipt of investment security repayments and maturities of $82 million and proceeds from the sale of commercial loans of $31 million partly offset by a net increase in FHLB stock of $14 million. Net cash used in financing activities during this period was $338 million, primarily due to a net decrease in other borrowings of $230 million and a decrease in deposit liabilities of $109 million offset by a net increase in mortgage escrow deposits of $1 million.
For the six months ended June 30, 2023, net cash provided by ASB’s operating activities was $43 million. Net cash used during the same period by ASB’s investing activities was $56 million, primarily due to a net increase in loans receivable of
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$208 million, purchases of loans held for investment of $26 million and additions to premises and equipment of $4 million, partly offset by the receipt of investment security repayments and maturities of $104 million, proceeds from the sale of commercial loans of $67 million, a net decrease in FHLB stock of $9 million and proceeds from the redemption of bank owned life insurance of $3 million. Net cash provided by financing activities during this period was $25 million, primarily due to a net increase in other borrowings of $336 million and a net increase in mortgage escrow deposits of $1 million, partly offset by a net decrease in repurchase agreements of $183 million, decreases in deposit liabilities of $105 million and $25 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 June 30, 2024, ASB was well-capitalized (well-capitalized ratio requirements noted in parentheses) with a Tier-1 leverage ratio of 8.4% (5.0%), common equity Tier-1 ratio of 13.2% (6.5%), Tier-1 capital ratio of 13.2% (8.0%) and total capital ratio of 14.2% (10.0%). As of December 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 12.3% (6.5%), Tier-1 capital ratio of 12.3% (8.0%) and total capital ratio of 13.4% (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). As of June 30, 2024, ASB did not request a dividend distribution from the OCC and FRB and will reevaluate its ability to distribute excess capital next quarter.
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 2023 Form 10-K (pages 81 to 83).
ASB’s interest-rate risk sensitivity measures as of June 30, 2024 and December 31, 2023 constitute “forward-looking statements” and were as follows:
Change in interest ratesChange in NII
(gradual change in interest rates)		Change in EVE
(instantaneous change in interest rates)
(basis points)June 30, 2024December 31, 2023June 30, 2024December 31, 2023
+3000.3 %2.1 %2.2 %2.7 %
+2000.2 1.4 1.9 2.5 
+1000.1 0.7 1.5 1.7 
-100(0.4)(1.0)(2.2)(2.3)
-200(1.0)(2.2)(5.2)(5.4)
-300(1.6)(3.5)(9.2)(10.3)
ASB’s net interest income (NII) sensitivity profile was less asset sensitive as of June 30, 2024 compared to December 31, 2023 primarily driven by lower cash balances and higher rate sensitive deposit balances.
Economic value of equity (EVE) sensitivity decreased as of June 30, 2024 compared to December 31, 2023 due to lower core deposit duration, partially offset by decrease in duration of mortgage-related investments and loans.

The computation of the prospective effects of hypothetical interest rate changes on the NII sensitivity and the percentage change in EVE is based on numerous assumptions, including relative levels of market interest rates, loan prepayments, balance changes and pricing strategies, and should not be relied upon as indications of actual results. To the extent market conditions and other factors vary from the assumptions used in the simulation analysis, actual results may differ materially from the simulation results. NII sensitivity analysis measures the change in ASB’s twelve-month, pretax NII in alternate interest rate scenarios, and is intended to help management identify potential exposures in ASB’s current balance sheet and formulate appropriate strategies for managing interest rate risk. The simulation does not contemplate any actions that ASB management might undertake in response to changes in interest rates. Further, the changes in NII vary in the twelve-month simulation period and are not necessarily evenly distributed over the period. These analyses are for analytical purposes only and do not represent management’s views of future market movements, the level of future earnings or the timing of any changes in earnings within the twelve month analysis horizon. The actual impact of changes in interest rates on NII will depend on the magnitude and speed with which rates change, actual changes in ASB’s balance sheet and management’s responses to the changes in interest rates.
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Item 4. Controls and Procedures
HEI:
Disclosure Controls and Procedures
The Company maintains a set of disclosure controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Company in reports that it files or submits under the Securities Exchange Act of 1934, as amended (Exchange Act), is recorded, processed, summarized and reported within the time periods specified in SEC’s rules and forms, and that such information is accumulated and communicated to the Company’s management, including its Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.
An evaluation was performed under the supervision and with the participation of the Company’s management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures, as defined in Rule 13a-15(e) or Rule 15d-15(e) of the Exchange Act. Management, including the Company’s Chief Executive Officer and Chief Financial Officer, concluded that the Company’s disclosure controls and procedures were effective, as of the end of the period covered by this report, at the reasonable assurance level.
Changes in Internal Control Over Financial Reporting
There have been no changes in internal control over financial reporting during the second quarter of 2024 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 second quarter of 2024 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 2023 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 2, 4 and 5 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 2023 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 and as supplemented below.
We have identified conditions or events that raise substantial doubt about our ability to continue as a going concern, and it is possible that any plan developed to alleviate such doubt may be unsuccessful. In addition, any capital raised may result in dilution to our current shareholders.
As described more fully in Note 1 of the Condensed Consolidated Financial Statements included herein, for the three and six months ended June 30, 2024, the Company incurred net losses of approximately $1.30 billion and $1.25 billion, respectively. For the three and six months ended June 30, 2024, the Utilities incurred net losses of approximately $1.23 billion and $1.19 billion, respectively. The net losses were primarily due to the accrual of estimated wildfire liabilities totaling approximately $1.71 billion related to the Maui windstorm and wildfire tort-related legal claims. This event has raised substantial doubt about the Company’s ability to continue as a going concern within one year after the date that the financial statements are issued. As of the date of filing of this Form 10-Q, management has not yet implemented a capital financing plan to address expected wildfire settlement payments. The Company expects to finance the settlement payments over time through a mix of debt, common equity, equity-linked securities or other potential options. There is no assurance that future financing will be available in sufficient amounts on a timely basis or on reasonable terms acceptable to us, if at all. If we raise funds by issuing equity or equity-linked securities, our shareholders may experience dilution. While management believes the Company will be able to raise the necessary capital, there is no assurance that management’s plans will be successful.
Substantial doubt about our ability to continue as a going concern may affect the price of our common stock, may impact our relationship with third parties with whom we do business, including our vendors, lenders and employees, may impact our ability to raise additional capital or refinance existing debt and may impact our ability to comply, going forward, with certain covenants in our debt agreements and/or satisfy conditions to draw thereunder, which could significantly and materially restrict our operations.
If a court-approved definitive settlement agreement to resolve Maui windstorm and wildfire tort-related legal claims is not obtained, or if financing for settlement payments is not available, we may need to consider other alternatives for addressing the outstanding legal claims or settlement payments, and such alternatives could adversely affect our financial results or other factors impacting our finances, operations or stock valuation.
As described more fully in Note 2 of the Condensed Consolidated Financial Statements included herein, the Company entered into an agreement in principle on August 2, 2024, to resolve all Maui windstorm and wildfire tort-related legal claims, including all claims among the defendants. Such agreement in principle is subject to reaching a definitive settlement agreement that is approved by the court, and is conditioned on a resolution of the claims of the insurance companies that have paid claims for property loss and other damages. If a final court-approved definitive settlement agreement is reached, the Company has agreed to make substantial payments to settle all Maui windstorm and wildfire tort-related legal claims. As described more fully in Note 2 of the Condensed Consolidated Financial Statements included herein, if a definitive settlement is not achieved, the Company intends to vigorously defend against the litigation. There is no assurance that the Company will be successful in the defense of the litigation or that insurance proceeds will be available to fund any potential settlements, judgments, or costs associated with the litigation.
If a court-approved definitive settlement agreement is reached, the Company expects to finance the settlement payments through a mix of debt, common equity, equity-linked securities or other potential options. While management believes the
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Company will be able to raise the capital necessary to finance the settlement payments, there is no assurance that future financing will be available in sufficient amounts, on a timely basis or on reasonable terms acceptable to us, if at all.
If the Company’s financing plans are unsuccessful, we may need to consider other strategic alternatives, including delaying strategic initiatives, selling assets, or other strategic measures including, without limitation, obtaining relief under the U.S. Bankruptcy Code. Such alternatives could adversely affect our financial results or other factors impacting our finances, operations or stock valuation.
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Item 2. Unregistered Sales of Equity Securities, Use of Proceeds, and Issuer Purchases of Equity Securities
(c) Purchases of HEI common shares were made on the open market during the second quarter of 2024 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
April 1 to 30, 202440,583$10.49—NA
May 1 to 31, 202426,747$10.64—NA
June 1 to 30, 202436,733$9.87—NA
NA - Not applicable.
* Trades (total number of shares purchased) are reflected in the month in which the order is placed.
**The purchases were made to satisfy the requirements of the DRIP, the HEIRSP and the ASB 401(k) Plan for shares purchased for cash or by the reinvestment of dividends by participants under those plans and none of the purchases were made under publicly announced repurchase plans or programs. Average prices per share are calculated exclusive of any commissions payable to the brokers making the purchases for the DRIP, the HEIRSP and the ASB 401(k) Plan. Of the “Total number of shares purchased,” 18,335 of the 40,583 shares, 3,532 of the 26,747 shares and 9,262 of the 36,733 shares were purchased for the DRIP; 16,967 of the 40,583 shares, 20,283 of the 26,747 shares and 24,637 of the 36,733 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
 
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Scott W. H. Seu (HEI Chief Executive Officer)
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Scott T. DeGhetto (HEI Chief Financial Officer)
HEI Certification Pursuant to 18 U.S.C. Section 1350
HEI Exhibit 101.INSXBRL Instance Document - the instance document does not appear on the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document
HEI Exhibit 101.SCHInline XBRL Taxonomy Extension Schema Document
HEI Exhibit 101.CALInline XBRL Taxonomy Extension Calculation Linkbase Document
HEI Exhibit 101.DEFInline XBRL Taxonomy Extension Definition Linkbase Document
HEI Exhibit 101.LABInline XBRL Taxonomy Extension Label Linkbase Document
HEI Exhibit 101.PREInline XBRL Taxonomy Extension Presentation Linkbase Document
HEI Exhibit 104Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
ABL Credit Agreement, dated May 17, 2024, among HE AR BRWR LLC, as Borrower, the
Lenders (as defined in the agreement), Barclays Bank PLC, as Administrative Agent, Funding
Agent and Collateral Agent, Wells Fargo Bank, National Association as Co-Collateral Agent (incorporated by reference to Exhibit 10.1 to HEI’s Current Report on Form 8-K dated May 17, 2024, File no. 1-8503)
Purchase and Contribution Agreement among Hawaiian Electric Company, Inc., Maui Electric
Company, Limited, and Hawaii Electric Light Company, Inc, as Originators, Hawaiian Electric
Company, Inc., as Servicer, and HE AR INTER LLC, as Buyer, dated May 17, 2024 (incorporated by reference to Exhibit 10.2 to HEI’s Current Report on Form 8-K dated May 17, 2024, File no. 1-8503)
Borrower Purchase and Contribution Agreement among HE AR INTER LLC, as Seller,
Hawaiian Electric Company, Inc., as Servicer, and HE AR BRWR LLC, as Buyer, dated May
17, 2024 (incorporated by reference to Exhibit 10.3 to HEI’s Current Report on Form 8-K dated May 17, 2024, File no. 1-8503)
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Shelee M. T. Kimura (Hawaiian Electric Chief Executive Officer)
Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Paul K. Ito (Hawaiian Electric Chief Financial Officer)
Hawaiian Electric Certification Pursuant to 18 U.S.C. Section 1350


106

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/ Scott T. DeGhetto
 By/s/ Paul K. Ito
 
Scott T. DeGhetto
  Paul K. Ito
 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: August 9, 2024 Date: August 9, 2024

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