# HAWAIIAN ELECTRIC INDUSTRIES INC (HE) Informational only - not investment advice. CIK: 0000354707 SIC: 4911 Electric Services SIC breadcrumb: [Transportation, Communications, Electric, Gas, And Sanitary Services](/division/E/) > [Electric, Gas, And Sanitary Services](/major-group/49/) > [SIC 4911 Electric Services](/industry/4911/) Latest 10-K filed: 2026-02-27 SEC page: https://www.sec.gov/edgar/browse/?CIK=354707 Filing source: https://www.sec.gov/Archives/edgar/data/354707/000035470726000008/he-20251231.htm ## Selected Fundamentals | Metric | Value | Unit | FY | Filed | | --- | ---: | --- | ---: | --- | | Revenue | 3086896000 | USD | 2025 | 2026-02-27 | | Net income | 126281000 | USD | 2025 | 2026-02-27 | | Assets | 8922879000 | USD | 2025 | 2026-02-27 | ## Financials Annual standardized facts from SEC companyfacts as of latest extracted filing date 2026-02-27. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0000354707.json. Derived margins are computed from the extracted annual SEC facts. | Metric | 2008 | 2009 | 2010 | 2016 | 2017 | 2018 | 2019 | 2020 | 2021 | 2022 | 2023 | 2024 | 2025 | | --- | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | ---: | | Revenue | | | | 2,380,654,000 | 2,555,625,000 | 2,860,849,000 | 2,873,948,000 | 2,579,775,000 | 2,850,379,000 | 3,420,917,000 | 3,287,503,000 | 3,219,850,000 | 3,086,896,000 | | Net income | 90,278,000 | 83,011,000 | 113,535,000 | | | | | 199,714,000 | 248,056,000 | 243,028,000 | 201,128,000 | -1,424,119,000 | 126,281,000 | | Operating income | | | | 355,838,000 | 346,233,000 | 333,356,000 | 348,021,000 | 311,493,000 | 386,066,000 | 279,555,000 | 274,992,000 | -1,706,760,000 | 235,322,000 | | Diluted EPS | | | | 2.29 | 1.52 | 1.85 | 1.99 | 1.81 | 2.25 | 2.20 | 1.81 | -11.23 | 0.71 | | Assets | | | | 11,881,981,000 | 12,534,160,000 | 13,104,051,000 | 13,745,251,000 | 15,004,007,000 | 15,822,637,000 | 16,284,244,000 | 7,677,372,000 | 8,931,416,000 | 8,922,879,000 | | Liabilities | | | | 10,324,460,000 | 10,402,481,000 | 10,907,478,000 | 11,430,698,000 | 12,632,212,000 | 13,397,460,000 | 14,047,452,000 | 14,864,687,000 | 7,418,034,000 | 7,316,960,000 | | Stockholders' equity | | | | 2,066,753,000 | 2,097,386,000 | 2,162,280,000 | 2,280,260,000 | 2,337,502,000 | 2,390,884,000 | 2,202,499,000 | 2,344,841,000 | 1,479,089,000 | 1,605,919,000 | | Cash and cash equivalents | | | | | 261,881,000 | 169,208,000 | 196,813,000 | 341,421,000 | 305,551,000 | 43,728,000 | 244,091,000 | 750,535,000 | 501,778,000 | | Net margin | | | | | | | | 7.74% | 8.70% | 7.10% | 6.12% | -44.23% | 4.09% | | Operating margin | | | | 14.95% | 13.55% | 11.65% | 12.11% | 12.07% | 13.54% | 8.17% | 8.36% | -53.01% | 7.62% | ## Quarterly Quarterly standardized facts from SEC companyfacts as of latest extracted filing date 2026-05-08. Source: https://data.sec.gov/api/xbrl/companyfacts/CIK0000354707.json. Flow metrics use discrete quarter-length periods from 10-Q/10-Q/A filings. Q4 revenue and net income are derived only when annual FY and nine-month YTD facts exist for the same fiscal year; derived Q4 values are labeled. EPS Q4 is not derived. | Quarter | End date | Revenue | Net income | Diluted EPS | Method | | --- | --- | ---: | ---: | ---: | --- | | 2022-Q2 | 2022-06-30 | | | 0.48 | reported discrete quarter | | 2022-Q3 | 2022-09-30 | | | 0.57 | reported discrete quarter | | 2022-Q4 | 2022-12-31 | | 57,821,000 | | derived Q4 = FY annual - nine-month YTD | | 2023-Q1 | 2023-03-31 | | 55,194,000 | 0.50 | reported discrete quarter | | 2023-Q2 | 2023-06-30 | 895,685,000 | 55,083,000 | 0.50 | reported discrete quarter | | 2023-Q3 | 2023-09-30 | 901,873,000 | 41,589,000 | 0.37 | reported discrete quarter | | 2023-Q4 | 2023-12-31 | 956,371,000 | 49,262,000 | | derived Q4 = FY annual - nine-month YTD | | 2024-Q1 | 2024-03-31 | 897,158,000 | 42,595,000 | 0.38 | reported discrete quarter | | 2024-Q2 | 2024-06-30 | 897,360,000 | -1,295,011,000 | -11.74 | reported discrete quarter | | 2024-Q3 | 2024-09-30 | 938,383,000 | -103,931,000 | -0.91 | reported discrete quarter | | 2024-Q4 | 2024-12-31 | 486,949,000 | -67,772,000 | | derived Q4 = FY annual - nine-month YTD | | 2025-Q1 | 2025-03-31 | 744,070,000 | 27,144,000 | 0.15 | reported discrete quarter | | 2025-Q2 | 2025-06-30 | 746,392,000 | | 0.15 | reported discrete quarter | | 2025-Q3 | 2025-09-30 | 790,610,000 | | 0.18 | reported discrete quarter | | 2025-Q4 | 2025-12-31 | 805,824,000 | 41,361,000 | | derived Q4 = FY annual - nine-month YTD | | 2026-Q1 | 2026-03-31 | 746,447,000 | 30,450,000 | 0.18 | reported discrete quarter | ## Macro Cross-References - [CPIAUCSL](/indicator/CPIAUCSL/): Consumer Price Index for All Urban Consumers: All Items in U.S. City Average - [UNRATE](/indicator/UNRATE/): Unemployment Rate - [FEDFUNDS](/indicator/FEDFUNDS/): Federal Funds Effective Rate - [CES0500000003](/indicator/CES0500000003/): Average Hourly Earnings of All Employees, Total Private - [DFEDTARU](/indicator/DFEDTARU/): Federal Funds Target Range - Upper Limit - [DFEDTARL](/indicator/DFEDTARL/): Federal Funds Target Range - Lower Limit - [DGS3MO](/indicator/DGS3MO/): Market Yield on U.S. Treasury Securities at 3-Month Constant Maturity - [DGS2](/indicator/DGS2/): Market Yield on U.S. Treasury Securities at 2-Year Constant Maturity - [DGS10](/indicator/DGS10/): Market Yield on U.S. Treasury Securities at 10-Year Constant Maturity - [DGS30](/indicator/DGS30/): Market Yield on U.S. Treasury Securities at 30-Year Constant Maturity - [T10Y2Y](/indicator/T10Y2Y/): 10-Year Treasury Constant Maturity Minus 2-Year Treasury Constant Maturity - [CPILFESL](/indicator/CPILFESL/): Consumer Price Index for All Urban Consumers: All Items Less Food and Energy - [CPIUFDSL](/indicator/CPIUFDSL/): Consumer Price Index for All Urban Consumers: Food - [CPIENGSL](/indicator/CPIENGSL/): Consumer Price Index for All Urban Consumers: Energy - [CUSR0000SAH1](/indicator/CUSR0000SAH1/): Consumer Price Index for All Urban Consumers: Shelter - [PCEPI](/indicator/PCEPI/): Personal Consumption Expenditures: Chain-type Price Index - [PCEPILFE](/indicator/PCEPILFE/): Personal Consumption Expenditures Excluding Food and Energy: Chain-type Price Index - [PPIACO](/indicator/PPIACO/): Producer Price Index by Commodity: All Commodities - [T10YIE](/indicator/T10YIE/): 10-Year Breakeven Inflation Rate - [U6RATE](/indicator/U6RATE/): Total Unemployed, Plus All Marginally Attached Workers Plus Total Employed Part Time for Economic Reasons - [PAYEMS](/indicator/PAYEMS/): All Employees, Total Nonfarm - [CIVPART](/indicator/CIVPART/): Labor Force Participation Rate - [EMRATIO](/indicator/EMRATIO/): Employment-Population Ratio - [UNEMPLOY](/indicator/UNEMPLOY/): Unemployed - [CE16OV](/indicator/CE16OV/): Employment Level - [ICSA](/indicator/ICSA/): Initial Claims - [JTSJOL](/indicator/JTSJOL/): Job Openings: Total Nonfarm - [JTSQUR](/indicator/JTSQUR/): Quits: Total Nonfarm - [GDPC1](/indicator/GDPC1/): Real Gross Domestic Product - [A191RL1Q225SBEA](/indicator/A191RL1Q225SBEA/): Real Gross Domestic Product: Percent Change from Preceding Period - [INDPRO](/indicator/INDPRO/): Industrial Production: Total Index - [TCU](/indicator/TCU/): Capacity Utilization: Total Index - [HOUST](/indicator/HOUST/): New Privately-Owned Housing Units Started: Total Units - [PERMIT](/indicator/PERMIT/): New Privately-Owned Housing Units Authorized in Permit-Issuing Places: Total Units - [RSAFS](/indicator/RSAFS/): Advance Retail Sales: Retail Trade - [PCE](/indicator/PCE/): Personal Consumption Expenditures - [DSPIC96](/indicator/DSPIC96/): Real Disposable Personal Income - [PSAVERT](/indicator/PSAVERT/): Personal Saving Rate - [M2SL](/indicator/M2SL/): M2 - [BOPGSTB](/indicator/BOPGSTB/): U.S. International Trade in Goods and Services: Balance - [MSPUS](/indicator/MSPUS/): Median Sales Price of Houses Sold for the United States - [HSN1F](/indicator/HSN1F/): New One Family Houses Sold: United States - [RHORUSQ156N](/indicator/RHORUSQ156N/): Homeownership Rate in the United States - [TTLCONS](/indicator/TTLCONS/): Total Construction Spending: Total Construction in the United States - [RRVRUSQ156N](/indicator/RRVRUSQ156N/): Rental Vacancy Rate in the United States - [TOTALSL](/indicator/TOTALSL/): Total Consumer Credit Owned and Securitized - [REVOLSL](/indicator/REVOLSL/): Revolving Consumer Credit Owned and Securitized - [DRCCLACBS](/indicator/DRCCLACBS/): Delinquency Rate on Credit Card Loans, All Commercial Banks - [GDP](/indicator/GDP/): Gross Domestic Product - [GPDI](/indicator/GPDI/): Gross Private Domestic Investment - [GCE](/indicator/GCE/): Government Consumption Expenditures and Gross Investment - [PCEC](/indicator/PCEC/): Personal Consumption Expenditures - [NETEXP](/indicator/NETEXP/): Net Exports of Goods and Services - [GFDEBTN](/indicator/GFDEBTN/): Federal Debt: Total Public Debt - [GFDEGDQ188S](/indicator/GFDEGDQ188S/): Federal Debt: Total Public Debt as Percent of Gross Domestic Product - [FYFSD](/indicator/FYFSD/): Federal Surplus or Deficit - [FGRECPT](/indicator/FGRECPT/): Federal Government Current Receipts - [FGEXPND](/indicator/FGEXPND/): Federal Government: Current Expenditures - [MANEMP](/indicator/MANEMP/): All Employees, Manufacturing - [USCONS](/indicator/USCONS/): All Employees, Construction - [USTRADE](/indicator/USTRADE/): All Employees, Retail Trade - [USFIRE](/indicator/USFIRE/): All Employees, Financial Activities - [USGOVT](/indicator/USGOVT/): All Employees, Government - [AWHAETP](/indicator/AWHAETP/): Average Weekly Hours of All Employees, Total Private - [DGORDER](/indicator/DGORDER/): Manufacturers' New Orders: Durable Goods - [NEWORDER](/indicator/NEWORDER/): Manufacturers' New Orders: Nondefense Capital Goods Excluding Aircraft - [BUSINV](/indicator/BUSINV/): Total Business Inventories - [EXPGS](/indicator/EXPGS/): Exports of Goods and Services - [IMPGS](/indicator/IMPGS/): Imports of Goods and Services - [IR](/indicator/IR/): Import Price Index (End Use): All Commodities - [PPIFIS](/indicator/PPIFIS/): Producer Price Index by Commodity: Final Demand ## Latest quarter (10-Q) Latest 10-Q source: https://www.sec.gov/Archives/edgar/data/354707/000035470726000037/he-20260331.htm Extracted between Part I Item 2 and the next Item 3/4 or Part II heading after HTML sanitization. Confidence: high Filing date: 2026-05-08 Report date: 2026-03-31 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 2025 Form 10-K and should be read in conjunction with such discussion and the 2025 annual consolidated financial statements of HEI and Hawaiian Electric and notes thereto included in HEI’s and Hawaiian Electric’s 2025 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. For discussion of the impacts of inflation and other macro-economic factors impacting the Utilities, see also “Recent developments” in Hawaiian Electric’s MD&A. See also “Economic conditions” below for further discussion of the economic impact of recent events, and Note 2 of the Condensed Consolidated Financial Statements for recent updates and disclosures relating to the Maui windstorm and wildfires. In June 2025, the Utilities submitted a request with the PUC to terminate or suspend the Affiliate Transaction Requirements (ATRs). Beginning in 2024 and continuing into 2026, HEI has embarked on a strategy to divest all of its affiliated companies other than the Utilities, intending for the Utilities to be HEI’s sole operating companies. Termination of the ATRs would allow implementation of a corporate integration, under which all HEI employees would move to Hawaiian Electric. A few officer positions would manage and operate both HEI and Hawaiian Electric (dual-hatted executives) and the HEI and Hawaiian Electric boards of directors would be composed of a single set of individuals. On October 31, 2025, HEI and Hawaiian Electric filed a revised request, after a September 2025 PUC order that provided guidance on the topics to be addressed in such a request. On March 23, 2026, the PUC issued an order approving the application of HEI and Hawaiian Electric to suspend the ATRs. The PUC’s approval is subject to specified commitments, including HEI’s divestment of all remaining Pacific Current and affiliated assets, a prohibition on pursuing new diversification activities, continued compliance with Hawaii Revised Statutes Section 269-19.5 governing affiliated interests, and ongoing cooperation with the PUC, including reporting obligations. HEI is required to file a report establishing a divestment timeline and to provide monthly progress reports thereafter. The order also requires advance notice to the PUC and Consumer Advocate prior to seeking any change in recovery of HEI-related expenses in future re-basing or rate proceedings. The PUC subsequently issued an order confirming that all ATR compliance filings and reporting are likewise suspended and closed the docket. RESULTS OF OPERATIONS Three months ended March 31 % (in thousands) 2026 2025 change Primary reason(s)1 Revenues $ 746,447  $ 744,070  —  Increase in the electric utility, partly offset by a decrease in the all other segment. Operating income 53,377  62,420  (14) Lower operating income for the electric utility, partly offset by lower operating loss for the all other segment. Net income for common stock 30,450  26,671  14  Lower net loss for the all other segment primarily due to the sale of Hamakua Holdings at Pacific Current in March 2025, partly offset by lower net income for the electric utility. 1    Also, see the all other segment discussion below. The Company’s effective tax rates for the three months ended March 31, 2026 and 2025 were 21% and 19%, respectively. The increase in the effective tax rate was primarily due to the non-recurrence of a discrete tax benefit recognized in the prior-year period related to the sale of Hamakua Holdings. Excluding this discrete item, the effective tax rates for both periods were comparable. 42 Maui windstorm and wildfires related expenses, net. For the three months ended March 31, 2026 and 2025, the Company’s incremental expenses related to the Maui windstorm and wildfires as discussed in Note 2 of the Condensed Consolidated Financial Statements, were as follows: Three months ended March 31, 2026 (in thousands) Electric utility All other HEI consolidated Maui windstorm and wildfires related expenses: Legal expenses $ 1,455  $ 452  $ 1,907  Other expense —  108  108  Total Maui windstorm and wildfires related expenses 1,455  560  2,015  Insurance recoveries (961) (371) (1,332) Total Maui windstorm and wildfires related expenses, net of insurance recoveries $ 494  $ 189  $ 683  Three months ended March 31, 2025 (in thousands) Electric utility All other HEI consolidated Maui windstorm and wildfires related expenses: Legal expenses $ 3,849  $ 5,001  $ 8,850  Outside services expense —  124  124  Other expense 5,695  233  5,928  Interest expense 1,752  279  2,031  Total Maui windstorm and wildfires related expenses 11,296  5,637  16,933  Insurance recoveries (3,064) (3,658) (6,722) Deferral treatment approved by the PUC1 (5,683) —  (5,683) Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment $ 2,549  $ 1,979  $ 4,528  1    Pursuant to the PUC order received on February 12, 2025, deferral accounting treatment limited to insurance premiums and outside services and legal costs associated with the asset-based lending facility credit agreement incurred in 2025 was granted. Applicable amounts were deferred to a regulatory asset. See “Risk Factors” in Item 1A. for further discussion of regulatory risks. See Note 2 of the Condensed Consolidated Financial Statements. Note: The all other segment Maui windstorm and wildfires related expenses (legal, outside services and other) and insurance recoveries are included in “Expenses-Other” and interest expense is included in “Interest expense, net” on the HEI and subsidiaries Condensed Consolidated Statements of Income. See Electric utility section below for more detail. From August 8, 2023 through March 31, 2026, HEI and its subsidiaries have incurred approximately $2.27 billion of Maui windstorm and wildfires related expenses, including the Utilities’ estimate of the losses related to a settlement of all wildfire tort-related legal claims and cross claims, the One ‘Ohana Initiative contribution and $47.8 million related to the securities class action settlement. Certain of these costs are reimbursable under excess liability insurance, professional liability insurance and directors and officers liability insurance policies. As of March 31, 2026, HEI and its subsidiaries have approximately $9 million, nil and $70 million of insurance coverage remaining under the excess liability, professional liability and directors and officers liability policies, respectively, after deducting applicable retention amounts, amounts that have been recovered under insurance policies (including the One ‘Ohana Initiative contribution), and amounts expected to be recovered for incurred costs, including the securities class action settlement, and recognized as a receivable as of the quarter end. On April 10, 2026, the last condition to the finalization of the tort settlement agreements and first installment payment was satisfied when the last insurer agreed to a stipulation withdrawing with prejudice the appeal of the December 30, 2025 summary judgment entered in favor of HEI, Hawaiian Electric and other defendants. As a result, the Company paid the first of its four equal annual $479 million installments pursuant to the settlement agreements and has initiated efforts to recover the remaining unpaid insurance coverage under its excess liability policy. 43 Economic conditions. Note: The statistical data in this section is from public third-party sources that management believes to be reliable (e.g., Board of Governors of the Federal Reserve System, Department of Business, Economic Development and Tourism, University of Hawaii Economic Research Organization (UHERO), U.S. Bureau of Labor Statistics, Honolulu Board of REALTORS®, and U.S. Energy Information Administration). In the first quarter of 2026, the average daily passenger count was 2.7% 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, including Japanese travelers, remaining at lower levels. In the first quarter, international visitor arrivals (excluding Japan) remained 20.1% below 2019 levels. Due to the weak yen, Japanese visitors are 38.6% below 2019 levels. Hawaii’s preliminary seasonally adjusted unemployment rate in February 2026 was 2.3%, which was a decrease from the February 2025 rate of 2.6%. The national unemployment rate in March 2026 was 4.3%, slightly higher than the March 2025 rate of 4.2%. According to a recent forecast by UHERO, issued on February 27, 2026, jobs in the State will increase by 0.2% in 2026. Hawaii real estate activity through March 2026, as indicated by Oahu’s home resale market, resulted in no change in the median sales price for condominiums and an increase of 2.6% for single-family homes compared to the same period in 2025. The median single-family home price was $1,205,000 in February 2026 and $1,199,500 in March 2026, both exceeding the previous all-time high of $1,185,000, set in February 2025. The number of closed sales through March 2026 saw a 3.6% decrease for condominiums and a 10.9% increase for single-family residential homes compared to the same period in 2025. Hawaii’s petroleum product prices are correlated to the crude oil price in international markets. The price of crude oil has increased 5.8% over the same quarter in the prior year. At its March 18, 2026 meeting, the Federal Open Market Committee (FOMC) decided to maintain the federal funds rate target range at 3.5% to 3.75%. The FOMC noted that uncertainty around the economic outlook remains elevated, and that the implications of developments in the Middle East for the U.S. economy are uncertain. UHERO forecasts full year 2026 real GDP to increase 1.6%, real personal income to increase 0.9%, a decrease in total visitor arrivals of 0.6%, and an unemployment rate of 2.3% for the State. According to UHERO, Hawaii’s economy is gradually moving beyond a mild jobs recession in 2025 as payrolls have begun to edge upward, supported by a resilient U.S. economy and the local construction industry. See also “Recent Developments” in the “Electric utility” section below for further discussion of the economic impact of recent events. All other segment. The all other business segment loss includes results of the stand-alone corporate operations of HEI, ASB Hawaii, GLST1 and Pacific Current, including the results of Hamakua Energy and the solar and battery energy storage system facilities up until the close of their respective sales in 2025. Three months ended March 31 (in thousands) 2026 2025 Change Primary reason(s) Revenues $ 2,407  $ 5,704  $ (3,297) The revenues for the first three months of 2026 were lower than the comparable period in 2025 primarily due to lower revenues at Mahipapa and the sale of Hamakua Holdings in March 2025 and the solar and BESS facilities at Pacific Current1 in August 2025. Operating loss (9,156) (13,517) 4,361  The first three months of 2026 and 2025 include $2.4 million and $5.2 million of operating loss, respectively, from Pacific Current1. The lower operating loss at Pacific Current is primarily due to the operating loss at Hamakua Holdings which was sold in March 2025. Corporate expenses for the first three months of 2026 were $1.7 million lower than the same period in 2025, primarily due to lower wildfire legal and other expenses. Net loss (4,893) (21,145) 16,252 [Excerpt truncated for page length; source filing is linked above.] ## Latest 10-K MD&A Extracted between Item 7 and the next Item 7A/8 heading after HTML sanitization. Confidence: high ITEM 7.    MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS HEI and Hawaiian Electric (in the case of Hawaiian Electric, only the information related to Hawaiian Electric and its subsidiaries): The following discussion should be read in conjunction with the Consolidated Financial Statements and the related Notes that appear in Item 8 of this report. For information on factors that may cause HEI’s and Hawaiian Electric’s actual future results to differ from those currently contemplated by the relevant forward-looking statements, see “Cautionary Note Regarding Forward-Looking Statements” at the front of this report and “Risk Factors” in Item 1A. The general discussion of HEI’s consolidated results should be read in conjunction with the Electric utility discussion that follows. HEI Consolidated Executive overview and strategy.  HEI is a holding company with operations primarily focused on Hawaii’s electric utility sector after selling its bank operations on December 31, 2024. In 2017, HEI formed Pacific Current to make investments in non-regulated renewable energy and sustainable infrastructure projects. On December 30, 2024, HEI, ASB, and ASB Hawaii, a wholly owned subsidiary of HEI and ASB’s parent holding company, entered into investment agreements to sell 90.1% of the common stock of ASB to various investors, including certain ASB officers and directors of ASB. The sale transaction closed on December 31, 2024 and no investor acquired more than 9.9% of the common stock of ASB. The proceeds from the sale were used to repay a ratable portion of each of HEI’s senior notes in April 2025. Subsequent to the sale, HEI has one reportable segment: Electric utility. HEI and its other subsidiaries which are not reportable segments are grouped and reported as an “All Other” non-reportable segment. Electric utility. Hawaiian Electric, Hawaii Electric Light and Maui Electric (Utilities) are regulated operating electric public utilities engaged in the production, purchase, transmission, distribution and sale of electricity on the islands of Oahu; Hawaii; and Maui, Lanai and Molokai, respectively. All Other. The All Other segment primarily comprises the results of Pacific Current, which invested in non-regulated clean energy and sustainable infrastructure in the State of Hawaii to help reach the state’s sustainability goals, and HEI’s corporate-level operating, general and administrative expenses. Subsequent to the Maui windstorm and wildfires, HEI and Pacific Current have suspended new investments and undertook a comprehensive review of strategic options for the assets of Pacific Current. As part of HEI’s comprehensive review of strategic options for Pacific Current, all investments of Pacific Current that were made through its subsidiaries were sold in 2025, except for Mahipapa, its remaining operating subsidiary which is in the process of being sold. The All Other segment also includes ASB Hawaii, which previously owned ASB, and a 40% interest in GLST1, an entity created for the specific purpose of holding HEI’s and Hawaiian Electric’s first liability installment payment pursuant to the settlement agreements to settle the tort-related claims in the litigation arising out of the Maui windstorm and wildfires. A major focus of HEI’s financial strategy is to grow core earnings/profitability at the Utilities in a controlled risk manner and optimize operating, capital and tax efficiencies in order to support its dividend and deliver shareholder value. HEI also continues to work on strategic financing plans to raise capital necessary to fund the settlement of wildfire tort claims. Recent developments. See also “Recent developments” in Hawaiian Electric’s MD&A and Note 2 of the Consolidated Financial Statements which includes recent updates and disclosures relating to the Maui windstorm and wildfires. On September 5, 2025, HEI and Hawaiian Electric each amended their senior unsecured revolving credit facility (the HEI Revolving Facility and the Hawaiian Electric Revolving Facility, respectively) resulting in increased borrowing capacities and available liquidity. HEI increased its revolving commitments available under the HEI Revolving Facility to $300 million from $175 million and extended the termination date to September 5, 2030 from May 14, 2027. Hawaiian Electric increased its revolving commitments available under the Hawaiian Electric Revolving Facility to $300 million from $200 million and extended the termination date to September 4, 2026, subject to an automatic extension to the earlier of (i) such date specified in a final order or approval of the PUC and (ii) if such order or approval is obtained, September 5, 2030. The Hawaiian Electric Revolving Facility also allows for commitment increases of up to an additional $75 million, subject to customary conditions. Refer to Note 6 of the Consolidated Financial Statements for additional terms of the amended credit facilities. In addition, on September 18, 2025, Hawaiian Electric issued $500 million in unsecured senior notes with an interest rate of 6.00% and maturing on October 1, 2033 (refer to Note 7 of the Consolidated Financial Statements for additional terms of the unsecured senior notes). A portion of the proceeds was used to repay the outstanding balance of the Utilities’ revolving and term loan facilities and the remaining proceeds are intended to be used to 1) finance capital expenditures, 2) repay long-term debt and short-term debt used to finance or refinance capital expenditures, and 3) reimburse funds used for the payment of capital expenditures. 30 In June 2025, the Utilities submitted a request with the PUC to terminate or suspend the ATRs. Beginning in 2024 and continuing into 2026, HEI has embarked on a strategy to divest all of its affiliated companies other than the Utilities, intending for the Utilities to be HEI’s sole operating companies. Termination of the ATRs would allow implementation of a corporate integration, under which all HEI employees would move to Hawaiian Electric. A few officer positions would manage and operate both HEI and Hawaiian Electric (dual-hatted executives) and the HEI and Hawaiian Electric boards of directors would be composed of a single set of individuals. In September 2025, the PUC dismissed the request without prejudice. In its order, the PUC provided guidance on the topics to be addressed in any future request. On October 31, 2025 HEI and Hawaiian Electric filed a revised request with the PUC to terminate or suspend the ATRs. After responding to information requests from the Consumer Advocate, the Consumer Advocate issued its statement of position on February 4, 2026. The Consumer Advocate supported the approval of the request with the condition that before any recovery of expenses related to HEI, the Utilities should give the Consumer Advocate and the PUC advance notice of likely changes to recovery. HEI and Hawaiian Electric informed the PUC that the docket was ready for decision making on February 5, 2026. Following a hearing on December 17, 2025, at which the court orally granted final approval of the Class Settlement Agreement and no class member objected, the Maui Circuit Court entered a written order granting such final approval on January 26, 2026. The deadline to file appeals from that order was February 25, 2026, and as of February 26, 2026, no appeal appeared on the docket. As it appears no party appealed the final approval of the Class Settlement Agreement, it appears that such final approval order is now final and unappealable. The tort Settlement Agreements do not resolve claims with insurers who have asserted or could assert subrogation claims in separate lawsuits, and such insurers are not parties to the Settlement Agreements, but resolving such claims in the manner set forth in the Settlement Agreements (summarized below) is a condition that must be satisfied before any payment is due from the defendants. On December 30, 2025, the court entered judgment in favor of the defendants in the two principal direct subrogation actions brought by various insurers as to all direct subrogation claims except for 16 such claims associated with insureds who had opted out of the class settlement and had not yet settled. On January 21, 2026, certain plaintiff insurers appealed the grant of summary judgment in these two actions. No briefing schedules in these appeals have been set. On November 5, 2025, the parties signed a binding term sheet to settle the Securities Action (the Securities Action Term Sheet) following negotiations facilitated by a mediator. On January 5, 2026, the parties executed a definitive stipulation of settlement (the Securities Action Stipulation of Settlement) that will provide for the complete resolution of the Securities Action in exchange for a payment by the Company of $47.8 million as part of the overall settlement described below. The settlement of the Securities Action is conditioned on, among other things, approval by the boards of the Company and Hawaiian Electric; the finalization and court approval of the Securities Actions stipulation of settlement; the finalization by February 26, 2026 and subsequent court approval of the stipulation of settlement in the Derivative Actions (defined and discussed below); and entry of a judgment of dismissal following final court approval. In connection with the settlement of the Securities Action, there will be no admission of liability by the Company or any defendants and the Company, the defendants, and related persons will receive a customary full release of all claims. On February 26, 2026, the United States District Court for the Northern District of California held a hearing to determine whether to preliminarily approve the Securities Action Stipulation of Settlement. Following the hearing, the court indicated that it will issue an order and set a hearing date for the final approval of the settlement. In connection with the execution of the Securities Action Term Sheet, HEI accrued, as of December 31, 2025, $47.8 million, and concurrently recorded an insurance reimbursement receivable of an equivalent amount as the recovery of the agreed settlement payment under its directors and officers liability insurance policy is deemed probable. In addition, on November 5, 2025, the parties signed a binding term sheet (the Derivative Litigation Term Sheet) to settle all of the outstanding derivative actions described above (the Derivative Actions). The Derivative Litigation Term Sheet was signed following negotiations facilitated by a mediator. On December 31, 2025, the parties executed a definitive settlement agreement (the Derivative Litigation Settlement Agreement) that provides for a complete resolution of the claims asserted in the Derivative Actions in exchange for a payment on behalf of the individual defendants by the Company’s insurers in the amount of $100 million, which will be used in part to pay the $47.8 million for the Securities Action Stipulation of Settlement and fees and expenses for plaintiffs’ counsel. The settlement of the Derivative Actions is conditioned on, among other things, the approval by the boards of HEI and Hawaiian Electric (including their independent directors) of the Derivative Litigation Settlement Agreement; final court approval of the Derivative Litigation Settlement Agreement; and entry of final judgment and orders of dismissal in the Derivative Actions. The plaintiffs’ counsel intends to request court approval for attorneys’ fees of 25% of the settlement proceeds, plus expenses not to exceed $475,000. In connection with the settlement of the Derivative Actions, there will be no admissions of liability, and the defendants and related persons will receive a customary full release of all claims. On March 9, 2026, the United States District Court for the District of Hawaii is scheduled to hold a hearing to determine whether to preliminarily approve the Derivative Litigation Settlement Agreement. The Derivative Litigation Settlement Agreement calls for the settlement to be fully funded by the Company’s directors and officers liability insurance policies. As noted above, $47.8 million of the $100 million total will be used to fund the settlement 31 of the Securities Action. The remaining amount, any award in the Derivative Actions for the plaintiffs’ attorneys’ fees and expenses, and payment of other settlement-related expenses provided for in the term sheet, is accounted for as a contingent gain which will be recognized when realized or realizable. On February 13, 2026, Hawaiian Electric Industries, Inc., Hawaiian Electric Company, Inc., and Maui Electric Company, Limited (collectively, the Hawaiian Electric Plaintiffs) filed suit against five of their insurers: Defendants XL Insurance Company of America, Inc., Allianz Global Risks US Insurance Company, the Princeton Excess and Surplus Lines Insurance Company, and General Security Indemnity Company of Arizona (the Insurers). The Insurers are commercial property insurers that insured the Hawaiian Electric Plaintiffs at the time of the August 2023 Maui windstorm and wildfires. The Insurers have acknowledged coverage under the policies at issue for loss or damage to the Hawaiian Electric Defendants’ property and have paid a portion of the companies’ losses. However, the parties dispute the extent of the damage, the nature of coverage, and apportionment under the policies. Therefore, the Hawaiian Electric Plaintiffs seek declaratory relief regarding the extent of the Insurers’ obligations under the policies, as well as a determination that the Insurers have breached the policies. Sustainability. At HEI, sustainability principles have long been embedded as applicable within the Company’s activities and are integral to the Company’s efforts to create value for all of its stakeholders. With all of its operations isolated in the middle of the Pacific Ocean, the Company’s long-term health and financial performance are inextricably linked with the strength of the Hawaii economy, its communities, and the environment. That is why long-term shareholder and broader stakeholder value are both served by the Company’s efforts to serve as a catalyst for a better Hawaii. In 2021, the Company identified a number of priorities that reflect the essential connection between the health of Hawaii’s environment, economy and communities and HEI’s long-term success. Those sustainability priorities included: •decarbonizing the Company’s operations and the broader Hawaii economy; •promoting Hawaii’s economic health and improving affordability for all residents; •ensuring resilience, including safety, as the Company adapts to evolving climate dynamics, which are exacerbating conditions that can lead to increasing risk of droughts, severe storms, flooding, wildfires and other extreme weather events and natural disasters; •maintaining resilience as the Company navigates the clean energy transition; •advancing digitalization of the Company’s operations to better serve customers and increase efficiency while protecting against cyber-security challenges; •promoting inclusion both within the Company and in the ways the Company interacts with and impacts external stakeholders; •increasing employee engagement; and •identifying and integrating climate-related risks and opportunities throughout the Company’s planning and decision-making. The Company has integrated sustainability considerations as appropriate into governance structures, strategies and risk management. This includes: •full HEI Board review of sustainability-related strategies, Audit & Risk Committee oversight of sustainability-related risks, Compensation & Human Capital Management Committee responsibility for sustainability-related compensation matters and human capital management and Nominating and Corporate Governance Committee responsibility for ensuring an appropriate board governance framework is in place with respect to sustainability. •robust sustainability and risk management expertise among board members, including directors with direct experience in renewable energy, policy and strategy in the context of evolving climate dynamics, and risk and environmental management. •sustainability goals incorporated as part of HEI and Utility executive incentive compensation as appropriate. •sustainability considerations explicitly woven into strategic planning efforts and enterprise risk management processes. The Company is committed to transparency and providing information to allow customers, community leaders, investors and other stakeholders to understand how the Company’s strategies and operations advance sustainability and long-term stakeholder value creation. The Company issued its first consolidated sustainability report in September 2020. The report was aligned with Sustainability Accounting Standards Board guidance. The Company has since further developed its sustainability reporting to include disclosures regarding risks and opportunities related to evolving climate dynamics, as well as associated risk management and governance processes, based on recommendations from the Task Force on Climate-related Financial Disclosures. It has also outlined key impacts for the Company under two climate scenarios, including a scenario targeted to limit global temperature rise to two degrees Celsius or lower. The Company’s most recent reports include HEI’s enterprise- 32 wide GHG emissions inventory. Net enterprise-wide GHG emissions in measured categories have decreased over time, driven largely by reductions in the utility’s generation-related emissions intensity. The Company’s sustainability reports can be found at www.hei.com/sustainability. HEI consolidated results of operations. (dollars in millions, except per share amounts) 2025 % change 2024 % change 2023 Revenues $ 3,087  (4) $ 3,220  (2) $ 3,288  Operating income (loss) 235  NM (1,707) NM 275  Income (loss) from continuing operations for common stock $ 123  NM $ (1,323) NM $ 146  Income (loss) from discontinued operations1 —  100  (103) NM 53  Net income (loss) for common stock $ 123  NM $ (1,426) NM $ 199  Net income (loss) by segment: Electric utility $ 168  NM $ (1,226) NM $ 194  Other (45) 53  (96) (100) (48) Income (loss) from continuing operations for common stock $ 123  NM $ (1,323) NM $ 146  Continuing operations - Basic earnings (loss) per common share $ 0.71  NM $ (10.42) NM $ 1.33  Discontinued operations - Basic earnings (loss) per common share1 —  100  (0.81) NM 0.49  Basic earnings (loss) per share $ 0.71  NM $ (11.23) NM $ 1.82  Continuing operations - Diluted earnings (loss) per common share $ 0.71  NM $ (10.42) NM $ 1.33  Discontinued operations - Diluted earnings (loss) per common share1 —  100  (0.81) NM 0.48  Diluted earnings (loss) per share $ 0.71  NM $ (11.23) NM $ 1.81  Dividends per share $ —  —  $ —  (100) $ 1.08  Weighted-average number of common shares outstanding (millions) 172.6  36  126.9  16  109.7  Dividend payout ratio — % — % 59 % 1     Includes the results of ASB’s operations through the date of the sale of the common shares, and the loss on the sale of the common shares. See Note 5 of the Consolidated Financial Statements for more information. Note: Totals may not foot due to rounding. In 2025, income (loss) from continuing operations for HEI common stock increased to $123 million compared to $(1,323) million in 2024, due to $1,395 million lower net income in 2024 at the Utilities as a result of recording $1,875 million of provision, net, for wildfire tort-related claims in 2024. In 2024, income (loss) from continuing operations for HEI common stock decreased to $(1,323) million compared to $146 million in 2023, due to $(1,420) million lower net income at the Utilities as a result of recording $1,875 million of provision, net, for wildfire tort-related claims in 2024. See “Electric utility” and “HEI Consolidated—All Other segment” sections below for additional information on year-to-year fluctuations. The Company’s effective tax rate (combined federal and state income tax rates) was 24% (tax expense) in 2025, compared to 26% (tax benefit) in 2024. The Company’s effective tax rate was lower than 2024 primarily due to the substantial pre-tax loss in 2024 resulting from the Utilities’ accrual of the loss contingencies related to the wildfire tort-related claims and because the impact of permanent items had a smaller impact on the effective tax rate in 2024, partially offset by recapture of investment tax credits and lower research and development tax credit claims in 2025. 33 Maui windstorm and wildfires related expenses, net. The Company’s incremental expenses related to the Maui windstorm and wildfires, as discussed in Note 2 of the Consolidated Financial Statements, for the years ended December 31, 2025, 2024 and 2023 were as follows: Year ended December 31, 2025 (in thousands) Electric utility All Other segment HEI Consolidated Maui windstorm and wildfires related expenses: Legal expenses $ 15,685  $ 8,698  $ 24,383  Outside services expense —  135  135  Wildfire securities-related claims —  47,750  47,750  Other expense 23,295  522  23,817  Interest expense 2,543  848  3,391  Total Maui windstorm and wildfires related expenses 41,523  57,953  99,476  Insurance recoveries1 (1,129) (54,049) (55,178) Deferral treatment approved by the PUC2 (27,826) —  (27,826) Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment $ 12,568  $ 3,904  $ 16,472  Year ended December 31, 2024 (in thousands) Electric utility All Other segment HEI Consolidated5 Maui windstorm and wildfires related expenses: Legal expenses $ 51,406  $ 18,373  $ 69,779  Outside services expense 8,500  2,514  11,014  Wildfire tort-related claims3 1,915,000  —  1,915,000  Other expense4 32,753  2,650  35,403  Interest expense 11,168  3,666  14,834  Total Maui windstorm and wildfires related expenses 2,018,827  27,203  2,046,030  Insurance recoveries (85,781) (8,918) (94,699) Deferral treatment approved by the PUC2 (37,960) —  (37,960) Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment $ 1,895,086  $ 18,285  $ 1,913,371  Year ended December 31, 2023 (in thousands) Electric utility All Other segment HEI Consolidated5 Maui windstorm and wildfires related expenses: Legal expenses $ 24,737  $ 9,232  $ 33,969  Outside services expense 10,532  1,492  12,024  Wildfire tort-related claims 75,000  —  75,000  Other expense 3,316  203  3,519  Interest expense 1,223  1,377  2,600  Total Maui windstorm and wildfires related expenses 114,808  12,304  127,112  Insurance recoveries (98,613) (5,967) (104,580) Deferral treatment approved by the PUC2 (14,692) —  (14,692) Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment $ 1,503  $ 6,337  $ 7,840  1    HEI consolidated includes insurance recovery related to the proposed settlement of the securities class action of $47.8 million for 2025. Also, includes adjustments related to costs that are no longer probable of recovery under the insurance policies. For 2025, HEI consolidated and Electric utility adjustments amount to $7.6 million of which, $4.5 million were deferred to a regulatory asset, and are reported on the line “Deferral treatment approved by the PUC.” 2    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 incurred through December 31, 2024. Pursuant to the PUC order received on February 12, 2025, 34 deferral accounting treatment limited to insurance premiums and outside services and legal costs associated with the asset-based lending facility credit agreement incurred in 2025 was granted. Applicable amounts were deferred to a regulatory asset. See “Risk Factors” in Item 1A. for further discussion of regulatory risks. See Note 2 of the Consolidated Financial Statements. 3    Represents the provision to record the Utilities’ settlement of all wildfire tort-related legal claims and cross claims as of December 31, 2024. See Note 2 of the Consolidated Financial Statements. 4    Includes $18.4 million ($16.6 million by the Utilities) pursuant to an agreement to settle indemnification claims asserted by the State of Hawaii, for 2024. Also includes $3.5 million accrual related to the Utilities’ share of settlement administration fees for 2024. See Note 2 of the Consolidated Financial Statements. 5    Excludes expenses related to discontinued operations amounting to $1.3 million and $11.3 million for 2024 and 2023, respectively. Note: All Other segment Maui windstorm and wildfires related expenses (legal, outside services, wildfire securities-related claims and other) and insurance recoveries are included in “Expenses-Other” and interest expense is included in “Interest expense, net” on the HEI and subsidiaries Consolidated Statements of Income. See Electric utility section below for more detail. From August 8, 2023 through December 31, 2025, HEI and its subsidiaries have incurred approximately $2.3 billion of Maui windstorm and wildfires related expenses, including the Utilities’ estimate of the losses related to a settlement of all wildfire tort-related legal claims and cross claims, the One ‘Ohana Initiative contribution and $47.8 million related to the securities class action settlement. Certain of these costs are reimbursable under excess liability insurance, professional liability insurance, and directors and officers liability insurance policies. As of December 31, 2025, HEI and its subsidiaries have approximately $10 million, nil and $71 million of insurance coverage remaining under the excess liability, professional liability, and directors and officers liability policies, respectively, after deducting applicable retention amounts, amounts that have been recovered under insurance policies (including the One ‘Ohana Initiative contribution), and amounts expected to be recovered for incurred costs, including the securities class action settlement, and recognized as a receivable as of year-end. With the Company accruing its losses related to a settlement of all wildfire tort-related legal claims and cross claims as of December 31, 2025, the Company expects the Electric utility and HEI to use the remaining $10 million of insurance coverage under its excess liability policy primarily for legal expenditures, in excess of amounts deferred, in connection with the Maui windstorm and wildfires. 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 fourth quarter of 2025, the average daily passenger count was 2.0% 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, including Japanese travelers, remaining at lower levels. In the fourth quarter, international visitor arrivals (excluding Japan) remained 18.0% below 2019 levels. Due to the weak yen, Japanese visitors are 36.6% below 2019 levels. Hawaii’s seasonally adjusted unemployment rate in December 2025 was 2.2%, lower than the December 2024 rate of 3.0%. The national unemployment rate in December 2025 was 4.4%, slightly higher than the December 2024 rate of 4.1%. According to a recent forecast by UHERO, issued on December 12, 2025, jobs in the State will increase by 0.5% in 2025 before decreasing by 0.3% in 2026. Hawaii real estate activity through December 2025, as indicated by Oahu’s home resale market, resulted in a 1.5% decrease in the median sales price for condominiums and an increase of 3.5% for single-family homes compared to the same period in 2024. The median single-family home price was $1,100,000 in December 2025, slightly lower than the all-time high of $1,185,000, set earlier this year in February 2025. The number of closed sales through December 2025 saw a 1.1% decrease for condominiums and a 3.5% increase for single-family residential homes compared to the same period in 2024. Hawaii’s petroleum product prices relate to the crude oil in international markets. The price of crude oil has decreased 14.7% over the same quarter in the prior year. At its December 10, 2025 meeting, the Federal Open Market Committee (FOMC) decided to lower the federal funds rate target range to 3.5% to 3.75%. The FOMC noted that economic growth has moderated, with job gains slowing and unemployment edging up. They further noted that uncertainty around the economic outlook remains elevated, and that they remain attentive to risks on both sides of its dual mandate of achieving maximum employment and 2 percent inflation over the longer run. UHERO forecasts full year 2026 real GDP and real personal income to be flat, a decrease in total visitor arrivals of 1.3%, and an unemployment rate of 3.0% for the State. According to UHERO, Hawaii’s economy is edging into a mild recession, with tourism in a downturn, likely to result in job losses in 2026. Inflation is also expected to increase as the impacts of tariffs 35 are reflected in consumer prices. Construction continues to be the only major source of economic strength in Hawaii, supported by large federal contracts and ongoing housing and infrastructure needs. See also “Recent Developments” in the “Electric utility” section below for further discussion of the economic impact of recent events. All Other segment. The “All Other” business segment (loss)/income includes results of the stand-alone corporate operations of HEI, ASB Hawaii, GLST1, and Pacific Current, including the results of Hamakua Energy and the solar and battery energy storage system facilities up until the close of their respective sales in 2025. (in millions) 2025 2024 Change Primary reason(s) Revenue1 $ 16  $ 13  $ 3  Increase in other sales at Pacific Current subsidiaries. Operating loss1 (44) (95) 51  Lower HEI corporate operating loss ($33 million in 2025 vs. $40 million in 2024) primarily due to $12 million lower Maui windstorm and wildfires related costs ($3 million in 2025 vs. $15 million in 2024), partly offset by increases in insurance and incentive compensation expenses. Lower Pacific Current operating loss ($11 million in 2025 vs. $55 million in 2024) primarily due to $35.2 million impairment loss on certain long-lived assets at Pacific Current in the prior year, a $4 million impairment loss on damaged assets in a March 2024 fire at Mahipapa, and Hamakua Energy’s and Mahipapa’s facilities being shut down for repairs in the prior year resulting in higher expense in the prior year. Interest expense & other, net (24) (45) 21  Primarily due to lower average long-term debt balances (due to $384 million paydown in April 2025) in 2025 than in 2024. Interest income 27  13  14  Primarily due to interest income from the September 2024 common stock offering proceeds. Loss on sale of subsidiaries and impairment loss on assets sold and held for sale (12) —  (12) Sale of Pacific Current subsidiaries and impairment loss on Pacific Current assets sold and held for sale in the current year. Income tax benefit 8  31  (23) Lower pretax loss. Net loss $ (45) $ (96) $ 51  1     Hamakua Energy’s sales to Hawaii Electric Light (a regulated affiliate) up until the close of its sale on March 10, 2025 are eliminated in consolidation. Note: Totals may not foot due to rounding. In late February 2024, Hamakua Energy’s combustion turbine (CT) and its leased combustion turbine (leased CT) unexpectedly sustained damages resulting in a plant shut down on Hawaii Island. As a result, in April 2024, Hamakua Energy purchased a new CT which was placed into service in June 2024. The leased CT was returned to the lessor and a new leased CT had been delivered and placed into service in September 2024 bringing Hamakua Energy back to full capacity. After conducting an investigation into the root cause of the damages, it was determined that contaminated fuel led to the turbine damages. Pacific Current is currently working with its legal counsel on seeking recovery of its losses related to damages sustained to its plant facilities. As part of HEI’s comprehensive review of strategic options for certain assets of Pacific Current, on February 7, 2025, Pacific Current entered into a Securities Purchase Agreement to sell all the membership interests in Hamakua Holdings, a then wholly owned subsidiary of Pacific Current and parent company of Hamakua Energy, to an unaffiliated third party. The sale transaction closed on March 10, 2025. As a result of the sale transaction, the Company recorded a pre-tax loss on the sale amounting to $13.2 million as of March 31, 2025. The sale of Hamakua Holdings and its subsidiary, Hamakua Energy, does not preclude Pacific Current from seeking recovery of its losses related to the aforementioned damages to its plant facilities from the fuel supplier. 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 was shut down while repairs were being performed. Mahipapa completed repairs to its facility and commenced operations in early December 2024 and returned to full capacity in the first quarter of 2025. In the first quarter of 2025, Mahipapa received insurance proceeds of $1.4 million under its business interruption policy. In addition to working with its insurance company, Mahipapa is 36 currently working with its legal counsel on seeking reimbursement of its losses related to damages sustained to its plant facilities. In September 2024, Pacific Current recorded a pretax long-lived asset impairment charge of $35.2 million after determining it was more-likely-than-not that the long-lived assets of Pacific Current will be sold significantly before the end of their previously estimated useful life and that the fair value of certain long-lived assets of Pacific Current were less than its carrying value. In addition, HEI forgave its intercompany loan receivable from Mahipapa, including accrued interest, amounting to $9.6 million. Concurrently, Mahipapa classified its intercompany loan payable to HEI, including accrued interest, of an equivalent amount as an equity contribution. These transactions were accounted for as equity transactions and offset in the Company’s Consolidated Balance Sheets. The impairment charge and intercompany loan transactions were 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. As part of HEI’s comprehensive review of strategic options for certain assets of Pacific Current, on August 1, 2025, Pacific Current, through an indirect subsidiary, sold all of the membership interests in Mauo, LLC, Alenuihaha Developments, LLC, Kaʻieʻie Waho Company, LLC and Upena, LLC. See Note 3 of the Consolidated Financial Statements for more information. Liquidity and capital resources.  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 wildfire related litigation noted above). The Company’s objective continues to be to operate a strong, financially healthy enterprise to empower a thriving future for Hawaii. While the fundamentals of its businesses remain strong, the Company took prudent and measured actions to reinforce its commitment to serving the community for the long term. Subsequent to the Maui windstorm and wildfires, in August 2023, HEI and Hawaiian Electric fully drew down $175 million and $200 million, respectively, on their previously existing revolving credit facilities. On September 5, 2025, HEI and Hawaiian Electric each entered into a fourth amended and restated credit agreement with a syndicate of eight financial institutions, increasing each of their committed capacities to $300 million (see Note 6 of the Consolidated Financial Statements for additional information). As of December 31, 2025, HEI and Hawaiian Electric had $20 million and nil, respectively, drawn on their revolving credit facilities and no commercial paper outstanding. The Company has taken additional prudent measures to strengthen its financial position while continuing to provide reliable service to its customers and reinforcing HEI’s commitment to serving the community for the long term, including the Utilities entering into an asset-based credit facility in May 2024 that allows the Utilities to borrow up to $250 million (see Note 6 of the Consolidated Financial Statements), and HEI registering with the SEC in September 2024 an at-the-market offering program under which HEI may offer and sell, from time to time at its sole discretion, its common stock, without par value, having an aggregate offering price of up to $250 million. To date, HEI has not sold any common stock under this program. In addition, HEI paid down a ratable portion of each of HEI’s senior notes in April 2025 amounting to $384 million, using the proceeds from the December 2024 sale of ASB. Additional proactive measures included suspending the quarterly cash dividend on HEI’s common stock after payment of the second quarter dividend in September 2023, repaying its revolving credit facilities and reducing or eliminating discretionary costs. As of December 31, 2025, HEI consolidated had $2.4 billion of long-term debt, of which $125 million is due or expected to be repaid within 12 months. In addition, as of December 31, 2025, the Utilities accrued estimated wildfire liabilities of approximately $1.92 billion (pre-tax), related to the settlement of the Maui windstorm and wildfire tort-related legal claims (see Note 2 of the Consolidated Financial Statements). HEI and Hawaiian Electric determined that making payments under the terms of the Settlement Agreements in four equal annual installments is the most viable option and have classified the first $479 million installment as a current liability based on expected timing of the payment and the remaining $1.44 billion as a noncurrent liability on the Company’s and the Utilities’ Consolidated Balance Sheets. To finance the first installment payment, in September 2024, HEI completed the sale of 62.2 million shares of common stock. The shares were issued under a registration statement registering up to $575 million of common stock. The net proceeds from the sale of common stock amounted to approximately $557.7 million. In November 2024, HEI transferred the first installment payment to GLST1, a wholly owned subsidiary created for the specific purpose of holding the first installment payment pursuant to the settlement of the Maui windstorm and wildfire tort-related legal claims (see Note 2 of the Consolidated Financial Statements). The cash for the first installment payment is classified as restricted cash on the Consolidated Balance Sheet as of December 31, 2025. 37 At December 31, 2025, the Company’s consolidated total available liquidity was approximately $1,572 million. The following table provides the components of available liquidity at December 31, 2025. See “Liquidity and capital resources” in Hawaiian Electric’s MD&A below for components of its available liquidity under existing credit facilities as of December 31, 2025. As of December 31, 2025 (in millions) Capacity Outstanding Undrawn Electric utility Total credit, excluding standing commitment letter with HEI1 $ 540  $ —  $ 540  Total available credit - Electric utility2 $ 540  All Other Unsecured revolving line of credit $ 300  $ 20  $ 280  At-the-market program 250  —  250  Total credit and other liquidity- All Other 550  20  530  Total available credit and other liquidity - All Other $ 530  Consolidated cash and cash equivalents 502  Total available liquidity $ 1,572  1     Pursuant to an HEI and Hawaiian Electric Intercompany Borrowing and Investment Policy which provides Hawaiian Electric a borrowing commitment of $75 million. Hawaiian Electric currently has no borrowings under this policy. See Note 6 of the Consolidated Financial Statements for a description of the HEI and Hawaiian Electric Intercompany Borrowing and Investment Policy. 2    As of December 31, 2025, the Utilities had no commercial paper outstanding. Hawaii Electric Light and Maui Electric had no short-term borrowings from Hawaiian Electric but had long-term intercompany loans from Hawaiian Electric in the amount of $25 million and $90 million, respectively, as of December 31, 2025. Management believes with the Company’s cash and cash equivalents amount of $502 million and GLST1’s restricted cash amount of $479 million, both as of December 31, 2025, the available capacity on Hawaiian Electric’s ABL Facility, HEI’s and Hawaiian Electric’s increased borrowing capacities of their unsecured lines of credit, and additional liquidity under HEI’s registered at-the-market offering program, the Company has adequate cash to meet its financial obligations and sustain operations in the short term, including available sufficient liquidity to fund the first installment of the settlement of wildfire tort claims (expected to be made no sooner than early 2026) and its other cash obligations for the next 12 months following the issuance of its financial statements. The Company expects that liquidity will continue to be impacted in the long term primarily due to the remaining liability payments to settle wildfire claims; the result of the August 2023 downgrades of their credit ratings to below investment grade which limits the Company from accessing unsecured, short-term borrowings and continues to restrict access to the capital markets and other sources of debt and equity financing on favorable terms; and higher working capital requirements resulting from inflation and elevated fuel prices. Although the Company has raised sufficient cash to pay the first installment of the settlement of wildfire tort claims, the Company is currently working with its financial advisors on a financing plan to raise the additional capital necessary to fund the remaining 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. If the financing plans are unsuccessful, the Company may need to consider other strategic alternatives. See further discussion in “Risk Factors” in Item 1A. If further liquidity is deemed necessary in the short term, Hawaiian Electric 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. 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 benefits 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; 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 remaining operating subsidiary. Forecasted HEI consolidated “net cash used in investing activities” consists primarily of the net capital expenditures of the Utilities principally related to maintaining and modernizing the grid to allow for the integration of more renewable energy, 38 improved customer reliability, greater system efficiency and enhanced resilience. The Utilities’ capital expenditures are forecasted to be funded primarily through a combination of retained earnings and proceeds from other sources of debt financings (see also discussion regarding other material cash requirements under “Financial Condition–Liquidity and capital resources,” contained in the “Electric utility” section below). In the future, if the Company is unable to refinance scheduled maturing debt, then debt maturities are expected to be repaid with the proceeds from existing cash on hand, other medium- or long-term debt, and/or dividends from subsidiaries. The ability of Hawaiian Electric to pay dividends or make other distributions to HEI are subject to contractual and regulatory restrictions (see Note 15 of the Consolidated Financial Statements). Additional debt and/or equity financing, if available, may be utilized to invest in the Utilities; to pay down commercial paper or other short-term borrowings, if any; to pay interest costs; or to fund unanticipated expenditures, such as increases in the costs of, or an acceleration of, the construction of capital projects of the Utilities or unanticipated utility capital expenditures. In addition, existing debt may be refinanced prior to maturity with additional debt or equity financing (or both). Certain Maui windstorm and wildfires legal-related costs of HEI and the Utilities are recoverable under $165 million of excess liability insurance, $25 million of professional liability insurance, and $145 million of directors and officers liability insurance policies (see further information in Note 2 of the Consolidated Financial Statements). As of December 31, 2025, HEI and the Utilities have approximately $10 million, nil and $71 million of insurance coverage remaining under the excess liability, professional liability, and directors and officers liability policies, respectively, after deducting applicable retention amounts, amounts that have been recovered under insurance policies (including the One ‘Ohana Initiative contribution), and amounts expected to be recovered for incurred costs, including the securities class action settlement, and recognized as a receivable as of year-end. Selected short-term and long-term contractual obligations and commitments.  Information about payments under the specified contractual obligations and commitments of HEI and its subsidiaries was as follows: December 31, 2025 Payments due by period (in millions) 2026 2027 2028 2029 2030 After five years Total Contractual obligations Long-term debt1 $ 125  $ 100  $ 139  $ 35  $ 189  $ 1,835  $ 2,423  Interest on long-term debt2 111  109  102  99  92  673  1,186  Maui Windstorm and Wildfire Settlement Agreements3 530  479  479  478  —  —  1,966  Operating and finance leases PPAs classified as leases 60  60  55  55  55  793  1,078  Other leases4 16  11  6  7  7  13  60  Hawaiian Electric open purchase order obligations5 226  61  43  6  6  26  368  Hawaiian Electric fuel oil purchase obligations (estimate based on fuel oil price at December 31) 6  —  —  —  —  —  6  Hawaiian Electric purchase power obligations–minimum fixed capacity charges not classified as leases 117  121  120  120  120  946  1,544  Liabilities for uncertain tax positions —  5  —  —  —  —  5  Total (estimated) $ 1,191  $ 946  $ 944  $ 800  $ 469  $ 4,286  $ 8,636  1Amounts do not include $54 million related to Mahipapa debt which are included in liabilities held for sale as of December 31, 2025. See Note 3 of the Consolidated Financial Statements. 2Amounts do not include $4 million of interest on Mahipapa debt which is included in liabilities held for sale as of December 31, 2025. See Note 3 of the Consolidated Financial Statements. 3As of December 31, 2025, HEI and Hawaiian Electric recorded $48 million and $40 million, respectively, of insurance reimbursement receivable related to the securities class action settlement and tort settlement, respectively. See Note 2 of the Consolidated Financial Statements. 4Amounts do not include $6 million related to Mahipapa leases which are included in liabilities held for sale as of December 31, 2025. See Note 3 of the Consolidated Financial Statements. 5Includes contractual obligations and commitments for capital expenditures and expense amounts. The table above does not include other categories of obligations and commitments, such as deferred taxes, certain trade payables, amounts that will become payable in future periods under collective bargaining and other employment agreements and employee benefit plans and potential refunds of amounts collected from ratepayers (e.g., under the earnings sharing mechanism). As of December 31, 2025, the fair value of the assets held in trusts to satisfy the obligations of the Company’s retirement benefit plans exceeded the retirement benefit plans’ benefit obligation. Minimum funding requirements for retirement benefit plans have not been included in the table above. See Note 11 of the Consolidated Financial Statements for 2026 estimated retirement benefit plan obligations and contributions. 39 See “Developments in renewable energy efforts—Biofuel sources” in Hawaiian Electric’s MD&A for additional information on fuel oil purchase obligations. See Notes 4 and 9 of the Consolidated Financial Statements for a discussion of power purchase commitments and operating leases obligations, respectively. Operating activities provided net cash of $391 million in 2025, $487 million in 2024 and $551 million in 2023, of which operating activities from continuing operations provided net cash of $391 million in 2025, $428 million in 2024 and $443 million in 2023. Investing activities used net cash of $322 million in 2025 and $257 million in 2023 and provided net cash of $258 million in 2024, of which investing activities from continuing operations used net cash of $322 million in 2025, $334 million in 2024 and $436 million in 2023. In 2025, 2024 and 2023, net cash used in investing activities from continuing activities was primarily due to capital expenditures. Financing activities used net cash of $331 million in 2025 and provided net cash of $155 million in 2024 and $196 million in 2023, of which financing activities from continuing operations used net cash of $331 million in 2025 and provided net cash of $498 million in 2024 and $203 million in 2023. In 2025, net cash used in financing activities included repayment of long-term debt, revolving credit facilities and short-term debt and redemption of preferred stock, partly offset by issuance of long-term debt. In 2024, net cash provided by financing activities from continuing operations included issuance of common stock (common stock offering) and increase in short-term debt, partly offset by repayment of long-term debt and revolving credit facilities. In 2023, net cash provided by financing activities from continuing operations included proceeds from revolving credit facilities, long-term debt and short-term debt, partly offset by repayment of long-term and short-term debt, net decreases in short-term borrowings and payment of common and preferred stock dividends. Other than capital contributions from their parent company, intercompany services (and related intercompany payables and receivables), Hawaiian Electric’s periodic short-term borrowings from HEI (and related interest), if any, and the payment of dividends to HEI, the electric utility is largely autonomous in its operating, investing and financing activities. (See the electric utility segment’s discussion of its cash flows in its “Liquidity and capital resources” section below.) During 2025, Hawaiian Electric paid cash dividends to HEI of $30 million. 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 2023 dividend and has not declared a cash dividend since that time. This action was 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. In May 2025, after a temporary suspension of Hawaiian Electric’s quarterly cash dividend to HEI that began with the second quarter 2024 dividend, the Hawaiian Electric Board of Directors approved a $10 million quarterly dividend for each of the first, second and third quarters of 2025. This decision was made after considering several factors, including the continued progress of the Maui windstorm and wildfire settlement, the Utilities’ results of operations and the Utilities’ liquidity position. A portion of the net assets of Hawaiian Electric is not available for transfer to HEI in the form of dividends, loans or advances without regulatory approval. In the absence of an unexpected material adverse change in the financial condition of the Utilities, such restrictions are not expected to significantly affect the operations of HEI or its ability to meet its debt or other cash obligations. See Note 15 of the Consolidated Financial Statements. The consolidated capital structure of HEI was as follows: December 31 2025 2024 (dollars in millions) Short-term borrowings, net $ —  — % $ 49  1 % Long-term debt, net, including current portion of long-term debt, net 2,410  60  2,800  64  Preferred stock of subsidiaries —  —  34  1  Common stock equity 1,606  40  1,479  34  $ 4,016  100 % $ 4,362  100 % Prior to the Maui windstorm and wildfires, HEI utilized short-term debt, typically commercial paper, to support normal operations, to refinance commercial paper, to retire long-term debt, to pay dividends and for other temporary requirements, including short-term financing needs of its subsidiaries. HEI also periodically makes short-term loans to Hawaiian Electric to meet Hawaiian Electric’s cash requirements, including the funding of loans by Hawaiian Electric to Hawaii Electric Light and Maui Electric, but no such short-term loans to Hawaiian Electric were outstanding as of December 31, 2025. Historically, HEI also periodically utilized unsecured long-term debt, to fund investments in and loans to its subsidiaries to support their capital improvement or other requirements, to repay long-term and short-term indebtedness and for other corporate purposes. The downgrades of HEI’s and Hawaiian Electric’s credit ratings have negatively impacted each of HEI’s and Hawaiian Electric’s ability to access lower cost sources of capital. See Notes 6 and 7 of the Consolidated Financial Statements for a brief description of the Company’s loans. 40 Credit ratings. On May 28, 2025, June 4, 2025 and June 27, 2025, Moody’s, Fitch and S&P, respectively, upgraded HEI’s credit ratings. As of February 17, 2026, the Fitch, Moody’s and S&P ratings of HEI were as follows: Fitch Moody’s S&P From1 To From1 To From1 To Long-term issuer default, long-term and issuer credit, respectively B B+ B1 Ba3 B- B+ Short-term issuer default, commercial paper and commercial paper, respectively B B NP NP B B Outlook Stable Positive Stable Positive Negative Watch Positive 1     As of December 31, 2024. In March 2025, S&P revised HEI’s outlook to “Positive” from “Negative” and affirmed the “B-” issuer credit rating. Note: The above ratings reflect only the view, at the time the ratings are issued or affirmed, of the applicable rating agency, from whom an explanation of the significance of such ratings may be obtained. Such ratings are not recommendations to buy, sell or hold any securities; such ratings may be subject to revision or withdrawal at any time by the rating agencies; and each rating should be evaluated independently of any other rating. The Company’s credit rating downgrades related to the Maui windstorm and wildfires will continue to adversely impact its ability to access lower cost sources of capital. Through the sale of common stock in September 2024, the Company has raised sufficient cash to pay the first installment of the settlement of wildfire tort claims expected to be made no sooner than early 2026. The Company is currently working with its financial advisors on a financing plan to raise the additional capital required to fund its remaining 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. The potential damages and losses related to the Maui windstorm and wildfires and related lawsuits (see further information in Note 2 of the Consolidated Financial Statements), the suspension of dividends from Hawaiian Electric, 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. See Item 1A. Risk Factors for further discussion of risks and uncertainties. See “Credit ratings” in Hawaiian Electric’s MD&A for Hawaiian Electric’s credit ratings. The downgrades of HEI’s and Hawaiian Electric’s credit ratings impacted the Company’s ability to access lower cost sources of capital. On September 25, 2024, HEI completed the sale of 62.2 million shares of common stock. The shares were issued under a registration statement registering up to $575 million of common stock. The net proceeds from the sale of common stock amounted to approximately $557.7 million and will be used to fund the Company’s contribution to the expected Maui wildfire tort litigation settlement and for general corporate purposes. On September 19, 2024, HEI filed a shelf registration statement with the SEC for an at-the-market offering program under which HEI may offer and sell, from time to time at its sole discretion, its common stock, without par value, having an aggregate offering price of up to $250 million. To date, HEI has not sold any common stock under this program. There were no new issuances of common stock through the HEIRSP 401(k) Plan in 2025, 2024 or 2023 and HEI satisfied the share purchase requirements of the HEIRSP 401(k) Plan through open market purchases of its common stock. There were no new issuances of common stock through the Dividend Reinvestment Program (DRIP) from January 1, 2023 through September 4, 2023, December 6 through December 31, 2023, in 2025 or in 2024 and HEI satisfied the share purchase requirements of the DRIP through open market purchases of its common stock. From September 5 through December 5, 2023, HEI satisfied the share purchase requirements of the DRIP through new issuances of approximately 0.5 million shares of common stock, amounting to $6.6 million, primarily for participants receiving the September 2023 dividend payment. Off-balance sheet arrangements.  Although the Company and the Utilities have certain off-balance sheet arrangements, management has determined that it has no off-balance sheet arrangements that either have, or are reasonably likely to have, a current or future effect on the Company’s and the Utilities’ financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources that are material to investors, including the following types of off-balance sheet arrangements: 1.obligations under guarantee contracts, 2.retained or contingent interests in assets transferred to an unconsolidated entity or similar arrangements that serve as credit, liquidity or market risk support to that entity for such assets, 3.obligations under derivative instruments, and 41 4.obligations under a material variable interest held by the Company or the Utilities in an unconsolidated entity that provides financing, liquidity, market risk or credit risk support to the Company or the Utilities, or engages in leasing, hedging or research and development services with the Company or the Utilities. 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. Material estimates that are particularly susceptible to significant change include the amounts reported for pension and other postretirement benefit obligations; contingencies and litigation; income taxes; regulatory assets and liabilities; and asset retirement obligations (AROs). Management considers an accounting estimate to be material if it requires assumptions to be made that were uncertain at the time the estimate was made and changes in the assumptions selected could have a material impact on the estimate and on the Company’s results of operations or financial condition. 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 the policies discussed below 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. The policies affecting both of the Company’s two principal segments are discussed below and the policies affecting just one segment are discussed in the respective segment’s section of “Material estimates and critical accounting policies.” Management has reviewed the material estimates and critical accounting policies with the HEI Audit & Risk Committee and, as applicable, the Hawaiian Electric Audit & Risk Committee. For additional discussion of the Company’s accounting policies, see Note 1 of the Consolidated Financial Statements and for additional discussion of material estimates and critical accounting policies, see the electric utility discussion below under the same heading. Pension and other postretirement benefits obligations. The Company’s benefit obligations and reported costs of providing retirement benefits are dependent upon numerous factors resulting from actual plan experience and assumptions about future experience. For example, retirement benefits costs are impacted by actual employee demographics (including age and compensation levels), the level of contributions to the plans, earnings and realized and unrealized gains and losses on plan assets, and changes made to the provisions of the plans. Costs may also be significantly affected by changes in key actuarial assumptions, including the expected return on plan assets, the discount rate and mortality. The Company’s accounting for retirement benefits under the plans in which the employees of the Utilities participate is also adjusted to account for the impact of decisions by the PUC. Changes in obligations associated with the factors noted above may not be immediately recognized as costs on the income statement, but generally are recognized in future years over the remaining average service period of plan participants. The discount rate used to calculate the Company’s benefit obligations is a significant assumption that affects the Company’s benefit obligations. As of December 31, 2025, the discount rates for HEI and the Utilities’ pension and other benefits plans were 5.78% and 5.67%, respectively. Based on various assumptions in Note 11 of the Consolidated Financial Statements, sensitivities of the projected benefit obligation (PBO) and accumulated postretirement benefit obligation (APBO) as of December 31, 2025, associated with a change in the discount rate, were as follows and constitute “forward-looking statements”: Actuarial assumption Change in assumption in basis points Impact on HEI Consolidated PBO or APBO Impact on Consolidated Hawaiian Electric PBO or APBO (dollars in millions) Pension benefits Discount rate +/-50 $(119)/$133 $(116)/$130 Other benefits Discount rate +/-50 $(6)/$7 $(6)/$7 Also, see Notes 1 and 11 of the Consolidated Financial Statements. Contingencies and litigation.  The Company is subject to proceedings (including PUC proceedings), lawsuits and other claims. Management assesses the likelihood of any adverse judgments in or outcomes of these matters as well as potential ranges of probable losses. A determination of the amount of reserves required, if any, for these contingencies is based on an analysis of each individual case or proceeding, often with the assistance of outside counsel. The required reserves may change 42 in the future due to new developments in each matter or changes in approach in dealing with these matters, such as a change in settlement strategy. In general, environmental contamination treatment costs are charged to expense, unless it is probable that the PUC would allow such costs to be recovered through future rates, in which case such costs would be capitalized as regulatory assets. Also, environmental costs are capitalized if the costs extend the life, increase the capacity, or improve the safety or efficiency of property; the costs mitigate or prevent future environmental contamination; or the costs are incurred in preparing the property for sale. As a result of the Maui windstorm and wildfires, HEI and Hawaiian Electric evaluated various financing plans to pay the amounts included in the tort-related Settlement Agreements and determined that paying in four equal annual installments is the most viable option and aligns with the Companies’ expectations of how the settlement amount will be paid. As of December 31, 2025, the Utilities have recorded a settlement accrual of $1.92 billion which reflects their best estimate of the loss contingency. In addition, as a result of executing final settlement agreements in its securities class action and shareholder derivative lawsuits, as of December 31, 2025, HEI recorded a settlement accrual of $47.8 million, and concurrently, recorded an insurance reimbursement receivable of an equivalent amount as the recovery of the agreed settlement payment under its directors and officers liability insurance policy is deemed probable. Refer to “Recent Developments” and Note 2 of the Consolidated Financial Statements for more information. See Notes 1, 2 and 4 of the Consolidated Financial Statements. Income taxes.  Deferred income tax assets and liabilities are established for the temporary differences between the financial reporting bases and the tax bases of the Company’s assets and liabilities using tax rates expected to be in effect when such deferred tax assets or liabilities are realized or settled. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. In 2024, the Company generated a $287.1 million capital loss from the sale of ASB. For federal tax purposes, any excess capital loss is first carried back three years and then carried forward for up to five years to offset future capital gains. For Hawaii state tax purposes, unused capital losses can only be carried forward for up to five years, with no carryback option available. Since capital losses can only be offset against capital gains, the Company believes it is more likely than not that the tax benefit of the capital loss on the sale of ASB will not be realized, because there is no expectation of generating capital gains and no tax strategies in place to produce capital gains before the loss expires. As of December 31, 2025, the Company’s federal and Hawaii capital loss carryforward is $273.1 million and $289.4 million, respectively, with a valuation allowance totaling $66.1 million for federal and state, related to the capital loss. In 2024, the Company agreed to settle the Maui windstorm and wildfires tort-related legal claims on a global basis. This nonrecurring settlement will create a net operating loss (NOL) of approximately $1.878 billion, resulting in a total deferred tax asset (DTA) of $483.7 million. The Company analyzed the positive and negative evidence of each source of taxable income that will allow the DTA to be realized as enumerated in ASC 740. Other than the capital loss carryforward discussed above, the Company expects to fully utilize current DTAs that will be generated over the next 17-year period for HEI consolidated and 13-year period for Hawaiian Electric consolidated, based on estimated income projections (exclusive of future reversals of taxable temporary differences). The Company believes that the DTA generated from the nonrecurring settlement, along with historical DTAs, will be fully utilized, with the exception of the capital loss carryforward. The Company has generated consistent earnings over the past three years exclusive of the nonrecurring settlement. The Company believes that it is more likely than not that the Company will realize the benefits of its gross DTAs, other than the capital loss carryforward, including the $483.7 million DTA recognized as a result of the settlement. If estimated future income projections turn out to be lower, it should be noted that the DTA related to the NOL carryforward does not expire. Management evaluates its potential exposures from tax positions taken that have or could be challenged by taxing authorities. These potential exposures result because taxing authorities may take positions that differ from those taken by management in the interpretation and application of statutes, regulations and rules. Management considers the possibility of alternative outcomes based upon past experience, previous actions by taxing authorities (e.g., actions taken in other jurisdictions) and advice from its tax advisors. Management believes that the Company’s provision for tax contingencies is reasonable. However, the ultimate resolution of tax treatments disputed by governmental authorities may adversely affect the Company’s current and deferred income tax amounts. See Note 13 of the Consolidated Financial Statements. Following is a discussion of the electric utility segment. Additional segment information is shown in Note 3 of the Consolidated Financial Statements. The discussion concerning Hawaiian Electric should be read in conjunction with its consolidated financial statements and accompanying notes. 43 Electric utility Executive overview and strategy.  The Utilities provide electricity on all the principal islands in the State of Hawaii, other than Kauai, to approximately 95% of the State’s population, and operate five separate grids. The Utilities’ mission is to empower their communities and customers with safe, reliable, resilient, affordable, and clean energy. The goal is to create a safe, modern, resilient, flexible, and dynamic electric grid that protects Hawaii from impacts of evolving climate dynamics, position the Utilities to achieve the expectations of their customers and communities and earn their trust, and achieve Hawaii’s decarbonization goals that are aligned with the statutory goal of 100% renewable portfolio standard and net-negative carbon emissions by 2045. Recent developments. See also “Recent developments” in HEI’s MD&A and Note 2 of the Consolidated Financial Statements, which includes disclosures relating to Maui windstorm and wildfires. For the full year 2025, the Utilities generated net income of approximately $168.2 million compared to net loss of $1.2 billion in 2024. See “Results of operations” below for variance explanations. For the full year 2025, kWh sales volume increased 2.5% from 2024 levels. The increase reflects warmer weather as well as the continuing economic recovery since the Maui windstorm and wildfires and increased pumping loads as Maui energy consumption increased 6.6% from 2024 to 2025. The price of crude oil has decreased about 14.1% compared to the prior year. 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 penalty/reward exposure annually). In December 2025, the Consumer Price Index (CPI) increased 2.7% over the last 12 months. In Hawaii, the January 2026 Urban Hawaii (Honolulu) CPI increased 2.4% over the last 12 months. Under the PBR Framework, inflation risk for the Utilities is partially mitigated by an Annual Revenue Adjustment (ARA), which is based on a formula that includes a compounded and non-compounded portion. •The compounded portion of the ARA 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. 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 2025 calendar year, the forecasted 2025 GDPPI was 1.98% (net of the 0.22% customer dividend), measured in October 2024, and became effective in rates on January 1, 2025. For the 2026 calendar year, the forecasted 2026 GDPPI was 2.58% (net of the 0.22% customer dividend), measured in October 2025, and became effective in rates on January 1, 2026. •The non-compounded portion of the ARA 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 2025 by $27 million, or 14% with arrears balance 1-30 days decreasing by 18% since December 31, 2024. The decrease in accounts receivable was primarily driven by receipt of government arrears. In addition, arrears balances have declined to pre-pandemic levels as the Utilities returned to pre-pandemic collection policies, except on Maui, where the moratorium on disconnections remain in place. Further at year-end, the Utilities pledged $1 million to assist customers with larger arrears balances who may be facing financial hardship, particularly on Maui, and decreased accounts receivable accordingly. See “Financial Condition—Liquidity and capital resources” below for additional information. Regulatory and legislative developments. Legislation. On June 6, 2025, Governor Josh Green signed Senate Bill 1501, now known as Act 191, which allows the State to “step-in” for the Utilities in the case of utility financial distress, ensuring project owners receive payment, addressing concerns of some independent power producers’ ability to procure low-cost financing for new renewable energy and storage projects due to the Utilities’ credit ratings. On July 1, 2025, the Governor signed into law Senate Bill 897, now known as Act 258, which directs the PUC to study the viability of a wildfire relief fund, establish an aggregate liability cap on economic damages from future wildfires and authorizes securitization to finance wildfire safety and resilience infrastructure improvements. On July 8, 2025, the Governor signed House Bill 1001, now known as Act 301, which appropriates funds to address the State of Hawaii’s settlement of claims related to the Maui wildfire and windstorm tort litigation settlement. Act 258 is expected to help support the Utilities’ financial stability to move forward, while Act 301 provides a resolution to those affected by the Maui windstorm and wildfires and provides assurance for a global settlement to move forward. Act 191 supports the Utilities’ ability to procure energy in order to provide customers and communities with safe, reliable and affordable clean energy. 44 On July 2, 2025, the Governor signed Senate Bill 589, now known as Act 266. Among other things, Act 266 authorizes wheeling of renewable energy and requires the PUC to establish policies and procedures to implement wheeling of renewable electricity for a capacity of not more than two megawatts, as well as microgrid service tariffs, by January 1, 2027. Act 266 also requires the PUC to establish an installation goal for new customer-sited distributed energy resources and establish tariffs to achieve the installation goal and for grid service programs, microgrids, and community-based renewable energy. The Utilities are currently assessing the potential impact related to wheeling as the PUC works to establish the provisions and terms for the implementation of wheeling in compliance with Act 266. For more information on wheeling, see discussion in “Investigation on the establishment of wheeling” below. The One Big Beautiful Act signed into law by President Trump on July 4, 2025 may impact the ability of the Utilities’ recently selected and new wind and solar projects to qualify for federal tax credits. Regulations continue to be developed, so the complete scope of potential impacts remains unknown at this time. Any loss in renewable energy tax credits could lead to project risk for new wind and solar projects in development and will likely result in higher prices for such projects, developers of which rely extensively on federal tax credits to finance such projects. It is also possible that the sunsetting of these tax credits will impact the supply chain for projects throughout the U.S. as developers rush to meet the four-year safe harbor timeline. The legislature is expected to consider legislation to provide a state tax credit to fill the void left by the expiration of the federal solar tax credit. However, due to budget shortfalls, the likelihood of its passage is limited. Trade policies. Impacts to the Utilities from trade policies imposed by the U.S. or its trading partners are uncertain at this time. The Utilities estimated that in 2024, more than 90% of the Utilities’ capital goods were domestically sourced. However, the Utilities and their independent power producers procure capital goods that flow through global supply chains and may include raw materials, sub-components, or components sourced or assembled outside the U.S. Utility capital costs and the cost of power procured from independent power producers may increase due to new trade policies and changes in trade policy from the U.S. and its trading partners, based on the amount of foreign content of capital goods. It is also possible that trade policies could impact commodities and raw materials costs, leading to inflation of utility capital costs indirectly through the broader supply chain. Utility-scale battery projects planned by both Hawaiian Electric and independent power producers may see significant cost increases or supply chain challenges, as the majority of battery components are currently manufactured in, or have significant supply chain exposure to, the People’s Republic of China. The Utilities are still assessing the potential impact of the trade policies. Re-basing. In its order issued on February 27, 2025, the PUC concluded that Utilities’ target revenues should be re-based for the next MRP (MRP2) and allowed the Utilities to file a single, consolidated application that presents their requested adjustment to target revenues. The proceeding to re-base the Utilities’ target revenues for MRP2 shall be bifurcated into two tracks, with the first track focused on reaching a decision on the Utilities’ revenue requirements prior to the commencement of MRP2 and the second track focused on making a final determination on the revenue requirement and addressing the rate design component. On August 28, 2025, the Utilities filed a request to extend the time to file a rate case in order to allow collaboration among the PBR working group parties on an alternative rate re-basing proposal that could eliminate the need for a general rate case application and process. Confirmation was also sought that if a non-rate case re-basing proposal is explored but does not result in a proposal supported by the Utilities, they could file a rate case in the second half of 2026 utilizing a 2027 test year. Effectively, this alternative process would pick up on previous PBR working group re-basing discussions. This would also mean, however, that the Utilities would not file their rate case application in December 2025. This alternative approach could also address concern that re-basing and consideration of other PBR Framework modifications be done in a more synchronized manner. Upon review and consideration of the record and circumstances, the PUC granted Hawaiian Electric’s Letter Request on September 29, 2025, subject to certain conditions. During the fourth quarter of 2025, the Utilities continued to meet with the PBR working group to develop an alternative rate re-basing proposal. On December 8, 2025, the Utilities, together with support from certain PBR parties, filed a request to extend the time to submit the alternative rate re-basing proposal by 30 days to February 6, 2026, with a corresponding extension to February 13, 2026, for statements from any party who opposes or does not agree with any submitted alternative proposal describing their opposition and the reasons. On December 16, 2025, the PUC granted the Utilities’ request to extend the deadline for the submission of an alternative re-basing proposal from January 7, 2026 to February 6, 2026 and affirmed (i) that any proposal submitted by this deadline must comport with the PUC’s prior guidance, (ii) if the parties are unsuccessful at developing an alternative proposal for the PUC’s review or if the PUC ultimately rejects any submitted alternative proposal, the Utilities shall resume work on their re-basing application utilizing a 2027 test year and file the re-basing application in the second half of 2026. The PUC correspondingly modified the deadline for parties to submit a statement of opposition to any alternative proposal from January 14, 2026 to February 13, 2026. See “Regulatory proceedings” in Note 4 of the Consolidated Financial Statements for additional discussions. 45 On January 28, 2026, the Utilities requested a final extension to file the alternative PBR re-basing proposal on May 7, 2026 to allow for additional time for the working group parties to develop PIMs and other PBR framework modifications. On February 12, 2026, the Utilities filed a written update with the PUC, which explained that the additional time requested will allow the parties to explore re-basing and consideration of other PBR Framework modifications in a more synchronized manner, streamline Phase 6 (the examination of proposal for modifications to the PBR Framework) and potentially save time and resources for both the PUC and parties. On February 24, 2026, the PUC granted in part the Utilities’ extension request, extending the deadline to submit an alternative re-basing proposal to March 6, 2026, to allow the PUC to promptly proceed with its review of the re-basing proposal. The PUC also extended the deadline for parties to submit any opposition to the alternative re-basing proposal to March 13, 2026. The PUC confirmed that it will resume Phase 6 following resolution of the alternative re-basing proposal. Affiliate transactions. In June 2025, the Utilities submitted a request with the PUC to terminate or suspend the Affiliate Transaction Requirements (ATRs). Beginning in 2024 and continuing into 2026, HEI has embarked on a strategy to divest all of its affiliated companies other than the Utilities, intending for the Utilities to be HEI’s sole operating companies. Termination of the ATRs would allow implementation of a corporate integration, under which all HEI employees would move to Hawaiian Electric. A few officer positions would manage and operate both HEI and Hawaiian Electric (dual-hatted executives) and the HEI and Hawaiian Electric boards of directors would be composed of a single set of individuals. In September 2025, the PUC dismissed the request without prejudice. In its order, the PUC provided guidance on the topics to be addressed in any future request. On October 31, 2025 HEI and Hawaiian Electric filed a revised request with the PUC to terminate or suspend the ATRs. After responding to information requests from the Consumer Advocate, the Consumer Advocate issued its statement of position on February 4, 2026. The Consumer Advocate supported the approval of the request with the condition that before any recovery of expenses related to HEI, the Utilities should give the Consumer Advocate and the PUC advance notice of likely changes to recovery. HEI and Hawaiian Electric informed the PUC that the docket was ready for decision making on February 5, 2026. System reliability. Since the August 2023 Maui windstorm and wildfires, the Utilities have developed a set of Interim Wildfire Safety Measures 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 performed in 2024. On January 10, 2025, the Utilities filed their 2025-2027 Wildfire Safety Strategy (WSS) with the PUC, which outlines their plans to reduce wildfire risk throughout their service territories over the next three years, and was approved by the PUC on December 31, 2025. In the near term, it is anticipated that these measures will result in disruptions to service and negatively impact Transmission and Distribution (T&D) System Average Interruption Duration Index (SAIDI) and System Average Interruption Frequency Index (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 “Wildfire Safety Measures.” Hawaii Island has two generators out of service for extended maintenance, one of which is expected to return to service in the second quarter of 2026. While these units are unavailable for maintenance, during certain periods there may be reductions in generation reserve margins and failure of other generators, which could risk generation shortfalls. For a discussion regarding the impact of the Maui windstorm and wildfires on the Utilities’ liquidity and capital resources, see discussion below under “Financial Condition–Liquidity and capital resources.” 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 developed a set of Interim Wildfire Safety Measures designed 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 had either already started, or were to start in 2024. These actions included wildfire risk analysis, operation procedures, including the implementation of the Public Safety Power Shutoff (PSPS) program, and grid design changes, enhanced inspection and vegetation management plans, and system hardening. In January 2025, the Utilities developed and filed with the PUC a 2025-2027 WSS, which identifies risk mitigation strategies to perform over the next three years across their service territories. The programs developed under the interim measures have been integrated into the 2025-2026 WSS. The strategies and actions include additional operational changes, grid hardening work, enhanced inspections and vegetation management, and risk modeling to inform and prioritize hardening work and operational actions. On May 30, 2025, the Utilities submitted an application to the PUC for Exceptional Project Recovery Mechanism (EPRM) cost recovery estimated at $350 million, net of costs funded through other existing programs. On December 31, 2025, the PUC approved the Utilities’ 2025-2027 WSS (also known as Wildfire Mitigation Plan). The PUC also directed the Utilities to provide a 2026-2027 Wildfire Mitigation Plan Update, and guidance for the next Wildfire Mitigation Plan covering the 2028-2029 time period. The PSPS program, initially developed under the Interim Wildfires Safety Measures Program, is now part of the Utilities’ operations. The PSPS program calls for the Utilities to preventatively de-energize circuits in areas identified as high fire risk 46 during certain weather conditions. The PSPS program launched on July 1, 2024 and is ready to use, if and when it is needed, to protect customers, communities and employees. Since the July 2024 implementation, the Utilities have continued to mature the PSPS program as it has gained experience executing the program along with public safety partners, communities, and residents. For example, the Utilities now have an in-house meteorologist and additional strategically placed weather stations to enhance its forecasting capability and situational awareness of localized hazardous conditions. The PSPS protocols 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 risk to the public arising from 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 evolving climate dynamics 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. Climate action plan. 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 have slowed the pace of progress toward reducing greenhouse gas emissions. Also, see the “Developments in renewable energy efforts—New renewable PPAs” section below. The One Big Beautiful Act signed into law by President Trump on July 4, 2025 may impact the ability of recently selected and new wind and solar projects to qualify for federal tax credits. Any loss in renewable energy tax credits could lead to project risk for new wind and solar projects in development and will likely result in higher prices for new renewable projects, which rely on such incentives to provide clean, affordable energy. Further, new tariffs imposed on equipment and materials used in the construction of renewable facilities will have an impact on pricing of new renewable projects. As a result of these challenges and the downgrade of Hawaiian Electric’s credit ratings after the Maui windstorm and wildfires, 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 2030 RPS goals. As of December 31, 2025, the Utilities estimate a reduction of carbon emissions of approximately 25%. This represented an increase in emissions compared to the 27% reduction in 2024 due to higher customer electric usage. As renewable energy replaces fossil fuel generation, carbon emissions are expected to continue to decline over time. 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 impacted by federal policies, key elements of the 2030 plan have already been completed or remain on track to be completed by 2030, including the closure of AES Hawaii, Inc., the State’s last coal-fired IPP plant, 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. State of Hawaii laws and policies. In January 2025, the State of Hawaii issued two key policy documents and an alternative fuel study. The PUC issued its 2024 Inclinations on the Future of Energy in Hawaii (2024 PUC Inclinations). The 2024 PUC Inclinations are intended to provide a guide for the completion of energy infrastructure upgrades for public safety, reliability and resiliency. This includes among other items, strategic hardening, diversification and enhancements of transmission and distribution systems, expedited replacement of older fossil fired generation, streamlined interconnection for renewable utility scale and distributed energy resources, including a specific goal to limit fossil fuel generation to no more than 40% on each island by 2030, software and hardware improvement to prevent cybersecurity threats, creation of resilience hubs, and integration of electric, gas, and renewable resources to support continuity of energy, telecommunications, water and wastewater services. The 2024 PUC Inclinations specifically state that “Strategic ownership of new generation (by the Utilities) may be beneficial, especially when such ownership stabilizes utility finances, benefits from low-interest federal loans or advances other objectives such as operational accountability, resilience and public safety.” Governor Josh Green issued Executive Order No. 25-01, Accelerating Hawaii’s Transition Toward 100 Percent Renewable Energy (EO 25-01). EO 25-01 sets forth collective actions to accelerate the State’s decarbonization, stabilize and reduce energy costs, lower the State’s carbon footprint, strengthen energy security, and gain access to capital for the energy transition. Among other actions, EO 25-01 calls for 100% renewable electricity production in the counties of Hawaii and Maui by 2035 and 47 achieving a 70% reduction of Oahu’s greenhouse gas emissions reductions from the electricity sector by 2035, using 2005 as a baseline, calls for the maximization of distributed solar energy paired with energy storage, including the installation of 50,000 new distributed energy resources by 2030, accelerating permitting tied to renewable energy, approving interconnection, and addressing energy burdens on low- and moderate-income residents. The Hawaii State Energy Office’s Alternative Fuel, Repowering and Energy Transition Study (Alternative Fuel Study) expresses concern about the speed of the transition to renewable energy and cites to the continued reliance on imported oil as a driver of high bills and intense carbon emissions. The report makes a case for the use of liquefied natural gas on Oahu to replace low sulfur fuel oil during the transition to 100% renewable energy, and names several entities as potential investors that could help speed the transition. On October 6, 2025, the Office of the Governor of the State of Hawaii and JERA Co., Inc., Japan’s largest power producer, signed a non-binding Strategic Partnering Agreement that establishes a framework for long-term collaboration to support Hawaii’s decarbonization goals and energy transition. The Strategic Partnering Agreement supports the implementation of the Hawaii State Energy Office’s Alternative Fuel Study to pursue fuel diversification, including liquified natural gas, to reduce near-term reliance on oil. The Utilities are engaged in planning activities designed to support the State’s energy policy objectives, including the transition to a more affordable, reliable, and sustainable energy system. These planning efforts evaluate a range of resource, fuel, and technology options and are informed by state energy policy guidance and stakeholder input. Importantly, all three documents recognize that to achieve the State’s ambitious goals is a collective effort that will require government agencies, electric utilities, and private stakeholders to work together, acknowledging that each of these groups has an important role to play. The 2024 PUC Inclinations for example state: “Energy utilities, government agencies and private stakeholders must embrace an ethos of collective responsibility to confront and effectively mitigate the vulnerabilities revealed by Lahaina’s heartbreaking tragedy, the COVID pandemic, ongoing global unrest, cybersecurity threats and the overarching climate crisis.” The PUC later states: “The Commission does not expect energy utilities to accelerate their transformation without regulatory assistance and third-party resources.” All three documents also recognize the progress made to date towards the State’s renewable energy goals. The Utilities remain committed to working with all stakeholders to support the State’s energy policy objectives and reach Hawaii’s ambitious renewable energy goals. 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 2025, 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 2025, the Utilities achieved a 36.8% RPS accruing a reward of $1.9 million based on $10/MWh in exceedance of 35.0% RPS. In 2026, the Utilities are eligible for a reward of $10/MWh in exceedance of 36.0% 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 their 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’ 48 continued transformation, and are updated regularly to adapt to changing technology, costs, and other factors. While there is no financial penalty for failure to achieve the Utilities’ long-range aspirational objectives, the Utilities recognize that there are environmental and social costs from the continued use of fossil fuels. The State of Hawaii’s policy is supported by the regulatory framework and includes a number of mechanisms designed to maintain the Utilities’ financial stability during the transition toward the State’s decarbonized future. Under the sales decoupling mechanism, the Utilities are allowed to recover from customers, target test year revenues, independent of the level of kWh sales, which have generally trended lower over time as privately-owned distributed energy resources 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, such as the annual revenue adjustment to provide annual changes in utility revenues, including inflationary adjustments, and the EPRM, which allows the Utilities to recover and earn on certain approved eligible projects placed into service. See “Regulatory proceedings” in Note 4 of the 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 first cycle of the IGP was accepted by the PUC on March 7, 2024, and 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. 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. On January 2, 2026, the PUC opened the Second Cycle of the Integrated Grid Plan to continue to plan for future resources needed on the Utilities’ systems. Demand response programs. Pursuant to PUC orders, the Utilities are developing an integrated Demand Response Portfolio Plan that will enhance system operations and reduce costs to customers. The reduction in cost for the customer will take the form of either rates or incentive-based programs that will compensate customers for their participation individually, or by way of engagements with turnkey service providers that contract with the Utilities to aggregate and deliver various grid services on behalf of participating customers and their distributed assets. In 2021, the PUC approved the 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, which provides approximately 43 MW on Oahu. Subsequently in 2022, the Utilities were approved to expand the EDRP program on the island of Maui and Oahu, which provides approximately 8 MW and 43 MW on Maui and Oahu, respectively. The PUC approved the cost recovery of the additional incentives for both Oahu and Maui through the Demand Side Management Surcharge. During the time that EDRP was available, Bring Your Own Device Level 1 was launched on April 1, 2025, to succeed EDRP, which closed on July 1, 2024, on Oahu. The Bring Your Own Device Level 1 later evolved into Bring Your Own Device Plus, which began on May 15, 2025. Enrollment for the Bring Your Own Device Plus program will be available until total enrolled program capacity reaches 50 MW statewide. 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 resiliency, reliability, distributed energy resources and renewable energy integration. Deployment was planned in two phases. The Utilities completed Phase 1 deployment of 447,000 advanced meters, servicing approximately 95% of the customers in 2024 and are recovering associated costs under the MPIR mechanism. Since GMS Phase 1 Project completion, the Utilities continue to deploy advanced meters as part of normal meter shop operations under the recovery of Annual Revenue Adjustment mechanism. The Utilities filed their initial application with the PUC on September 30, 2019 for an Advanced Distribution Management System as part of Phase 2 of their GMS implementation. However, as the Utilities were unsuccessful in securing IIJA federal funding in 2024, the Utilities are currently re-scoping GMS Phase 2 and plan to file another updated and supplemented PUC application for updated project costs in the second quarter of 2026. 49 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 includes five projects currently in operation (3,270 kW on Oahu, 28.32 kW on Maui, 750 kW on Hawaii and 250 kW on Molokai). In 2021 and 2022, the Utilities opened their Phase 2, Tranche 1 RFPs and low-to-moderate income RFPs for Oahu, Maui and Hawaii Island, as well as RFPs for Molokai and Lanai. This second phase includes 12.5 MW of dedicated-Low-to-Moderate Income projects, which were expected to become operational in 2026 but have since been delayed. 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. A project was selected in the Lanai RFP, but negotiations were terminated. On July 1, 2022, a replacement project was selected and negotiations commenced. On October 23, 2024, the developer submitted a withdrawal letter to the Utilities. See “Developments in renewable energy efforts–Requests for renewable proposals, expressions of interest, and information” for more information. The Utilities are exploring other options for procuring renewable energy on Lanai. On Molokai, two contracts for solar plus storage facilities with a total capacity of 2.45-MW of photovoltaic (PV) paired with 11.1-MWh of battery energy storage were executed and approved by the PUC on January 8, 2024. The Utilities CBRE Phase 2 Tariff Rule 29 became effective on March 10, 2022. The Utilities are currently still 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. On October 31, 2025, the Utilities filed to the PUC a proposed framework for an update to the CBRE program that the Utilities have named CBRE Phase 3: Utility-Resourced Model. In the proposed framework, the Utilities address challenges with previous phases of the CBRE program with a utility-resourced model and putting a special emphasis on Low-to-Moderate Income customer participation. As of December 31, 2025, there has been no PUC decision on the Utilities’ proposed framework. 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. For Phase 1, the PUC approved the Microgrid Service Tariff developed by the Utilities, which created a regulatory pathway to microgrid development in Hawaii. For Phase 2, the PUC established its Prioritized Issues for Resolution 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. Additionally, 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. On June 12, 2025, the PUC issued an order closing the docket as the PUC believes that the primary objectives of Act 200 have been accomplished. However, the PUC also believes that further modifications to the Microgrid Services Tariff should be explored, such exploration should be within the context of the State’s current resilience needs. To further these objectives, the PUC intends to establish an informal working group. On July 2, 2025, Governor Josh Green signed Senate Bill 589, now known as Act 266, which, among other things, authorizes wheeling of renewable energy (100 kW - 2 MW) and requires the PUC to establish policies related to distributed energy resources, retail wheeling, and microgrid service tariffs. Investigation on the establishment of wheeling. On July 1, 2024, the PUC issued an order to institute a proceeding to investigate the establishment of electricity wheeling policies and procedures for the electric utilities for the State of Hawaii. The 50 PUC stated that it intended to address matters using lessons learned in the initial three docket phases to explore implementation of an intragovernmental wheeling policy and an evaluation of retail wheeling in subsequent phases, as appropriate. On May 15, 2025, the PUC issued an order, suspending the procedural schedule for the docket in consideration of Senate Bill 589, and set a status conference for June 24, 2025. By suspending the procedural schedule and convening a status conference, the PUC sought to facilitate a comprehensive review of Senate Bill 589 and its implications for electricity wheeling in Hawaii. Due to ongoing uncertainties, the PUC subsequently cancelled the status conference on June 19, 2025. For more information on Act 266, see discussion in “Regulatory and legislative developments” above. On August 29, 2025, the PUC issued an order reopening the docket and divided the proceeding into two tracks, Track A, focused on retail wheeling, and Track B, focused on an intragovernmental credit share program that was the subject of the prior procedural schedule in the docket. Among other matters, a new intervention period for interested parties to be admitted as a party to the docket and a new procedural schedule was established. Hawaiian Electric is required to develop a “straw proposal” under Track A, on or before November 10, 2025, for comment by the State of Hawaii Office of Consumer Advocacy, and any other stakeholders, on or before January 20, 2026. On October 16, 2025, the PUC issued an order, addressing the various motions for Participation and Intervention in the docket. On October 22, 2025, the Utilities filed feedback on the PUC’s proposed Track B, Intragovernmental Shared Credit Program. The Utilities support the program but emphasize that careful program design is necessary to ensure technical feasibility, administrative efficiency, and fairness for all customers. The Utilities agree that the program could support the development of Renewable Energy Zones by unlocking government lands for renewable projects and enabling proactive transmission planning. On November 10, 2025, the Utilities filed its Track A Retail Wheeling Straw Proposal. The Utilities note that it is providing a high-level proposal to help identify areas for further detailed discussion as Track A of the docket proceeds and reserves the right to amend the proposal or positions contained herein as discussions continue. The Utilities’ Straw Proposal provides an overview for the application process, a discussion of technical standards for grid interconnection and monitoring, provisions for metering and monitoring and a discussion of pricing mechanisms in the tariff structure and how to appropriately allocate wheeling costs. The Consumer Advocate and stakeholders provided comments on the Utilities’ Straw Proposal by January 20, 2026. The Utilities are to file responses to the comments of the Consumer Advocate and stakeholders on March 6, 2026. 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. The Utilities are currently exploring a collaborative non-rate case re-basing proposal under the PBR Framework as an alternative to a rate case process. See “Regulatory proceedings” in Note 4 of the Consolidated Financial Statements for a discussion of re-basing, PBR Framework and 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 (i.e., above 12.5% or below 6.5%). 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. On August 31, 2023, the PUC issued an order temporarily suspending the Earnings Sharing Mechanism (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 ESM remains suspended and the earnings sharing adjustment for 2025 is zero as of December 31, 2025. Actual and PUC-allowed returns, as of December 31, 2025, were as follows: Ratio (%) Rate-making Return on rate base (RORB)* Book ROACE** Rate-making ROACE*** Year ended December 31, 2025 Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric Utility returns 7.61  6.65  4.49  19.27  9.51  3.48  9.92  8.19  4.54  PUC-allowed returns 7.37  7.52  7.43  9.50  9.50  9.50  9.50  9.50  9.50  Difference 0.24  (0.87) (2.94) 9.77  0.01  (6.02) 0.42  (1.31) (4.96) *       Based on recorded operating income and average rate base, both adjusted for items not included in determining electric rates. 51 **     Based on recorded net income divided by average common equity. ***   Based on recorded net income adjusted to remove items not included in determining electric rates, divided by rate making equity. Rate-making calculations remove the impacts of the Settlement Agreements and eliminate the balances for the asset-based lending facility (ABL Facility) on a stand-alone company basis. The Utilities have stated that customers will not be impacted by payments related to the Settlement Agreements for the Maui windstorm and wildfires, which are expected to be $1.9 billion (see Note 2 of the Consolidated Financial Statements). The ABL Facility contains certain intercompany costs related to the ABL Facility that are eliminated on a consolidated basis, and these transactions are eliminated on a stand-alone company basis for rate-making. Therefore, the rate-making returns were adjusted to exclude these impacts. 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, other operation and maintenance (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). In 2025, Maui Electric's returns are lower than allowed levels due to higher sustained maintenance and investments than what is recovered in current rates. 52 Results of operations. 2025 vs. 2024 2025 2024 Increase (decrease) (dollars in millions, except per barrel amounts) $ 3,071 $ 3,207 $ (136) Revenues. Net decrease largely due to: $ (132) lower fuel oil prices partially offset by higher kWh generated1 (27) lower purchased power energy prices, partially offset by higher kWh purchased and higher PPAC revenues2 (2) lower Major Project Interim Recovery (MPIR) revenue 4  higher Demand-Side Management revenue 23  higher revenue from ARA 947 1,078 (131) Fuel oil expense1. Net decrease largely due to lower fuel oil prices and better heat rate performance, partially offset by higher kWh generated 678 703 (25) Purchased power expense1,2. Net decrease largely due to lower purchased power energy prices, along with liquidated damages due to project delays and performance deficiency, offset in part by higher kWh purchased and continued addition of Stage 1 and Stage 2 renewable projects 620 610 10  Operation and maintenance expense. Net increase largely due to: 10  higher Maui windstorm legal and consulting costs primarily due to deferral of similar costs in 2024 7  higher incentive compensation programs 7  higher IT consulting and system maintenance expenses 6  higher property and general liability insurance costs 6  higher wildfire mitigation program related to vegetation management and inspections 3  higher pilot process and Demand Response cost (4) 2024 accrual for settlement administration fees (10) deferral of Wildfire Safety Strategy costs in 2025 (17) the settlement of indemnification claims asserted by the State of Hawaii in 2024 3 —  1,875  (1,875) Wildfire tort-related claims, net. Decrease due to the accrual of estimated wildfire liability related to the settlement of the Maui windstorm and wildfire tort-related legal claims and cross claims in 2024 546 552 (6) Other expenses. Decrease due to lower revenue taxes partially offset by higher depreciation expense due to increasing investments to integrate more renewable energy and improve customer reliability and system efficiency 280 (1,612) 1,892  Operating income (loss). Increase largely due to wildfire tort-related claims in 2024, higher ARA revenue, better heat rate performance, offset in part by higher operation and maintenance expenses 221 (1,664) 1,885  Income (loss) before income taxes. Increase largely due to higher operating income, higher interest income earned, and higher AFUDC related to increased capital expenditures, offset in part by higher interest expense 168 (1,226) 1,394  Net income (loss) for common stock. Increase due to higher income before income taxes, partially offset by loss on redemption of preferred stock. See below for effective tax rate explanation 12.3  % NM NM Return on average common equity $ 100.40 $ 115.00  $ (14.60) Average fuel oil cost per barrel 8,423 8,219  204  Kilowatt-hour sales (millions)4 2,608 2,518  90  Number of full-time employees (at December 31) 1The rate schedules of the 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 Utilities currently contain purchased power adjustment clauses (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 Consolidated Financial Statements. 4kWh sales were higher compared to the prior year. The increase in sales can be primarily attributed to warmer weather across the service territory and the recovery from the impacts from the Maui windstorm and wildfires. NM - Not meaningful. Hawaiian Electric’s effective tax rate (combined federal and state income tax rates) in 2025 was 22% (tax expense) compared to 26% (tax benefit) in 2024. The effective tax rate in 2025 was lower than 2024 primarily due to the substantial pre- 53 tax loss in 2024 resulting from the accrual of the loss contingencies related to the wildfire tort-related claims and because the impact of permanent items had a smaller impact on the effective tax rate in 2024, partially offset by lower research and development tax credit claims in 2025. For a discussion of 2023 results, please refer to the “Results of operations” section in Item 7, “Management Discussion and Analysis of Financial Condition and Results of Operations—Electric utility,” in the Company’s 2024 Form 10-K. For more information of the Utilities’ incremental expenses related to the Maui windstorm and wildfires for the year ended December 31, 2025, see “Results of operations—Maui windstorm and wildfires related expenses, net” in HEI’s MD&A. The net book value (cost less accumulated depreciation) of utility property, plant and equipment (PPE) as of December 31, 2025 amounted to $5.8 billion, of which approximately 18% related to generation PPE, 66% related to transmission and distribution PPE, and 16% related to other PPE. Approximately 5% 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. Developments in renewable energy efforts.  The Utilities continue to procure renewable energy ambitiously. The Utilities’ renewable energy goals depend, in large part, on the success of renewable projects developed and operated by independent power producers. 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 Consolidated Financial Statements and the following: New renewable PPAs. •Under a request for proposal process governed by the PUC and monitored by independent observers, the Utilities issued Stage 2 Renewable RFPs for Oahu, Maui and Hawaii Island and Grid Services RFP on August 22, 2019. Of the 11 PPAs filed by the Utilities, 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. 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 approved all three amendments. To date, two Stage 2 projects have reached commercial operations. See also “Purchase commitments” in Note 4 of the Consolidated Financial Statements. Separately, the PUC approved the Utilities’ Waena Battery Energy Storage System project under Stage 2. See “Utility projects” in Note 4 of the Consolidated Financial Statements. A summary of the remaining four approved Stage 2 PPAs and the self-build project is as follows: Utilities Number of contracts Total photovoltaic size (MW) BESS Size (MW/MWh) Guaranteed commercial operation dates Contract term (years) Total projected annual lump sum payment (in millions) PPAs Hawaiian Electric 3 79 79 / 443 5/17/24*, 6/7/24 & 9/1/24* 20 & 25 $ 31.4  Hawaiian Electric 1 N/A 185 / 565 12/19/23 20 24.0  Self-build Maui Electric 1 40 / 160 11/30/26 Total 5 79 304 / 1,168 $ 55.4  * Project delays have resulted in Guaranteed Commercial Operations Date being missed. 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. •Additionally, two Grid Services Purchase Agreements were filed with the PUC. The two Grid Services Purchase Agreements were approved by the PUC in December 2020. One of the aggregators has had financial difficulties and therefore, Hawaiian Electric terminated the Grid Services Purchase Agreement contract on January 29, 2025. On February 7, 2025, Hawaiian Electric requested for approval for an interim solution for the roughly 1,200 stranded customers to the PUC. Hawaiian Electric will proceed with implementing the alternative solution, pending PUC approval. 54 A summary of the Grid Services Purchase Agreements that were approved by the PUC in December 2020 is as follows: Utilities Fast Frequency Response - 1 (MW) Fast Frequency Response - 2 (MW) Capacity - Load Build (MW) Capacity - Load Reduction (MW) Hawaiian Electric — 26.7 14.5 19.4 Hawaii Electric Light 6.0 — 3.2 4.0 Maui Electric 6.1 — 1.9 4.7 Total 12.1 26.7 19.6 28.1 See also “Commitments and Contingencies—Waena Battery Energy Storage System Project” in Note 4 of the Consolidated Financial Statements for further discussion. Tariffed renewable resources. •As of December 31, 2025, there were approximately 719 MW, 155 MW and 159 MW of installed distributed renewable solar energy technologies 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, Interim Smart Export, Smart Distributed Energy Resources — Export, Smart Distributed Energy Resources — Non-Export, Battery Bonus, Community-Based Renewable Energy, and Bring Your Own Device. As of December 31, 2025, an estimated 45% of single-family homes on the islands of Oahu, Hawaii and Maui have installed private rooftop solar systems, and approximately 25% of the Utilities’ total customers have solar systems.  •The Utilities’ feed-in tariff program is designed to encourage the addition of more renewable energy projects in Hawaii. As of December 31, 2025, 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 August 23, 2024, the Utilities issued an RFP for biodiesel fuel supply commencing February 1, 2026. Proposals were due on September 30, 2024, and the Utilities have completed negotiations with two suppliers and submitted an application to the PUC on April 3, 2025. On June 2, 2025, the Utilities and Pacific Biodiesel Technologies, LLC (PBT) signed an agreement for supply of biodiesel commencing February 1, 2026, which was approved by the PUC on January 14, 2026. •On June 30, 2021, the Utilities issued an RFP for all fuels, including biodiesel, for supply commencing January 1, 2023. On December 13, 2021, the Utilities and PBT signed an agreement 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 2026. •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 2026 and will continue with no volume purchase requirements. Requests for renewable proposals, expressions of interest, and 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. 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, which included one utility self-build project and one proposal that requires two contracts, were selected to the Final Award Group on December 8, 2023. On February 2, 2024, one additional project totaling 40 MW of firm renewable generation was selected. Of the 16 projects, one solar-plus storage and one firm renewable generation project on Oahu, one solar-plus storage project on Maui, and two solar-plus storage projects on Hawaii Island have been withdrawn by the developers. Contracts for three paired PV with storage projects have been executed and filed with the PUC for approval. On April 21, 2025, the PUC dismissed the three applications without prejudice and directed that new applications be filed upon completion of the respective 55 Interconnection Requirement Study. A contract for a firm generation project on Maui was executed on September 22, 2025 and filed with the PUC for approval on September 26, 2025. On November 12, 2025, the PUC suspended the firm generation project’s docket to address the applicability of Hawaii Revised Statutes Chapter 343 (Hawaii Environmental Policy Act) to the project. In addition, two solar-plus storage projects on Oahu were executed on November 24, 2025 and December 18, 2025, and filed with the PUC for approval on November 26, 2025 and December 23, 2025, respectively. One solar-plus project on Maui was executed on December 22, 2025, and filed with the PUC for approval on December 23, 2025. Negotiations for the remaining projects are ongoing. On March 28, 2025, the Utilities filed an application to the PUC for their self-build project - Waiau Repower Project. The project was estimated at $847 million and involves replacing six existing turbines with six fuel-flexible combustion turbines that provide 253 MW of renewable firm generation, expected to be placed in service in 2033. The Utilities request, among other things, approvals of 1) the commitment of funds for such project, and 2) recovery of project costs through the EPRM. On October 17, 2025, the Utilities filed an updated application reflecting revised costs of $1.16 billion, citing unavoidable and changed market conditions outside the Utilities' control. The Utilities are requesting a decision from the PUC by March 13, 2026. A summary of the Stage 3 PPAs and self-build project is as follows: Utilities Number of contracts Total photovoltaic size (MW) BESS Size (MW/MWh) Firm Generation (MW) PPAs Hawaiian Electric 4 126 510 307 Hawaii Electric Light 3 86 374 60 Maui Electric 4 90 240 40 Self-build project Hawaiian Electric 1 — — 253 Total 12 302 1,124 660 •On August 19, 2024, the PUC opened a docket for the Utilities’ Integrated Grid Planning RFP (IGP RFP). On August 26, 2024, the Utilities filed their draft IGP RFP for Oahu and Hawaii Island. The Oahu portion of the IGP RFP seeks 750 GWh per year of energy and 350 MW of grid forming resources by November 1, 2030, and 81 MW of renewable firm capacity by December 2033. The Hawaii Island portion of the IGP RFP seeks 435 GWh per year of energy and 115 MW of grid forming resources by November 1, 2030, and 30 MW of renewable firm capacity by December 2032. On January 9, 2025, the PUC issued a decision and order (D&O) converting the docket into a contested case proceeding and opened a period for interested parties to move to intervene or participate. An updated draft IGP RFP with supporting documentation was filed on April 3, 2025. The Utilities’ Reply Statement of Position and an updated draft IGP RFP with supporting documentation was filed on May 2, 2025. Multiple supplemental filings were made in June 2025. On July 7, 2025, the PUC issued a D&O extending the procedural schedule to August 18, 2025, to allow parties to the docket to ask information requests and submit Statements of Position. On August 14, 2025, the PUC issued a D&O extending the deadline for the Utilities to file a Reply Supplemental Statement of Position from August 18, 2025 to August 25, 2025. On August 18, 2025, the Utilities filed a request with the PUC for approval to not offer utility-owned sites to other potential bidders. On August 25, 2025, the Utilities filed its Reply Supplemental Statement of Position, completing the steps in the procedural schedule. On September 2, 2025, the PUC issued a D&O modifying the procedural schedule to September 9, 2025 to receive responses by any of the parties to the Utilities’ request filed on August 18, 2025. On September 9, 2025, the Consumer Advocate filed a response indicating it did not object to the Utilities’ request and a party to the docket filed a response requesting that the PUC consider the broader market impacts that limiting available sites would have on the available interconnection capacity and market competitiveness. On December 12, 2025, the Utilities filed its response to an additional PUC information request. 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 “Item 1. Business” and Note 4 of the Consolidated Financial Statements. Federal grant. The Utilities continue to pursue government grants or assistance to help the Utilities create a safe, modern, resilient, flexible and dynamic electric grid in Hawaii. On August 7, 2024, the Utilities received a notification from the U.S. Department of Energy that their Climate Adaption Transmission and Distribution Resilience Program (Resilience Program) application for $95 million in federal funds was officially awarded. See “Utility projects” in Note 4 of the Consolidated Financial Statements for additional discussions. There is no assurance that the federal government will reimburse in a timely manner or may dispute reimbursement. 56 In 2025, President Trump has issued multiple executive orders that impact federal funding. The Utilities continue to monitor for any new executive orders and any changes that are passed down through the federal contracting officer for the Resilience Program. 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 (Supply Agreement) commencing January 1, 2023. On December 1, 2022, the PUC issued a D&O approving the PAR Hawaii fuels contract and recovery of associated costs through ECRC. On August 14, 2024, the Utilities entered into a second amendment of the Supply Agreement. The second amendment extends the term of the Supply Agreement by additional three years and creates savings in fuel costs. The second amendment became effective on June 18, 2025, upon the issuance of the final D&O by the PUC. 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 measures to ensure adequate supply of fuel by entering into a backup fuel supply contract with Vitol Inc. (Vitol) commencing on December 1, 2022 through June 30, 2023, with annual extensions if mutually agreed by both parties. The fuel supply contract was extended to June 30, 2026. 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. Liquidity and capital resources. As discussed in Note 2 of the Consolidated Financial Statements, HEI and Hawaiian Electric determined that making payments under the terms of the Settlement Agreements in four equal annual installments is the most viable option and have classified the first $479 million installment as a current liability based on expected timing of the payment and the remaining $1.44 billion as a noncurrent liability on the Utilities’ Consolidated Balance Sheets. To finance the first installment payment, in September 2024, HEI completed the sale of 62.2 million shares of common stock in a registered offering, raising net proceeds of approximately $557.7 million. In addition, HEI transferred the amount of the first payment, $479 million, into a new subsidiary, GLST1, which is restricted from disbursing such funds except in connection with the initial payment to the settlement funds. HEI expects to make this initial payment no sooner than early 2026. In addition, HEI filed a shelf registration statement with the SEC for an at-the-market offering program under which HEI may offer and sell, from time to time at its sole discretion, its common stock, without par value, having an aggregate offering price of up to $250 million. To date, HEI has not sold any common stock under this program. Management believes that HEI’s current cash and cash equivalents balances of $501.8 million as of December 31, 2025, which includes $486.2 million at Utilities, the available capacity on Hawaiian Electric’s ABL Facility (see Note 6 of the Consolidated Financial Statements), and the additional liquidity from HEI’s at-the-market offering program provide sufficient liquidity to fund operations and satisfy their other obligations for the next 12 months following the issuances of their financial statements. 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. 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 their business remain strong, the Utilities took prudent and measured actions to strengthen their financial position while continuing to provide reliable service to their customers and reinforcing their 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. The Utilities have repaid the entire draw down from August 2023 as of December 31, 2025. On September 5, 2025, HEI and Hawaiian Electric each entered into a fourth amended and restated credit agreement with a syndicate of eight financial institutions, increasing each of their committed capacities to $300 million (see Note 6 of the Consolidated Financial Statements). Longer term, the Utilities entered into an asset-based credit facility that allows borrowing up to $250 million (see Note 6 of the Consolidated Financial Statements) and are also evaluating other sources of liquidity that could include securitization, re-prioritizing capital spending and reducing O&M, issuing unsecured debt, and conducting asset sales, among others. 57 The following table provides the components of available liquidity under existing facilities. As of December 31, 2025 (in millions) Capacity Outstanding Undrawn Unsecured revolving line of credit $ 300  $ —  $ 300  ABL Facility 240  —  240  Borrowing from HEI - standing commitment letter 75  —  75  Total credit $ 615  $ —  615  Cash and cash equivalents 486  Total available liquidity from cash and under existing facilities $ 1,101  As of December 31, 2025, Hawaiian Electric had no commercial paper outstanding. Hawaii Electric Light and Maui Electric had no short-term borrowings from Hawaiian Electric but had long-term intercompany loans from Hawaiian Electric in the amount of $25 million and $90 million, respectively, as of December 31, 2025. See Notes 6 and 7 of the Consolidated Financial Statements for a brief description of Hawaiian Electric’s loans. Hawaiian Electric’s consolidated capital structure was as follows: December 31 2025 2024 (dollars in millions) Short-term borrowings, net $ —  — % $ 49  1 % Long-term debt, net 2,183  58  1,901  61  Preferred stock —  —  34  1  Common stock equity 1,583  42  1,157  37  $ 3,766  100 % $ 3,141  100 % As of December 31, 2025, the Utilities are in compliance with all applicable financial covenants and expect to continue to be in compliance with all the financial covenants in the next 12 months. However, the Utilities cannot predict the future effects on the Utilities’ ability to access additional capital or the future impacts on the Utilities’ financial position, results of operations, and cash flows. The Utilities’ liquidity has improved, but continues to be impacted from the downgrades of their credit ratings, which result in higher credit spreads compared to investment grade credit spreads. Progress made in finalizing the litigation settlement and legislation that was passed allowing securitization of rates improved access to capital markets. On September 18, 2025, Hawaiian Electric issued $500 million in unsecured senior notes with an interest rate of 6.00% (2025 Notes). A portion of the proceeds was used to repay the outstanding balance of the Utilities’ revolving and term loan facilities and the remaining proceeds are intended to be used to 1) finance capital expenditures, 2) repay long-term debt and short-term debt used to finance or refinance capital expenditures, and 3) reimburse funds used for the payment of capital expenditures. 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 of lines in high-risk locations will be significantly more expensive than using overhead lines and will thus result in increased costs. 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 issued by the State of Hawaii Department of Budget and Finance 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 lower cost sources of capital. 58 Credit ratings. On May 28, 2025, June 4, 2025 and June 27, 2025, Moody’s, Fitch and S&P, respectively, upgraded the credit ratings of Hawaiian Electric. As of February 17, 2026, the Fitch, Moody’s and S&P ratings of Hawaiian Electric were as follows: Fitch Moody’s S&P From1 To From1 To From1 To Long-term issuer default, long-term and issuer credit, respectively B BB- Ba3 Ba2 B- B+ Short-term issuer default, commercial paper and commercial paper, respectively B B NP NP B B Senior unsecured debt/special purpose revenue bonds B+ BB Ba3 Ba2 * * Cumulative preferred stock (selected series) * * B3 WR2 * * Outlook Stable Positive Stable Positive  Negative Watch Positive 1     As of December 31, 2024. In March 2025, S&P revised Hawaiian Electric’s outlook to “Positive” from “Negative” and affirmed the “B-” issuer credit rating 2    Rating withdrawn due to preferred stock redemption in the fourth quarter of 2025. *    Not rated. NP - Not Prime WR - Withdrawn rating Note: The above ratings reflect only the view, at the time the ratings are issued or affirmed, of the applicable rating agency, from whom an explanation of the significance of such ratings may be obtained. Such ratings are not recommendations to buy, sell or hold any securities; such ratings may be subject to revision or withdrawal at any time by the rating agencies; and each rating should be evaluated independently of any other rating. See “Credit and Capital Market Risk” in Item 1A. Risk Factors. The downgrades of Hawaiian Electric’s credit ratings will continue to adversely impact the Utilities’ ability to access lower cost sources of capital. 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 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. Hawaiian Electric received the first and second approvals from the PUC for the ABL Credit Facility Agreement that allows short-term and long-term borrowings of up to $250 million on June 27, 2024 and October 11, 2024, respectively, subject to the availability of a sufficient borrowing base of eligible receivables. The ABL Facility became effective on July 24, 2024. As of December 31, 2025, total available capacity under the ABL Facility was $240 million and remains undrawn. 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 Utilities have repaid the entire draw down from August 2023 as of December 31, 2025, by making payments of $34 million in 2024 and $45 million, $78 million, and $43 million in the first, second, and third quarters of 2025, respectively. On September 24, 2025, Hawaiian Electric requested PUC approval of its fourth amended and restated revolving unsecured syndicated credit facility agreement, including approving extending its term to September 5, 2030 from September 4, 2026. See Note 6 of the Consolidated Financial Statements for additional information. Taxable debt. On July 24, 2025, the Utilities received PUC approval to issue during the three-year period 2025 through 2027, unsecured obligations bearing taxable interest (Hawaiian Electric up to $900 million, Hawaii Electric Light up to $115 million and Maui Electric up to $150 million), to finance capital expenditures, repay long-term and/or short-term debt used to finance or refinance capital expenditures, and/or to reimburse funds used for payment of capital expenditures. Pursuant to the approval, on September 18, 2025, Hawaiian Electric issued $500 million in unsecured senior notes with an interest rate of 6.00%. A portion of the proceeds was used to repay the outstanding balance of the Utilities’ revolving and term loan facilities and the remaining proceeds are intended to be used to 1) finance capital expenditures, 2) repay long-term debt and short-term debt used to finance or refinance capital expenditures, and 3) reimburse funds used for the payment of capital expenditures. The 2025 Notes will mature on October 1, 2033. 59 On November 3, 2025, Hawaiian Electric made long-term intercompany loans to Hawaii Electric Light and Maui Electric in the amount of $25 million and $90 million, respectively. The interest rate and term of the loans are the same as Hawaiian Electric’s 2025 Notes. The long-term intercompany loans are eliminated in the total consolidated Hawaiian Electric amounts. See summary table below for remaining authorized amounts as of December 31, 2025 for each respective utility. (in millions) Hawaiian Electric Hawaii Electric Light Maui Electric Total “up to” amounts of taxable debt authorized from 2025 through 2027 $ 900  $ 115  $ 150  Less: taxable debt executed on September 18, 2025/ long-term intercompany loans 500  25  90  Remaining authorized amounts $ 400  $ 90  $ 60  As of December 31, 2025, the Utilities have $2.2 billion of long-term debt, of which $125 million is due or expected to be repaid within 12 months. Equity. On October 28, 2025, the Utilities received PUC approval to issue and sell each utility’s common stock over a three-year period from January 1, 2025 through December 31, 2027 (Hawaiian Electric sale/s to HEI of up to $210 million, Hawaii Electric Light sale/s to Hawaiian Electric of up to $70 million, and Maui Electric sale/s to Hawaiian Electric of up to $145 million) and the purchase of Hawaii Electric Light and Maui Electric common stock by Hawaiian Electric. As of December 31, 2025, no common stock has been issued under this authorization. Cash flows. The following table reflects the changes in cash flows for the year ended December 31, 2025 compared to the year ended December 31, 2024: Years ended December 31 (in thousands) 2025 2024 Change Net cash provided by operating activities $ 437,086  $ 465,733  $ (28,647) Net cash used in investing activities (333,431) (317,631) (15,800) Net cash provided by (used in) financing activities 198,417  (72,031) 270,448  Net cash provided by operating activities: The decrease in net cash provided by operating activities was primarily driven by higher cash paid for fuel oil stock due to higher volume purchased, and higher cash paid for accounts payable due to timing, partially offset by lower income taxes paid. Net cash used in investing activities: The increase in net cash used in investing activities was primarily driven by an increase in capital expenditures related to construction activities. Net cash provided by financing activities: The increase in net cash provided by financing activities was largely driven by higher proceeds from the issuance of long-term debt, primarily offset by the repayment of long- and short-term debt and the redemption of preferred stock. 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 2024 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 Consolidated Financial Statements), O&M expenses, labor and benefits 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 Utilities’ credit rating downgrades related to the Maui windstorm and wildfires will continue to adversely impact their ability to access lower cost sources of capital. Through the sale of common stock in September 2024, HEI has raised sufficient cash to pay the first installment of the settlement of wildfire tort claims expected to be made no sooner than early 2026. HEI is currently working with its financial advisors on a financing plan to raise the additional capital required to fund the remaining wildfire tort claims. While management believes that HEI will be able to raise the necessary capital, there is no assurance that 60 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 Consolidated Financial Statements), the economic impact of higher fuel prices, inflation, higher 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. Selected short-term and long-term contractual obligations and commitments.  See “Selected short-term and long-term contractual obligations and commitments” in HEI’s MD&A for more information on the Utilities’ contractual obligations and commitments. Competition.  Although competition in the generation sector in Hawaii is moderated by the scarcity of generation sites, various permitting processes and lack of interconnections to other electric utilities, the PUC has promoted a more competitive electric industry environment through its decisions concerning competitive bidding and distributed generation. An increasing amount of generation is provided by IPPs and customer distributed generation. Competitive bidding.  On June 30, 2022, the PUC issued a decision that included a final Integrated Grid Planning Framework for Competitive Bidding that succeeded the original Framework for Competitive Bidding adopted on December 8, 2006. The final Integrated Grid Planning Framework for Competitive Bidding states, among other things, that: (1) a utility is required to use competitive bidding to acquire system resources unless the PUC finds bidding to be unsuitable; (2) the framework does not apply in certain situations identified in the framework; (3) waivers from competitive bidding for certain circumstances will be considered; (4) as ordered by the PUC, the PUC or the electric utility shall identify qualified candidates for an independent observer and select an independent observer from the final list of identified qualified candidates; (5) the utility may consider its own self-bid proposals in response to system resource needs identified in its RFP; and (6) for any resource to which competitive bidding does not apply (due to waiver or exemption), the utility retains its traditional obligation to offer to purchase capacity and energy from a Qualifying Facility (QF) at avoided cost upon reasonable terms and conditions approved by the PUC. In 2024, the PUC proposed certain revisions to the Integrated Grid Planning Framework for Competitive Bidding, and Hawaiian Electric provided comments and proposed additional modifications. On February 25, 2025, the PUC issued an order adopting the modifications. Technological developments.  New emerging and breakthrough technological developments may impact the Utilities’ future competitive position, results of operations, financial condition and liquidity. The Utilities continue to seek prudent opportunities to develop, test, pilot, and implement technologies that align with their technical and business plans and support WSS, clean energy and decarbonized goals, while ensuring reliability and resilience as the Utilities adapt to evolving climate dynamics. Technologies that the Utilities are evaluating include the commercial development of enhanced fault detection and advanced protection schemes that would monitor, detect, and isolate falling overhead distribution and transmission lines to reduce wildfire risks and improve public/employee safety. Other technologies include long-duration energy storage, grid-forming and black starting inverters in low inertia power systems, microgrids, distributed generation, grid modernization, and electrification of transportation. The Utilities also plan to start to use artificial intelligence and machine learning to test predictive analytics and control through edge computing to help assess the state of health of utility assets and prevent premature failure, and the diversification of generation from renewable sources. Environmental matters.  See “Electric utility—Regulation—Environmental regulation” under “Item 1. Business” and “Environmental regulation” in Note 4 of the Consolidated Financial Statements. Commitments and contingencies. See Item 1A. Risk Factors, and Note 4 of the Consolidated Financial Statements for a discussion of important commitments and contingencies. Off-balance sheet arrangements. See “Off-balance sheet arrangements” above in HEI Consolidated section. Material estimates and critical accounting policies.  Also see “Material estimates and critical accounting policies” above in HEI Consolidated section. Regulatory assets and liabilities.  The Utilities are regulated by the PUC. In accordance with accounting standards for regulatory operations, the Company’s and the Utilities’ financial statements reflect assets, liabilities, revenues and costs of the Utilities based on current cost-based rate-making regulations. The actions of regulators, including the PBR Framework, can affect the timing of recognition of revenues, expenses, assets and liabilities. Regulatory liabilities represent amounts collected from customers for costs that are expected to be incurred in the future, or amounts collected in excess of costs incurred that are refundable to customers. Regulatory assets represent incurred costs that have been deferred because their recovery in future customer rates is probable. As of December 31, 2025, the consolidated regulatory liabilities and regulatory assets of the Utilities amounted to $1,444 million and $308 million, respectively, compared to $1,244 million and $281 million as of December 31, 2024, respectively. Regulatory liabilities and regulatory assets are 61 itemized in Note 4 of the Consolidated Financial Statements. Management continually assesses whether the regulatory assets are probable of future recovery by considering factors such as changes in the applicable regulatory environment. The Utilities record regulatory assets and liabilities when they are deemed probable of recovery from or refund to customers. Determining probability requires significant judgment by management and includes considerations of regulatory orders, proposed regulatory treatment, strength of the applications and other available evidence. Management believes that the operations of the Utilities, including the impact of the approved PBR Framework, currently satisfy the criteria for regulatory accounting. If events or circumstances should change so that those criteria are no longer satisfied, the Utilities expect that their regulatory assets, net of regulatory liabilities, would be charged to the statement of income in the period of discontinuance, which may result in a material adverse effect on the Company’s and the Utilities’ results of operations, financial condition and liquidity. Asset retirement obligations. The Utilities recognize AROs at present value of expected costs to retire long-lived assets from service, which is estimated using a discounted cash flow model that relies on significant estimates and assumptions about future decommissioning costs, inflationary rates, and the estimated date of decommissioning. The estimated future cash flows are discounted using a credit-adjusted risk-free rate to reflect the risk associated with decommissioning the assets. The Utilities have not recorded AROs for assets that are expected to operate indefinitely or where the Utilities cannot estimate a settlement date (or range of potential settlement dates.) As such, ARO liabilities are not recorded for certain asset retirement activities, including various Utility-owned generating facilities and certain electric transmission, distribution and telecommunication assets resulting from easements over property not owned by the Utilities.     Changes in estimated costs, timing of decommissioning or other assumptions used in the calculation could cause material revision on the recorded liabilities. As of December 31, 2025 and December 31, 2024, the Utilities’ AROs totaled $13.0 million and $12.5 million, respectively.