EDGAR 10-K Filing

Company CIK: 46207
Filing Year: 2025
Filename: 46207_10-K_2025_0000354707-25-000013.json

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ITEM 1. BUSINESS
ITEM 1. BUSINESS
HEI Consolidated
HEI and subsidiaries and lines of business. HEI is a holding company with its subsidiaries principally engaged in electric utility and non-regulated renewable/sustainable infrastructure businesses operating in the State of Hawaii. As a holding company with no significant operations of its own, HEI’s sources of funds are dividends or other distributions from its operating subsidiaries, borrowings, and sales of equity. The rights of HEI and its creditors and shareholders to participate in any distribution of the assets of any of HEI’s subsidiaries are subject to the prior claims of the creditors and preferred shareholders of such subsidiary, except to the extent that claims of HEI in its capacity as a creditor are recognized as primary. The abilities of certain of HEI’s subsidiaries to pay dividends or make other distributions to HEI are subject to contractual and regulatory restrictions (see Note 15 of the Consolidated Financial Statements). HEI is headquartered in Honolulu, Hawaii and 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 and its operating utility subsidiaries, Hawaii Electric Light Company, Inc. (Hawaii Electric Light) and Maui Electric Company, Limited (Maui Electric), are regulated electric public utilities that provide essential electric service to approximately 95% of Hawaii’s population through the operation of five separate grids that serve communities on the islands of Oahu, Hawaii, Maui, Lanai and Molokai. See also “Electric utility” section below.
All Other. The All Other non-reportable segment is composed of HEI’s corporate-level operating, general and administrative expenses and the results of Pacific Current, LLC (Pacific Current). Pacific Current was formed in September 2017 to focus on investing in non-regulated clean energy and sustainable infrastructure in the State of Hawaii to help reach the state’s sustainability goals. See also “Electric utility-Hawaii Electric Light firm capacity PPAs” section below and Note 3 of the Consolidated Financial Statements for additional information on Pacific Current activities. The All Other segment also includes ASB Hawaii, Inc. (ASB Hawaii) (a holding company), which previously owned ASB.
Additional information. Prior to December 31, 2024, ASB Hawaii owned ASB, a federally chartered, full-service Hawaii community bank. ASB was a reportable segment of HEI, until its sale on December 31, 2024. For additional information about HEI, see HEI’s MD&A, HEI’s “Quantitative and Qualitative Disclosures about Market Risk” and HEI’s Consolidated Financial Statements.
The Company’s website address is www.hei.com, where annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to those reports (last 10 years) are made available free of charge in the Investor Relations section as soon as reasonably practicable after such material is electronically filed with, or furnished to, the SEC (and available at the SEC’s website at www.sec.gov). The information on the Company’s website is not incorporated by reference in this annual report on Form 10-K unless, and except to the extent, specifically incorporated herein by reference. HEI and Hawaiian Electric intend to continue to use HEI’s website as a means of disclosing additional information. Accordingly, investors should routinely monitor such portions of HEI’s website, in addition to following HEI’s and Hawaiian Electric’s press releases, SEC filings and public conference calls and webcasts. Investors may also wish to refer to the PUC website at hpuc.my.site.com/cdms/s/ in order to review documents filed with and issued by the PUC. No information at the PUC website is incorporated herein by reference, and the Company has no control over its accuracy or completeness.
Regulation. HEI and Hawaiian Electric are each holding companies within the meaning of the Public Utility Holding Company Act of 2005 and implementing regulations, which requires holding companies and their subsidiaries to grant the Federal Energy Regulatory Commission (FERC) access to books and records relating to FERC’s jurisdictional rates. FERC granted HEI and Hawaiian Electric a waiver from its record retention, accounting and reporting requirements, effective May 2006.
HEI is subject to an agreement entered into with the PUC (the PUC Agreement) which, among other things, requires PUC approval of any change in control of HEI. The PUC Agreement also requires HEI to provide the PUC with periodic financial information and other reports concerning intercompany transactions and other matters. It also prohibits the electric utilities from loaning funds to HEI or its nonutility subsidiaries and from redeeming common stock of the electric utility subsidiaries without PUC approval. Further, the PUC could limit the ability of the electric utility subsidiaries to pay dividends on their common stock. See also Note 15 of the Consolidated Financial Statements and “Electric utility-Regulation” below.
In October 2021, Pacific Current requested informal guidance from the PUC regarding application of the affiliate transaction requirements (ATRs) to certain investments. In response, in January 2022, the PUC issued guidance (Order No. 38186, Docket No. 2018-0065) providing that, if Pacific Current acquires or invests in an unaffiliated entity that has been awarded a power purchase agreement with the Utilities through the Stage 1 or 2 Request for proposals (RFPs), such entity
would become an “Affiliate” or “Affiliate-Related Entity” under the ATRs, and any wholesale power transactions between the entity and the Utilities, including under the awarded power purchase agreement, would require PUC review and approval. Such a requirement may impact Pacific Current’s competitiveness in acquiring and investing in new utility-scale projects in the Utilities’ service territory and thereby impact the pace and extent of Pacific Current’s growth. As a result of the D&O, Pacific Current intended to focus its future growth activities on projects not subject to a power purchase agreement with the Utilities or projects outside of the Utilities’ service territory. However, subsequent to the Maui windstorm and wildfires, HEI and Pacific Current have suspended any new investments while undertaking a comprehensive review of strategic options for certain assets of Pacific Current.
On December 30, 2024, HEI, ASB and ASB Hawaii 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, while retaining 9.9% of the common stock of ASB. The sale transaction closed on December 31, 2024 and no investor, including HEI, retains or owns more than 9.9% of the common stock of ASB. As HEI and ASB Hawaii no longer have a controlling interest in ASB, HEI and ASB Hawaii are in the process of deregistering themselves as “unitary savings and loan holding companies” and upon final deregistration approval, would no longer be subject to applicable federal and state regulation and supervision (including under the Federal Reserve Board and Office of the Comptroller of the Currency).
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, LLC, a wholly owned subsidiary of Pacific Current, to an unaffiliated third party for cash consideration to be determined under the provisions of the agreement. Hamakua Holdings, LLC has two wholly-owned subsidiaries: Hamakua Energy, LLC, which owns a 60-MW combined cycle power plant that sells power to Hawaii Electric Light under an existing power purchase agreement, and HAESP, LLC (created in connection with the current on-going Stage 3 RFP process). Upon closing, both Hamakua Energy and HAESP, LLC as wholly-owned subsidiaries of Hamakua Holdings will no longer be owned by Pacific Current. The close of the transaction is subject to the satisfaction of certain customary closing conditions and is expected to be finalized in March 2025. The sale transaction is not expected to have a material impact to the Company’s consolidated financial statements.
Environmental regulation. HEI and its subsidiaries are subject to federal and state statutes and governmental regulations pertaining to water quality, air quality and other environmental factors. See the “Environmental regulation” discussion in the “Electric utility” section below, and Note 1 of the Consolidated Financial Statements.
Human Capital Resources. The Company’s workforce and culture are critical to its ability to achieve its business strategies. As such, the Company seeks to attract, retain and develop a talented workforce and create a high-performing, inclusive and safety-driven culture.
Employees. The Company had total and full-time employees as follows:
December 31 2024 2023 2022
Total Full-time Total Full-time Total Full-time
employees employees employees employees employees employees
HEI1
69 69 75 75 79 79
Hawaiian Electric and its subsidiaries 2,533 2,518 2,654 2,564 2,605 2,511
ASB2
- - 977 958 1,072 1,050
2,602 2,587 3,706 3,597 3,756 3,640
1 Includes consolidated Pacific Current employees. For 2024, 2023, and 2022, HEI corporate had 44, 45, and 41 employees, respectively.
2 Beginning December 31, 2024, as a result of the sale transaction, ASB was no longer a subsidiary of HEI.
The employees of HEI and its direct and indirect subsidiaries, other than the electric utilities, are not covered by any collective bargaining agreement. The Utilities target compensation at market rates, and due to the significant increase in competitive market pay for linemen over the past few years, provided an 11.4% market rate adjustment and a 4% annual incentive for linemen effective February 1, 2024. The International Brotherhood of Electrical Workers Local 1260 represents roughly half of the Utilities’ workforce covered by a collective bargaining agreement. On January 26, 2024, a new three-year contract was ratified and will be in effect from November 1, 2024 through October 31, 2027. The contract provides for a 3% general wage increase in each year of the three-year contract, double time for callouts, and a 1% incentive payment upon achievement of specified objectives.
Culture of inclusion and belonging. The Company views fostering an inclusive culture - where all employees can thrive and feel they belong - as key to its success. The Company believes such a culture promotes collaboration, trust, engagement, excellence and innovation, in turn enhancing problem-solving and decision-making. The Company believes that a workforce comprised of a diverse array of backgrounds, experiences, skills and perspectives strengthens the Company’s ability to meet the needs of its customers, communities and stakeholders. Operating exclusively in Hawaii, one of the most culturally diverse states
in the U.S., the Company also recognizes the importance of having a workforce that understands its customer base, including Hawaii’s unique culture, history and demographics.
Employee development & training. In order to meet the changing demands of the industries in which the Company operates, address the needs of the Company’s stakeholders, attract, engage and retain talented employees, and design and carry out the Company’s strategies, it is crucial for the Company’s workforce to be highly skilled in their areas of focus and be able to adapt and evolve over time. As such, the Company invests in specific skill enhancement training as well as industry and leadership development programs.
Hawaiian Electric offers Hawaiian Electric and HEI holding company employees skills and professional training programs, including leadership development courses, employee development courses, technical training, apprenticeship programs, operational, environmental compliance, cybersecurity awareness and required safety training. Hawaiian Electric also offers tailored leadership development programs, including supervisor training to transition new supervisors to critical operational, administrative, and leadership roles as well as leadership and employee assessments geared to improve productivity and
effectiveness in the workplace. Learning and development initiatives align with individual and organizational performance, and are reinforced in the annual performance evaluation process. Ongoing leadership succession planning ensures the identification and development of successors, high potential individuals, and nurtures a leadership pipeline.
Safety and health. As a core value, the Company strives to create workplace environments that prioritize the physical and emotional well-being of its employees. For the Utility, safety is of paramount importance due to the inherent risks involved in certain aspects of its operations and the critical role the Utility plays in maintaining the electrical grid for the State of Hawaii.
Hawaiian Electric is committed to maintaining a strong safety culture. Due to the intrinsic nature of its operations, safety is part of Hawaiian Electric’s DNA. Management proactively assumes the responsibility of providing visible leadership and strategic direction for the health and safety management system and programs in their area of oversight. This leadership and direction are instrumental to building and sustaining a resilient safety culture and drive continual safety improvement. Allocating adequate resources to enable seamless implementation of safety programs and holding leaders accountable for the implementation of safety programs and resulting health and safety performance are strategic requirements. This commitment is shown in executive compensation, which is tied to the achievement of recordable incidents and lost workdays targets. These targets reward improvements in workplace safety, promote employee well-being, and contribute to long-term expense reductions. Hawaiian Electric promotes a safety culture that aims for zero incidents, with every employee taking ownership of their own safety, as well as that of their co-workers, contractors, and the public. More information on such targets is available in HEI’s annual proxy statement.
Hawaiian Electric is creating a culture of total well-being to support its employees from hire to retire and beyond by instituting best practices and advancing wellness as a business strategy. Some of the programs and benefits that foster employees’ total well-being include emotional, physical, occupational, social, spiritual, intellectual, environmental and financial. These programs include access to an extensive Employee Assistance Program for employees and their family members, participation in various community charity walks, wellness related trainings and resources, onsite mental health support, a wide variety of corporate wellness activities, gym and group fitness discounts, and financial wellness classes.
Workforce Stability. The Company’s employees are its greatest asset and the Company strives to create a highly desirable place to work.
Hawaiian Electric seeks to provide compensation and benefits that are comprehensive, market-competitive, and internally equitable to attract, engage, and retain highly skilled employees. Hawaiian Electric believes that employee engagement is key to creating a desirable, inclusive, rewarding place to work and conducts employee engagement surveys on a regular cycle. Hawaiian Electric is expanding its strategic workforce planning initiative to build its workforce to support future transformation plans.
Properties. HEI leases office space from a nonaffiliated lessor in downtown Honolulu under leases that expire in December 2027. See “Electric Utility” section for a description of properties owned and leased.
Hamakua Energy, LLC (Hamakua Energy), an indirect wholly owned subsidiary of Pacific Current, which is included in the “All Other” segment, owns a 60-MW dual-train combined-cycle facility and a total of approximately 93 acres located on the Hamakua coast on the island of Hawaii. Its power plant is situated on approximately 59 acres and the remaining 34 acres includes surrounding parcels of which 30 acres are located on the ocean front. On February 7, 2025, the parent company of Hamakua Holdings, LLC, an indirect subsidiary of HEI and parent company of Hamakua Energy, entered into a Securities Purchase Agreement to sell all of the membership interests in Hamakua Holdings, LLC to an unaffiliated third party. The sale is expected to close in March 2025. Kaʻieʻie Waho Company, LLC (Kaʻieʻie Waho), a wholly owned subsidiary of Pacific Current, owns a 6-MW solar photovoltaic facility located on approximately 20 acres on the southern coast of the island of Kauai.
Mahipapa, LLC (Mahipapa), a wholly owned subsidiary of Pacific Current, owns a 7.5- MW biomass facility located on approximately 65 acres of land and leases 3,500 acres on the island of Kauai.
Electric utility
Hawaiian Electric and subsidiaries and service areas. 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.
In 2024, the electric utilities’ revenues and net loss amounted to approximately 100% and 93% respectively, of HEI’s consolidated revenues and loss from continuing operations. The electric utilities’ revenues and net income amounted to approximately 99% and 133% in 2023 and approximately 100% and 117% in 2022, respectively, of HEI’s consolidated revenues and income from continuing operations.
The islands of Oahu, Hawaii, Maui, Lanai and Molokai have a combined population estimated at 1.4 million, or approximately 95% of the total population of the State of Hawaii, and comprise a service area of 5,815 square miles. The principal communities served include Honolulu (on Oahu), Hilo and Kona (on Hawaii) and Wailuku and Kahului (on Maui). The service areas also include numerous suburban communities, resorts, U.S. Armed Forces installations and agricultural operations. In November 2020, the PUC approved Hawaiian Electric’s acquisition of the electric distribution systems serving 12 U.S. Army installations on Oahu, including Schofield Barracks, Wheeler Army Airfield, Tripler Army Medical Center, Fort Shafter and Army housing areas.
The state has granted Hawaiian Electric, Hawaii Electric Light and Maui Electric nonexclusive franchises, which authorize the Utilities to construct, operate and maintain facilities over and under public streets and sidewalks. Each of these franchises will continue in effect for an indefinite period of time until forfeited, altered, amended or repealed.
Climate change action plan. In 2021, the Utilities set an aggressive goal to cut carbon emissions from power generation 70% by 2030, compared with 2005 levels. The emissions covered by this goal include stack emissions from generation owned by Hawaiian Electric and independent power producers (IPPs) who sell electricity to the Utilities. In addition, the Utilities have committed to achieving net zero carbon emissions from power generation by 2045 or sooner.
Key elements of the 2030 plan to reduce emissions include:
• The closing of the state’s last coal plant, which occurred in September 2022 upon expiry of the PPA
• Adding nearly 50,000 rooftop solar systems, more than a 50% increase, compared to the approximately 90,000 systems online in 2021 when the Climate Change action plan was developed
• Retiring at least six fossil-fueled generating units and significantly reducing the use of others as new renewable resources come online
• Adding additional renewable energy projects capable of generating a total of at least 1 gigawatt beyond resources in place in 2021, including shared solar (community-based renewable energy)
• Using more grid-scale and customer-owned energy storage
• Expanding geothermal resources
• Creating innovative programs that provide customers incentives for using clean, lower-cost energy at certain times of the day and using less fossil-fueled energy at night
Since the time the 2030 goal was established, delays and cancellations in the commercial operation of new renewable third-party generation resources and higher costs as a result of supply chain disruptions and inflationary pressures, as well as federal policies related to solar panel imports, have slowed the pace of progress toward reducing greenhouse gas (GHG) emissions. The downgrade of Hawaiian Electric’s credit ratings after the Maui windstorm and wildfires, which makes it more difficult for independent power producers to procure low-cost financing, has added an additional impediment to completion of new renewable energy and storage projects. As a result of these challenges, the Utilities expect the planned 70% reduction in carbon emissions to be achieved later than the original 2030 target date. However, the Utilities will continue to replace significant amounts of fossil fuel generation with renewable energy between now and 2030 and expect to meet or exceed the State of Hawaii’s RPS goals.
After 2030, progress on elimination of carbon from power generation assumes continued use of proven resources, including wind, solar, geothermal, hydroelectric, biofuels and energy storage, along with the development of new and existing technologies. Those technologies may include offshore wind, green hydrogen, wave energy and carbon-capture-all currently under development around the world-as well as other solutions that will emerge. A diverse portfolio of resources will also enhance resilience to climate-related events.
Sales of electricity.
Years ended December 31 2024 2023 2022
(dollars in thousands) Customer accounts* Electric sales revenues Customer accounts* Electric sales revenues Customer accounts* Electric sales revenues
Hawaiian Electric 310,336 $ 2,246,646 309,631 $ 2,324,044 306,978 $ 2,422,232
Hawaii Electric Light 90,522 475,556 89,477 458,157 88,757 479,566
Maui Electric 71,678 434,810 72,497 443,017 73,933 464,823
472,536 $ 3,157,012 471,605 $ 3,225,218 469,668 $ 3,366,621
* As of December 31.
Regulatory mechanisms. Base electric rates are set in rate cases, and on April 29, 2020, the PUC issued an order terminating the mandatory triennial rate case cycle in anticipation of the performance-based regulation framework (PBR Framework). The regulatory framework in effect in 2020 included a number of mechanisms designed to provide utility financial stability during the transition toward the state’s 100% renewable energy goals. For example, under the sales decoupling mechanism, the Utilities are allowed to recover from customers, target test year revenues, independent of the level of kilowatt-hour (kWh) sales. The decoupling mechanism (i.e., the Revenue Balancing Account) continues under the PBR Framework.
On December 23, 2020, the PUC issued a D&O in Phase 2 of the PBR proceeding, establishing the PBR Framework for the Utilities. The PBR Framework includes, among other matters, a five-year multi-year rate plan with an index-driven annual revenue adjustment (ARA), which replaces the RAM, modification of the MPIR mechanism (renamed Exceptional Project Recovery Mechanism (EPRM)) to include deferred and operation and maintenance (O&M) expense projects and to permit the Utilities to include the full amount of approved costs in the EPRM for recovery in the first year the project goes into service, pro-rated for the portion of the year the project is in service, and continuation of (i) the revenue balancing account, (ii) the pension and other postretirement benefit tracking mechanisms, and (iii) energy cost recovery clause, purchased power adjustment clause, and other recovery mechanisms. See “Commitments and contingencies-Regulatory proceedings-Performance-based regulation framework” in Note 4 of the Consolidated Financial Statements.
These regulatory mechanisms are summarized as follows:
Mechanism Description
Sales decoupling Provides predictable revenue stream by fixing net revenues at the level approved in last rate case (revenues not linked to kWh sales).
Annual Revenue Adjustment (ARA) Annually adjusts revenue levels during a Multi-Year Rate Period, determined by formula which includes an inflation factor, a predetermined productivity adjustment (currently set at zero), adjustments for exceptional circumstances not in the Utilities’ control and a customer dividend component. The ARA replaced the Revenue Adjustment Mechanism (RAM) effective June 1, 2021.
Exceptional Project Recovery Mechanism (EPRM) Reduces regulatory lag and permits recovery of revenues for net costs of approved eligible projects placed in service during the Multi-Year Rate Period through the revenue balancing account (RBA) that is not provided for by other effective tariffs, the ARA, Performance Incentive Mechanism (PIMS) or Shared Savings Mechanisms (SSMs). The EPRM was formerly known as the Major Project Interim Recovery (MPIR) adjustment mechanism.
Energy cost recovery clause (ECRC) and purchased power adjustment clause (PPAC) Allows for timely recovery of fuel and purchased power costs to reduce earnings volatility. Symmetrical fossil fuel cost risk-sharing (98% customer/2% utility) mechanism established for Hawaiian Electric, Hawaii Electric Light and Maui Electric capped at $2.5 million, $0.6 million and $0.6 million annually, respectively.
Performance incentive mechanism (PIM) / Shared Savings Mechanism (SSM) Annually adjusts revenue to recover from or credit customers for specific areas of the Utilities’ performance measured against the PUC’s approved targets. Adding a portfolio of SSMs and new PIMs is intended to encourage acceleration in renewables, grid services, interconnection of DERs, low-to-moderate income energy efficiency, advanced metering infrastructure, generation-based reliability (penalties only), interconnection of utility scale renewable projects, and cost control of non-ARA costs and allow for financial rewards for exemplary performance.
Pension and other post-employment benefit trackers Allows tracking of pension and other post-employment benefit costs and contributions above or below the cost included in rates in a separate regulatory asset/liability account.
Renewable energy infrastructure program Permits recovery of renewable energy infrastructure projects through a surcharge.
Pilot Process
Fosters innovation by establishing an expedited implementation process for pilots that test new technologies, programs, business models and other arrangements and allows for timely cost recovery of annual expenditures of approved pilot projects through an adjustment to target revenues. Proposed pilots are subject to PUC approval with a total annual cap of $10 million.
Earnings Sharing Mechanism (ESM) Protects the Utilities and customers from excessive earnings or losses, as measured by the Utilities’ achieved rate making ROACE; reflecting a symmetrical ESM for achieved rate making ROACE outside of a 300 basis points dead band above or below the current authorized ROACE of 9.5% for each of the Utilities.
Seasonality. kWh sales of the Utilities follow a seasonal pattern, but they do not experience extreme seasonal variations experienced by some electric utilities on the U.S. mainland. In Hawaii, kWh sales tend to increase in the warmer, more humid months as a result of increased demand for air conditioning and higher visitor arrivals. This is partially offset by the reduction of sales due to privately owned customer photovoltaic (PV) systems which generate the most energy during the aforementioned warmer months.
Significant customers. The Utilities derived approximately 11%, 12% and 12% of their operating revenues in 2024, 2023 and 2022, respectively from the sale of electricity to various federal government agencies. Hawaiian Electric continues to work with various federal agencies to implement measures that will help them achieve their energy efficiency, resilience and clean energy objectives.
Selected consolidated electric utility operating statistics.
Years ended December 31 2024 2023 2022 2021 2020
MWh sales (thousands)
Residential 2,295.4 2,342.1 2,415.2 2,491.6 2,525.4
Commercial 2,597.8 2,586.7 2,628.8 2,572.5 2,456.0
Industrial 3,301.3 3,273.5 3,295.7 3,174.3 3,118.0
Other 24.4 24.4 14.3 22.7 20.8
8,218.9 8,226.7 8,354.0 8,261.1 8,120.2
MWh net generated and purchased (thousands)
Net generated 5,251.6 5,343.0 5,011.9 4,501.0 4,629.2
Purchased 3,549.1 3,271.2 3,750.4 4,153.7 3,896.2
8,800.7 8,614.2 8,762.3 8,654.7 8,525.4
MWh customer-sited solar (thousands) 1,691.2 1,585.5 1,522.4 1,418.0 1,325.8
RPS (%)1
35.8 33.3 31.8 38.4 34.5
Losses and system uses (%) 6.4 4.2 4.4 4.3 4.5
Energy supply (December 31)
Net generating capability-MW 1,647 1,739 1,738 1,738 1,737
Firm and other purchased capability-MW2
366 362 362 540 517
2,013 2,101 2,100 2,278 2,254
Net peak demand-MW3
1,424 1,447 1,467 1,471 1,471
Btu per net kWh generated 11,074 11,102 10,941 10,988 10,834
Average fuel oil cost per MBtu (cents) 1,868.2 2,060.0 2,310.9 1,305.4 1,028.7
Customer accounts (December 31)
Residential 417,253 416,072 413,744 414,713 412,484
Commercial 53,810 54,060 54,416 54,373 54,035
Industrial 712 702 696 698 694
Other 761 771 812 828 826
472,536 471,605 469,668 470,612 468,039
Electric revenues (thousands)
Residential $ 1,011,289 $ 1,028,415 $ 1,069,974 $ 843,655 $ 770,135
Commercial 1,013,567 1,029,927 1,077,521 802,878 708,180
Industrial 1,122,152 1,156,909 1,211,242 853,293 754,775
Other 10,004 9,967 7,884 7,780 6,440
$ 3,157,012 $ 3,225,218 $ 3,366,621 $ 2,507,606 $ 2,239,530
Average revenue per kWh sold (cents) 38.41 39.21 40.30 30.35 27.58
Residential 44.06 43.91 44.30 33.86 30.50
Commercial 39.02 39.82 40.99 31.21 28.83
Industrial 33.99 35.34 36.75 26.88 24.21
Other 41.05 40.79 55.24 34.19 31.01
Residential statistics
Average annual use per customer account (kWh) 5,512 5,628 5,821 6,022 6,145
Average annual revenue per customer account $ 2,429 $ 2,471 $ 2,579 $ 2,039 $ 1,874
Average number of customer accounts 416,402 416,177 414,910 413,725 410,973
1.In July 2022, former Governor Ige signed Act 240 (H.B.2089), which 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.
2 Puna Geothermal Venture (PGV) with 34.6 MW of firm capacity went offline due to lava flow on Hawaii Island in May 2018, but returned to service in the first quarter of 2021 and is currently providing 32.2 MW. Additionally, AES Hawaii provided 180 MW of firm capacity from its coal-fired cogeneration plant. The purchase power agreement expired on September 1, 2022 and was not renewed. The AES Hawaii coal plant has ceased operations.
3 Sum of the net peak demands on all islands served, noncoincident and nonintegrated.
Generation statistics. The following table contains certain generation statistics as of and for the year ended December 31, 2024. The net generating and firm purchased capability available for operation at any given time may be more or less than shown because of capability restrictions or temporary outages for inspection, maintenance, repairs or unforeseen circumstances.
Hawaiian Electric Hawaii Electric Light Maui Electric
Island of
Oahu Island of
Hawaii Island of
Maui Island of
Lanai Island of
Molokai Total
Net generating and firm purchased capability (MW) as of December 31, 20241
Conventional oil-fired steam units 906.9 50.1 35.9 - - 992.9
Diesel internal combustion engine - 29.5 98.6 9.4 9.8 147.3
Simple-cycle combustion turbines 230.8 46.3 - - 2.2 279.3
Dual train combined-cycle unit - 56.2 113.6 - - 169.8
Biodiesel internal combustion engine 57.4 - - - - 57.4
Firm contract power2
276.5 90.0 - - - 366.5
1,471.6 272.1 248.1 9.4 12.0 2,013.2
Net peak demand (MW)3
1,050.0 183.6 178.5 5.9 5.8 1,423.8
Reserve margin 40.0 % 48.2 % 39.0 % 59.3 % 106.9 % 41.4 %
Annual load factor 71.8 % 68.9 % 65.1 % 67.9 % 62.3 % 70.6 %
MWh net generated and purchased (thousands) 6,607.5 1,108.4 1,018.1 35.1 31.6 8,800.7
1Hawaiian Electric units at normal ratings; Hawaii Electric Light and Maui Electric units at reserve ratings.
2Nonutility generators - Hawaiian Electric: 208 MW (Kalaeloa Partners, L.P., oil-fired) and 68.5 MW (HPOWER, refuse-fired); Hawaii Electric Light: 60 MW (Hamakua Energy, oil-fired) and 34.6 MW (PGV, geothermal). PGV’s current limited capability of 32.2 MW has been incorporated into the utility’s firm contract power capability as of December 31, 2024.
3Noncoincident and nonintegrated.
Generating reliability and reserve margin. Hawaiian Electric serves the island of Oahu and Hawaii Electric Light serves the island of Hawaii. Maui Electric has three separate electrical systems-one each on the islands of Maui, Molokai and Lanai. Hawaiian Electric, Hawaii Electric Light and Maui Electric have isolated electrical systems that are not currently interconnected to each other or to any other electrical grid and, thus, each maintains a higher level of reserve generation and cost structure than is typically carried by interconnected mainland U.S. utilities, which are able to share reserve capacity. These higher levels of reserve margins are required to meet peak electric demands, to provide for scheduled maintenance of generating units (including the units operated by IPPs relied upon for firm capacity) and to allow for the forced outage of the largest generating unit in the system.
Nonutility generation. The Utilities have supported state and federal energy policies which encourage the development of renewable energy sources that reduce the use of fuel oil as well as the development of qualifying facilities. The Utilities’ renewable energy sources and potential sources range from wind, solar, photovoltaic, geothermal, wave and hydroelectric power to energy produced by municipal waste and other biofuels.
The rate schedules of the electric utilities contain ECRCs and PPACs that allow them to recover costs of fuel and purchase power expenses.
In addition to the firm capacity PPAs described below, the electric utilities also purchase energy on an as-available basis directly from nonutility generators and through its Feed-In Tariff programs, as well as through renewable dispatchable generation power purchase agreements. The electric utilities also receive renewable energy from customers under its customer-sited DER programs.
The PUC has allowed rate recovery for the firm capacity and purchased energy costs for the electric utilities’ approved firm capacity and as-available energy PPAs.
Hawaiian Electric firm capacity PPAs. Hawaiian Electric currently has two major firm capacity PPAs that provide a total of 276.5 MW of firm capacity, representing 19% of Hawaiian Electric’s total net generating and firm purchased capacity on the Island of Oahu as of December 31, 2024.
Under a 1988 PPA, as amended, Hawaiian Electric is committed to purchase 208 MW of firm capacity from Kalaeloa Partners, L.P. (Kalaeloa). The Kalaeloa facility, which is a Qualifying Facility (QF), is a combined-cycle operation, consisting
of two oil-fired combustion turbines burning low sulfur fuel oil (LSFO) and a steam turbine that utilizes waste heat from the combustion turbines. The PPA term ended on May 23, 2016 and was extended while the parties were in negotiations for a new agreement. The parties executed an Amended and Restated Power Purchase Agreement (ARPPA) on October 29, 2021, which among other provisions extends the term for ten contract years after the effective date. The ARPPA was approved on November 23, 2022. The parties executed a letter agreement to establish that the rates under the ARPPA became effective on January 1, 2023.
Hawaiian Electric also entered into a PPA in March 1986 and a firm capacity amendment in April 1991 with the City and County of Honolulu with respect to a refuse-fired plant (HPOWER). Under the PPA, as amended and restated, Hawaiian Electric is committed to purchase 68.5 MW of firm capacity annually up until the PPA expires on April 2, 2033.
Hawaii Electric Light firm capacity PPAs. Hawaii Electric Light has two major firm capacity PPAs that provide a total of 85.7 MW of firm capacity, representing 33% of Hawaii Electric Light’s total net generating and firm purchased capacity on the Island of Hawaii as of December 31, 2024.
In October 1997, Hawaii Electric Light entered into an agreement with Encogen, which was succeeded by Hamakua Energy Partners, L. P. (HEP). The agreement requires Hawaii Electric Light to purchase up to 60 MW (net) of firm capacity for a period of 30 years, expiring on December 31, 2030. The dual-train combined-cycle facility consists of two oil-fired combustion turbines and a steam turbine that utilizes waste heat from the combustion turbines, which primarily burns naphtha (a mixture of liquid hydrocarbons) and, starting in late 2019, biodiesel (comprising approximately 41.8% of HEP’s fuel mix in 2024). In November 2017, Hamakua Energy, an indirect subsidiary of HEI, purchased the plant from HEP. On February 7, 2025, the parent company of Hamakua Holdings, LLC, an indirect subsidiary of HEI and parent company of Hamakua Energy, entered into a Securities Purchase Agreement to sell all the membership interests in Hamakua Holdings, LLC to an unaffiliated third party. The sale is expected to close in March 2025. See “Sale of Hamakua Holdings, LLC” in Note 3 of the Consolidated Financial Statements.
Hawaii Electric Light has a 35-year PPA, as amended, with Puna Geothermal Venture (PGV) for 34.6 MW of firm capacity from its geothermal steam facility, which will expire on December 31, 2027. However, the PGV facility went offline in May 2018 due to lava flow on Hawaii Island. In March 2019, Hawaii Electric Light entered into a Rebuild Agreement with PGV, which sets forth the parties’ respective responsibilities associated with restoration of the facility. The Rebuild Agreement shall govern the terms until PGV becomes fully operational. PGV returned to service at a level providing limited output without firm capacity in the fourth quarter of 2020 and is currently providing 32.2 MW of capacity. In December 2019, Hawaii Electric Light entered into an Amended and Restated PPA (ARPPA) with PGV to, among other things, extend the term by 25 years to 2052 and expand the firm capacity capable of being delivered to 46 MW. The ARPPA was approved by the PUC subject to certain conditions on December 29, 2023. See “New renewable PPAs” in the “Developments in renewable energy efforts” section in Hawaiian Electric’s MD&A.
Maui Electric firm capacity PPAs. Maui Electric currently has no firm capacity PPAs.
Fuel oil usage and supply. The rate schedules of the Utilities include ECRCs under which electric rates (and consequently the revenues of the electric utility subsidiaries generally) are adjusted for changes in the weighted-average price paid for fuel oil and certain components of purchased power, and the relative amounts of company-generated power and purchased power. See discussion of rates and issues relating to the ECRC below under “Rates.”
Hawaiian Electric’s steam generating units consume LSFO and Hawaiian Electric’s combustion turbine peaking units consume diesel. Hawaiian Electric’s Schofield Generating Station consumes mostly B99 grade biodiesel, but is permitted to also burn ultra-low sulfur diesel (ULSD).
Hawaii Electric Light’s and Maui Electric’s steam generating units burn high sulfur fuel oil (HSFO) and Hawaii Electric Light’s and Maui Electric’s Maui combustion turbine generating units burn diesel. Hawaii Electric Light’s and Maui Electric’s Maui, Molokai, and Lanai diesel engine generating units burn ULSD.
See “Fuel contracts” in Hawaiian Electric’s MD&A.
The following table sets forth the average cost of fuel oil used by Hawaiian Electric, Hawaii Electric Light and Maui Electric to generate electricity in 2024, 2023 and 2022:
Hawaiian Electric Hawaii Electric Light Maui Electric Consolidated
$/Barrel ¢/MBtu $/Barrel ¢/MBtu $/Barrel ¢/MBtu $/Barrel ¢/MBtu
114.42 1,839.5 117.55 1,960.3 115.93 1,945.6 115.00 1,868.2
2023 127.45 2,051.1 124.04 2,063.7 124.86 2,101.1 126.73 2,060.0
2022 144.63 2,339.5 131.36 2,183.4 135.39 2,274.5 141.49 2,310.9
The average per-unit cost of fuel oil consumed to generate electricity for Hawaiian Electric, Hawaii Electric Light and Maui Electric reflects a different volume mix of fuel types and grades as follows:
Hawaiian Electric Hawaii Electric Light Maui Electric
% LSFO % Biodiesel/Diesel % HSFO % Diesel % HSFO % Diesel
93 7 32 68 26 74
2023 92 8 35 65 22 78
2022 93 7 36 64 24 76
The prices that Hawaiian Electric and Hawaii Electric Light pay for purchased energy from certain older nonutility generators are generally linked to the price of oil. The energy prices for Kalaeloa, which purchases LSFO from Par Hawaii Refining, LLC (PAR), vary primarily with the price of Asian crude oil. On December 31, 2019, Hawaii Electric Light and PGV entered into an Amended and Restated Power Purchase Agreement, which delinks the pricing for energy delivered from the facility from fossil fuel prices. Hamakua Energy’s energy prices vary primarily with the cost of naphtha.
The Utilities estimate that 69% of the net energy they generate will come from fossil fuel oil in 2025 compared to 74% in 2024. Hawaiian Electric generally maintains an average system fuel inventory level equivalent to 47 days of forward consumption. Hawaii Electric Light and Maui Electric generally maintain an average system fuel inventory level equivalent to approximately one month’s supply of both HSFO and diesel. The PPA with Hamakua Energy requires that it maintains certain minimum fuel inventory levels.
Rates. Hawaiian Electric, Hawaii Electric Light and Maui Electric are subject to the regulatory jurisdiction of the PUC with respect to rates, issuance of securities, accounting and certain other matters. See “Regulation” below.
General rate increases require the prior approval of the PUC after public and contested case hearings. Rates for Hawaiian Electric and its subsidiaries include ECRCs, and PPACs. Under current law and practices, specific and separate PUC approval is not required for each rate change pursuant to automatic rate adjustment clauses previously approved by the PUC. Public Utility Regulatory Policies Act of 1978 (PURPA) requires the PUC to periodically review the adjustment clauses related to energy cost of electric and gas utilities in the state, and such clauses, as well as the rates charged by the utilities generally, are subject to change. PUC approval is also required for all surcharges and adjustments before they are reflected in rates.
See “Utility projects” under “Commitments and contingencies” in Note 4 of the Consolidated Financial Statements.
Competition. See “Competition” in Hawaiian Electric’s MD&A.
Regulation. The PUC regulates the rates, issuance of securities, accounting and certain other aspects of the operations of Hawaiian Electric and its electric utility subsidiaries. See the previous discussion under “Rates”.
On September 15, 2014, the State of Hawaii and the U.S. Department of Energy executed a Memorandum of Understanding (MOU) recognizing that Hawaii is embarking on the next phase of its clean energy future. The MOU provides the framework for a comprehensive, sustained effort to better realize its vast renewable energy potential and allow Hawaii to push forward in three main areas: the power sector, transportation and energy efficiency. This next phase is focused on stimulating deployment of clean energy infrastructure as a catalyst for economic growth, energy system innovation and test bed investments.
Electrification of Transportation. In June 2018, the PUC initiated a proceeding to review the Utilities’ Electrification of Transportation (EoT) Strategic Roadmap, which provided an economic analysis for light duty electric vehicles on the island of Oahu, Maui and Hawaii. The Utilities subsequently filed an update in May 2024, called the EoT Strategic Roadmap 2.0 to reflect changes to market conditions since 2018 and identifies potential utility EoT actions through 2030, through input from community and industry experts.
In October 2019, the Utilities filed their EoT Workplan, establishing a schedule to continue implementation of the EoT roadmap with a focus on EV rate design and make ready charging infrastructure in the near term. The Utilities followed through
on the EoT Workplan, with three filings: the electric bus make ready infrastructure pilot, Charge Ready Hawaii commercial infrastructure pilot, and two commercial EV rates, EV-J and EV-P. The Utilities completed the 18-month Smart Charge Hawaii Telematics pilot in December 2024.
The Utilities operate 32 public DC fast chargers (DCFC) as part of the EV-U pilot and EV-MAUI tariff. They filed a request in the fourth quarter of 2021 to expand and make permanent the public charging pilot with an additional 150 DCFCs and 150 level 2 charging stations at 75 locations. On August 20, 2024, the PUC suspended the docket effective September 6, 2024, in line with the Utilities request for suspension filed on August 13, 2024. On January 10, 2025, the Utilities learned they were not awarded federal funding as part of the Federal Joint Office and Fueling Infrastructure grant. On January 15, 2025, the Utilities filed an update to the PUC responding to their December 10, 2024 letter with a status update on changes to the priority, timing, and ability to commit funds to the application once they hear back from the Department of Energy Loan Program Office.
In August 2020, the Utilities committed to electrifying 100% of its class 1 vehicles (sedans, SUVs and light trucks) by 2035.
Renewable Portfolio Standards. In 2015, Hawaii’s RPS law was amended to require electric utilities to meet an RPS of 15%, 30%, 40%, 70% and 100% by December 31, 2015, 2020, 2030, 2040 and 2045, respectively. Energy savings resulting from energy efficiency programs do not count toward the RPS since 2014 (only electrical generation using renewable energy as a source counts). 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 would have been 39.1% under the prior method versus 31.8% under the revised method. The change in the definition is to be applied prospectively to future milestone measurements and will require that the Utilities acquire more renewable energy than under the previous RPS calculation to comply with the RPS milestones; however, the Utilities expect to continue to meet the RPS milestones under the amended RPS law to exceed the 2030 RPS requirement of 40%. The ability of the Utilities to meet RPS milestones after 2030 may be impacted by the Utilities’ current credit ratings, which may impact independent power producers’ ability to secure low-cost financing. In 2024, the Utilities’ RPS was 35.8%.
Affiliate transactions. Certain transactions between HEI’s electric public utility subsidiaries (Hawaiian Electric, Hawaii Electric Light and Maui Electric) and HEI and affiliated interests (as defined by statute) are subject to regulation by the PUC.
In December 1996, the PUC issued an order in a docket to review the relationship between HEI and Hawaiian Electric and the effects of that relationship on the operations of Hawaiian Electric. The order required Hawaiian Electric to continue to provide the PUC with periodic status reports on its compliance with the PUC Agreement (pursuant to which HEI became the holding company of Hawaiian Electric). Hawaiian Electric files such status reports annually. In the order, the PUC also required the Utilities to present a comprehensive analysis of the impact that the holding company structure and investments in nonutility subsidiaries have on a case-by-case basis on the cost of capital to each utility in future rate cases and remove any such effects from the cost of capital. The Utilities have made presentations in their subsequent rate cases to support their positions that there was no evidence that would modify the PUC’s finding that Hawaiian Electric’s access to capital did not suffer as a result of HEI’s involvement in nonutility activities and that HEI’s diversification did not permanently raise or lower the cost of capital incorporated into the rates paid by Hawaiian Electric’s utility customers.
In December 2018, the PUC established a set of requirements governing transactions and sharing of information between the Utilities and its affiliates (Affiliate Transaction Requirements, ATRs), which was subsequently modified and clarified in January 2019 following the Utilities’ motion for reconsideration. The PUC stated the intent of the ATRs is to establish safeguards to avoid potential market power benefits and cross-subsidization between regulated and unregulated activities. The requirements include rules on interactions with affiliates, information handling, business development, political activities, promotional activities, sales of products and services, and employee sharing restrictions. The ATRs include implementing an internal code of conduct, a compliance plan, including policies and procedures to comply with the requirements, and having an audit conducted every three years that examines the compliance with the requirements. Penalties for non-compliance depend on the severity of the violation, and can range from daily fines to divestiture of the Utilities by the holding company. The second external audit is anticipated to commence in the second quarter of 2025 and the selection of the external auditor is pending PUC review and approval.
Other regulations. The Utilities are not subject to regulation by the FERC under the Federal Power Act, except under Sections 210 through 212 (added by Title II of PURPA and amended by the Energy Policy Act of 1992), which permit the FERC to order electric utilities to interconnect with qualifying cogenerators and small power producers, and to wheel power to other electric utilities. Title I of PURPA, which relates to retail regulatory policies for electric utilities, and Title VII of the
Energy Policy Act of 1992, which addresses transmission access, also apply to the Utilities. The Utilities are also required to file various operational reports with the FERC.
Because they are located in the State of Hawaii, Hawaiian Electric and its subsidiaries are exempt by statute from limitations set forth in the Powerplant and Industrial Fuel Use Act of 1978 on the use of petroleum as a primary energy source.
Regulatory Developments. See “Regulatory proceedings” in Note 4 of the Consolidated Financial Statements for additional discussions.
See also “HEI Consolidated-Regulation” above.
Environmental regulation. Hawaiian Electric, Hawaii Electric Light and Maui Electric, like other utilities, are subject to periodic inspections by federal, state and, in some cases, local environmental regulatory agencies, including agencies responsible for the regulation of water quality, air quality, hazardous and other waste and hazardous materials. These inspections may result in the identification of items needing corrective or other action. Except as otherwise disclosed in this report (see “Risk Factors” in Item 1A, and Notes 1 and 4 of the Consolidated Financial Statements), the Utilities believe that each subsidiary has appropriately responded to environmental conditions requiring action and that, as a result of such actions, such environmental conditions will not have a material adverse effect on the capital expenditures, earnings and competitive position of the Utilities.
Water quality controls. The generating stations, substations and other utility facilities operate under federal and state water quality regulations and permits, including, but not limited to, the Clean Water Act National Pollution Discharge Elimination System (governing point source discharges, including wastewater and storm water discharges) and the Safe Drinking Water Act Underground Injection Control (regulating disposal of wastewater into the subsurface).
Oil pollution controls. The Oil Pollution Act of 1990 (OPA) establishes programs that govern actual or threatened oil releases and imposes strict liability on responsible parties for clean-up costs and damages to natural resources and property. The federal Environmental Protection Agency (EPA) regulations under OPA require certain facilities that use or store oil to prepare and implement Spill Prevention, Control and Countermeasures (SPCC) Plans in order to prevent releases of oil to navigable waters of the U.S. Certain facilities are also required to prepare and implement Facility Response Plans (FRPs) to ensure prompt and proper response to releases of oil. The utility facilities that are subject to SPCC Plan and FRP requirements have prepared and implemented SPCC Plans and FRPs.
Air quality controls. The Clean Air Act (CAA) establishes permitting programs to reduce air pollution. The CAA amendments of 1990, established the federal Title V Operating Permit Program (in Hawaii known as the Covered Source Permit program) to ensure compliance with all applicable federal and state air pollution control requirements. The 1977 CAA Amendments established the New Source Review (NSR) permitting program, which affect new or modified generating units by requiring a permit to construct under the CAA and the controls necessary to meet the National Ambient Air Quality Standards.
Title V operating permits have been issued for all of the Utilities’ affected generating units.
Hazardous waste and toxic substances controls. The operations of the electric utility are subject to EPA regulations that implement provisions of the Resource Conservation and Recovery Act (RCRA), the Comprehensive Environmental Response, Compensation and Liability Act (CERCLA, also known as Superfund), the Superfund Amendments and Reauthorization Act (SARA), and the Toxic Substances Control Act (TSCA) as well as equivalent State laws and regulations.
RCRA underground storage tank (UST) regulations require all facilities that use USTs for storing petroleum products to comply with established leak detection, spill prevention, standards for tank design and retrofits, financial assurance, operator training, and tank decommissioning and closure requirements. All of the Utilities’ USTs currently meet the applicable requirements.
The Emergency Planning and Community Right-to-Know Act under SARA Title III requires the Utilities to report potentially hazardous chemicals present in their facilities in order to provide the public with information so that emergency procedures can be established to protect the public in the event of hazardous chemical releases. Since January 1, 1998, the steam electric industry category has been subject to Toxics Release Inventory (TRI) reporting requirements.
The TSCA regulations specify procedures for the handling and disposal of polychlorinated biphenyls (PCBs), a compound found in some transformer and capacitor dielectric fluids. The TSCA regulations also apply to responses to releases of PCBs to the environment. The Utilities have instituted procedures to monitor compliance with these regulations and have implemented a program to identify and replace PCB transformers and capacitors in their systems.
Hawaii’s Environmental Response Law (ERL), as amended, governs releases of hazardous substances, including oil, to the environment in areas within the state’s jurisdiction. Responsible parties under the ERL may be jointly, severally, and strictly
liable for a release of a hazardous substance. Responsible parties include owners or operators of a facility where a hazardous substance is located and any person who at the time of disposal of the hazardous substance owned or operated any facility at which such hazardous substance was disposed.
The Utilities periodically discover leaking oil-containing equipment such as USTs, piping, and transformers. Each subsidiary reports releases from such equipment when and as required by applicable law and addresses the releases in compliance with applicable regulatory requirements.
State and Federal Endangered Species Act. Under the State and Federal Endangered Species Acts species that are listed as threatened or endangered are to be protected from harm. Various activities of the Utilities including vegetation management, operations, construction, and the presence of infrastructure in sensitive areas may have the potential to affect such species. The Utilities have developed best management practices, protocols and in some areas are developing habitat conservation plans and obtaining related permits to help protect these species.
Additional information. For additional information about Hawaiian Electric, see Hawaiian Electric’s MD&A, Hawaiian Electric’s “Quantitative and Qualitative Disclosures about Market Risk” and Hawaiian Electric’s Consolidated Financial Statements, including the Notes thereto.
Properties. As of December 31, 2024, the Utilities’ ownership in generating assets was as follows:
Property Location (island) Principal Fuel Type Generating Capacity (MW) Status
Hawaiian Electric:
Waiau1,2
Oahu LSFO / Diesel 388.2 Active
Kahe1
Oahu LSFO 620.5 Active
Campbell Industrial Park (CIP)1
Oahu Diesel 129.0 Active
Honolulu Power Plant1
Oahu N/A - Retired in 2023
Schofield Generating Station3
Oahu Biodiesel / ULSD 49.4 Active
West Loch PV Project4
Oahu Renewable (Solar) 20.0 Active
Hawaii Electric Light5:
Shipman Hawaii N/A - Retired in 2015
Waimea Hawaii ULSD 7.5 Active
Keahole Hawaii Diesel / ULSD 77.6 Active
Puna Hawaii HSFO / Diesel 36.7 Active
Hill/Kanoelehua Hawaii HSFO / ULSD 55.4 Active
Distributed generators at substation sites6
Hawaii ULSD 3.8 Active
Maui Electric7:
Kahului Maui HSFO 35.9 Active
Maalaea Maui Diesel / ULSD 208.4 Active
Miki Basin Lanai ULSD 9.4 Active
Palaau Molokai ULSD 12.0 Active
Distributed generators at substation sites
Maui
ULSD
3.8 Active
1 The four plants are situated on Hawaiian Electric-owned land having a combined area of 542 acres.
2 Waiau Units 3 and 4 were retired on December 31, 2024.
3 Hawaiian Electric has a 35-year land lease on 8.13 acres, effective September 1, 2016 (with an option to extend an additional 10 years), with the Department of the Army.
4 Hawaiian Electric has a 37-year land lease on 102 acres, effective July 1, 2017, with the Secretary of the Navy.
5 The plants are situated on Hawaii Electric Light-owned land having a combined area of approximately 44 acres. The distributed generators are located within Hawaii Electric Light-owned substation sites having a combined area of approximately four acres.
6 One of the four distributed generators (Panaewa D24, 1.25 MW) was damaged in a substation fire in January 2024.
7 The four plants are situated on Maui Electric-owned land having a combined area of 60.7 acres. The distributed generators are located within Maui Electric-owned substation sites having a combined area of approximately three acres.
As of December 31, 2024, the Utilities’ ownership in fuel storage facilities was as follows:
Facility Location (island) Fuel Type Capacity (barrels in thousands) Generation Serviced
Hawaiian Electric:
Barbers Point Tank Farm Oahu LSFO 1,025 Kahe, Waiau
Generation sites - various (in aggregate) Oahu LSFO 771 Various
Generation sites - various (in aggregate) Oahu Diesel 147 Various
Generation sites - various (in aggregate) Oahu Biodiesel 11 Various
Hawaii Electric Light1:
Generation sites - various (in aggregate) Hawaii HSFO 57 Various
Generation sites - various (in aggregate) Hawaii Diesel 87 Various
Maui Electric2:
Generation sites - various (in aggregate) Maui HSFO 84 Various
Generation sites - various (in aggregate) Maui Diesel 109 Various
1 There are an additional 19,249 barrels of diesel and 24,675 barrels of HSFO storage capacity for Hawaii Electric Light-owned fuel off-site at Island Energy Services, LLC-owned terminalling facilities.
2 There are an additional 56,358 barrels of diesel oil storage capacity off-site at Aloha Petroleum, Ltd-owned terminalling facilities.
Other properties. The Utilities own overhead transmission and distribution lines, underground cables, pole (some jointly) and metal high voltage towers. Electric lines are located over or under public and nonpublic properties.
Hawaiian Electric owns a total of 126.5 acres of land on which substations, transformer vaults, distribution baseyards and the Kalaeloa cogeneration facility are located. Hawaiian Electric also owns buildings and approximately 11.6 acres of land located in Honolulu, which house its operating and engineering departments. It also leases an office building and certain office spaces in Honolulu, land for office spaces and storage in Pearl City, and a warehousing center in Kapolei.
Hawaii Electric Light owns 6 acres of land in Kona, which is used for a baseyard, and one acre of land in Hilo, which houses its accounting, customer services and administrative offices. Hawaii Electric Light also leases 3.7 acres of land for its baseyard in Hilo under a lease expiring in 2030. In addition, Hawaii Electric Light owns a total of approximately 150 acres of land, and leases a total of approximately 6 acres of land, on which hydro facilities, substations and switching stations, microwave facilities and transmission lines are located. The deeds to the sites located in Hilo contain certain restrictions, but the restrictions do not materially interfere with the use of the sites for public utility purposes.
Maui Electric’s administrative offices, as well as its engineering and distribution departments, are situated on 9.1 acres of Maui Electric-owned land in Kahului. Maui Electric also owns approximately 20 acres of land which house some of its substations, leases approximately 3,600 square feet of land for its telecommunication and microwave facilities, leases approximately 6,000 square feet of land at Kahului Harbor for pipeline purposes, and leases 17,958 square feet of land at Puunene for the Puunene Substation. Maui Electric also owns approximately 87 acres of undeveloped land at Waena, Palaau, and Kahului. Fuel storage facilities are located on Maui Electric-owned properties at Kahului Baseyard, Kahului Power Plant, Maalaea Power Plant, Miki Basin, Palaau, Hana, and the Kuihelani Substation. Two, 1-MW stand-by diesel generators are located within the Maui Electric-owned land at Hana Substation. One, 1.83-MW stand-by diesel generator is located within the Maui Electric-owned land at Kuihelani Substation.
See “Hawaiian Electric and subsidiaries and service areas” above for a discussion of the nonexclusive franchises of Hawaiian Electric and subsidiaries.
See “Generation statistics” above for a further discussion of some of the electric utility properties.

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ITEM 1A. RISK FACTORS
ITEM 1A. RISK FACTORS
The businesses of HEI and its subsidiaries involve numerous risks which, if realized, could have a material and adverse effect on the Company’s financial statements. For additional information for certain risk factors enumerated below and other risks of the Company and its operations, see “Cautionary Note Regarding Forward-Looking Statements” above and HEI’s MD&A, HEI’s “Quantitative and Qualitative Disclosures about Market Risk,” the Notes to the Consolidated Financial Statements, Hawaiian Electric’s MD&A and Hawaiian Electric’s “Quantitative and Qualitative Disclosures About Market Risk.”
Holding company and company-wide risks.
Potential losses resulting from the Maui windstorm and wildfires could have a material adverse effect on HEI’s and Hawaiian Electric’s financial condition, liquidity, cash flows and results of operations. On August 8, 2023, a number of brush fires in the West Maui (Lahaina) and Upcountry Maui areas caused widespread property damage, including damage to property of the Utilities, and 102 confirmed fatalities in Lahaina (the Maui windstorm and wildfires). The Maui Department of Fire and Public Safety (MFD) and Bureau of Alcohol, Tobacco, Firearms and Explosives (ATF) reports classified the cause of the fire as “accidental.”
Multiple lawsuits have been filed against the Utilities and HEI alleging, among other things, that they were negligent in failing to prevent the wildfires that led to the property destruction and loss of life. The amount of any liability arising from the Maui windstorm and wildfires (which could exceed amounts currently reserved for the settlement liability), whether determined at trial or through a negotiated settlement, could have a material adverse impact on HEI’s and Hawaiian Electric’s financial condition, liquidity, cash flows and results of operations. As of December 31, 2024, HEI and the Utilities have approximately $13 million, nil and $122 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 and recognized as a receivable as of year-end.
HEI’s and Hawaiian Electric’s access to capital markets and other sources of debt and equity financings in a timely manner and on acceptable terms will continue to be negatively impacted as a result of the downgrades in their debt credit ratings to below investment grade. In August 2023, HEI and Hawaiian Electric received multiple downgrades to their debt, including to ratings below investment grade, by Fitch, Moody’s and S&P. As of February 14, 2025, the Fitch, Moody’s and S&P ratings of HEI and Hawaiian Electric were as follows:
Fitch Moody’s S&P
HEI:
Long-term issuer default, long-term corporate family and issuer credit, respectively
B B1
B-
Short-term issuer default, commercial paper and commercial paper, respectively B NP B
Outlook Stable
Stable
Negative
Hawaiian Electric:
Long-term issuer default, long-term and issuer credit, respectively B Ba3
B-
Short-term issuer default, commercial paper and commercial paper, respectively
B NP B
Senior unsecured debt/special purpose revenue bonds B+ Ba3 *
Cumulative preferred stock (selected series) * B3 *
Outlook Stable
Stable
Negative
* Not rated.
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.
Unless and until these debt ratings are upgraded to investment grade, the Company will continue to have restricted access to capital markets and other sources of debt and equity financings, if at all, in a timely manner and on acceptable terms. Recent projects, such as, wildfire mitigation plan, grid modernization, reliability and resilience all require significant capital expenditures to implement. The Company may not be able to obtain the necessary financing to achieve its business objectives as a result of the downgrades. Accordingly, the Company’s financial condition, liquidity, cash flows and results of operations may be adversely impacted if debt credit ratings are maintained at below investment grade for an extended period of time.
HEI’s and Hawaiian Electric’s credit ratings only reflect the view, at the time the ratings are issued, of the applicable rating agency. There is no assurance that any such credit rating will remain in effect for any given period of time or that such rating will not be lowered, suspended or withdrawn entirely by the applicable rating agency if, in such rating agency’s judgment, circumstances, such as current, past or future effects or events so warrant. Any such lowering, suspension or withdrawal of any rating may have an adverse effect on the availability of capital to the Company or the market price or marketability of HEI’s and/or Hawaiian Electric’s securities, which could increase the cost of capital of HEI and Hawaiian Electric, and such increased costs, including interest charges, under HEI’s and/or Hawaiian Electric’s debt securities and credit facilities, would result in reductions in HEI’s consolidated net income in future periods. Because HEI’s and Hawaiian Electric’s credit ratings were downgraded, HEI and Hawaiian Electric are unable to sell commercial paper and were required to draw on more expensive
bank lines of credit and prioritize capital and other expenditures. Neither HEI nor Hawaiian Electric management can predict the duration of the downgrades and future rating agency actions or their effects on the future cost of capital of HEI or Hawaiian Electric. 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.
Extreme weather events and other natural disasters, particularly those exacerbated by climate change such as the Maui windstorm and wildfires, could materially affect Hawaiian Electric’s assets and infrastructure, particularly if such infrastructure is damaged or is found to have contributed to other catastrophic events such as a wildfire. Extreme weather-related incidents and other natural disasters, including volcanic eruptions, mudslides, hurricanes, tsunamis and other storms, can interfere with the generation and transmission of electricity, and can seriously damage the infrastructure necessary to deliver electricity to customers. Damage to Hawaiian Electric’s infrastructure can also cause or contribute to additional loss through events such as wildfires. These risks are increasing, as climate change has exacerbated some of the conditions that lead to these extreme weather events and natural disasters. Such an event can result in lost revenue and increased expenses for the Utilities, but it also can result in regulatory penalties and disallowances if Hawaiian Electric is unable to restore power on a timely basis. Also, an extreme event can lead to significant claims for damages, including for loss of life and property, and has been the case with the Maui windstorm and wildfires. Therefore, these events could have a material adverse effect on the Company’s business, reputation, financial condition and results of operations.
Holding Company Risk-HEI is a holding company that derives its income from its principal operating subsidiary, Hawaiian Electric, and depends on the ability of Hawaiian Electric to pay dividends or make other distributions to HEI and on its own ability to raise capital. HEI is a legal entity separate and distinct from its subsidiaries. As a holding company with no significant operations of its own, HEI’s cash flows and consequent ability to service its obligations and pay dividends on its common stock is dependent upon its receipt of dividends or other distributions from Hawaiian Electric and its ability to issue common stock or other equity securities and to incur additional debt. A material reduction or delay in dividends or other distributions by Hawaiian Electric for an extended period of time, such as a continuation or expansion of the reduction in dividends that HEI currently is experiencing due to the Maui windstorm and wildfires, could have a material adverse effect on the Company’s business, financial condition and results of operations. The ability of HEI’s subsidiaries to pay dividends or make other distributions to HEI, in turn, is subject to the risks associated with their operations and to contractual and regulatory restrictions, including:
•the provisions of an HEI agreement with the PUC (PUC Agreement), which could limit the ability of HEI’s principal electric public utility subsidiary, Hawaiian Electric, to pay dividends to HEI in the event that the consolidated common stock equity of the Utilities falls below 35% of total capitalization of the electric utilities. As of December 31, 2024, the consolidated common stock equity of HEI’s electric utility subsidiaries was 33% of their total capitalization based on the current definition under the PUC Agreement and, as a result, the Utilities are restricted in cash payment of their dividend to HEI at this time (see Note 15 of the Consolidated Financial Statements.);
•the provisions of preferred stock resolutions and debt instruments of HEI and its subsidiaries.
Credit and Capital Market Risk-The Company, and its lowered credit rating, is subject to risks associated with the Hawaii economy, including catastrophic events such as the Maui windstorm and wildfire (in the aggregate and on an individual island basis), volatile U.S. capital markets and changes in the interest rate and credit market environment that have or could result in higher retirement benefit plan funding requirements and restrictions on the ability of HEI or its subsidiaries to borrow money or issue securities. The two largest components of Hawaii’s economy are tourism and the federal government (including the military). Because the core businesses of HEI’s subsidiaries are providing local public electric utility services (through Hawaiian Electric and its subsidiaries), the Company’s operating results are significantly influenced by: Hawaii’s economy, which in turn is influenced by economic conditions in the mainland U.S. (particularly California) and Asia (particularly Japan) as a result of the impact of those conditions on tourism; by the impact of interest rates on the construction and real estate industries and by the impact of federal government spending in Hawaii, which can be affected by world conditions; and, from time to time, the expiration of federal government appropriations bills. In addition, the Hawaii economy could be directly or indirectly affected by implications and potential impacts of U.S. and foreign capital and credit market conditions and federal, state and international responses to those conditions and the potential impacts of global and local developments (including economic conditions and uncertainties; unrest, terrorist acts, wars (such as the Russia-Ukraine war and the Israel-Hamas war), conflicts, political protests, deadly virus epidemic, pandemics, or other crisis; the effects of changes that have or may occur in U.S. policy, such as with respect to immigration and trade).
Changes in the U.S. capital markets can also have significant effects on the Company. For example, pension funding requirements are affected by the market performance of the assets in the master pension trust maintained for pension plans, and by the discount rate used to estimate the service and interest cost components of net periodic pension cost and value obligations. The Utilities’ pension tracking mechanisms help moderate pension expense; however, a significant reduction in the discount rate or in the value of the Company’s defined benefit pension plan assets could result in a substantial increase in the gap between the projected benefit obligations under the plans and the value of plan assets, resulting in increases in funding requirements.
HEI and the Utilities are also exposed to interest rate risk primarily due to their periodic borrowing requirements, the discount rate used to determine pension funding requirements and the possible effect of interest rates on the electric utilities’ rates of return. Interest rates are sensitive to many factors, including general economic conditions and the policies of government and regulatory authorities. HEI cannot predict future changes in interest rates, nor be certain that interest rate risk management strategies it or its subsidiaries have implemented will be successful in managing interest rate risk.
There may be future conditions or events that raise substantial doubt about our ability to continue as a going concern, and it is possible that any plan developed to alleviate such doubt may be unsuccessful. In addition, any capital raised may result in dilution to our current shareholders. For the year ended December 31, 2024, the Company incurred losses from continuing operations of approximately $1.32 billion. For the year ended December 31, 2024, the Utilities incurred net losses of approximately $1.23 billion. The net losses for the year ended December 31, 2024, were primarily due to the accruals of estimated wildfire liabilities in the second and third quarters of 2024, totaling approximately $1.92 billion related to the Maui windstorm and wildfire tort-related legal claims. The Company previously disclosed in its Quarterly Report on Form 10-Q for the quarter ending June 30, 2024, that based on its financial and liquidity condition, and because it had not yet implemented a capital financing plan to address proposed wildfire settlement payments, there was substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern.
Management believes the Company’s cash and cash equivalents amount of $751 million and GLST1’s restricted cash amount of $479 million, both as of December 31, 2024, the available capacity on Hawaiian Electric’s asset-based lending facility (ABL Facility) (see Note 6 of the Consolidated Financial Statements included herein), additional liquidity under HEI’s recently registered ATM program as well as expenditure reduction efforts effectively alleviate any conditions that may cause substantial doubt regarding HEI’s and Utilities’ ability to continue as a going concern. 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 earlier than the fourth quarter of 2025 and its other cash obligations for the next 12 months following the issuance of its financial statements. The plans that have been implemented have mitigated the conditions that previously caused the substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern as of the date of filing their 2024 second quarter financial statements. 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.
The recurrence of any substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern may affect the price of our common stock, may impact our relationship with third parties with whom we do business, including our vendors, lenders and employees, may impact our ability to raise additional capital or refinance existing debt and may impact our ability to comply, going forward, with certain covenants in our debt agreements and/or satisfy conditions to draw thereunder, which could significantly and materially restrict our operations.
If a court-approved definitive settlement agreement to resolve Maui windstorm and wildfire tort-related legal claims is not obtained, or if financing for settlement payments is not available, we may need to consider other alternatives for addressing the outstanding legal claims or settlement payments, and such alternatives could adversely affect our financial results or other factors impacting our finances, operations or stock valuation. As described more fully in Note 2 of the Consolidated Financial Statements included herein, the Company entered into Settlement Agreements effective November 1, 2024, to resolve all Maui windstorm and wildfire tort-related legal claims, including all claims among the defendants. Such Settlement Agreements are subject to court approval, and other conditions including resolution of the claims of the insurance companies that have paid claims for property loss and other damages. If all conditions of the Settlement Agreements are satisfied, the Company has agreed to make substantial payments to settle all Maui windstorm and wildfire tort-related legal claims. As described more fully in Note 2 of the Consolidated Financial Statements included herein, if the conditions of the Settlement Agreements are not satisfied or the agreements are otherwise terminated, the Company intends to vigorously defend against the litigation. There is no assurance that the Company will be successful in the defense of the litigation or that insurance proceeds will be available to fund any potential settlements, judgments, or costs associated with the litigation.
If all conditions of the Settlement Agreements are satisfied, the Company expects to finance the settlement payments through a mix of debt, common equity, equity-linked securities or other potential options. While management believes the Company will be able to raise the capital necessary to finance the settlement payments, there is no assurance that future financing will be available in sufficient amounts, on a timely basis or on reasonable terms acceptable to us, if at all.
If the Company’s financing plans are unsuccessful, we may need to consider other strategic alternatives, including delaying strategic initiatives, selling assets, or other strategic measures including, without limitation, obtaining relief under the U.S.
Bankruptcy Code. Such alternatives could adversely affect our financial results or other factors impacting our finances, operations or stock valuation.
You may experience future dilution as a result of future equity offerings. In order to raise additional capital, including capital necessary to fund litigation settlement expenses, the Company may in the future offer additional shares of HEI’s Common Stock or other securities convertible into or exchangeable for HEI Common Stock at prices that may not be the same as the current market price per share, and investors purchasing shares or other securities in the future could have rights superior to existing stockholders. The price per share at which the Company may sell additional shares of HEI Common Stock, or securities convertible or exchangeable into HEI Common Stock, in future transactions may be higher or lower than the current market price per share of HEI Common Stock.
In addition, any future sales of a substantial number of shares of HEI Common Stock in the public market, or the perception that such sales may occur, could adversely affect the price of HEI Common Stock. We cannot predict the effect, if any, that market sales of those shares of Common Stock, or the perception that those shares may be sold, will have on the market price of HEI Common Stock. Further, we may not have the ability to raise the amount of capital necessary on reasonable terms, or at all, to fund our contribution to the Maui wildfire tort litigation settlement, and uncertainties about the Company’s access to capital could have a material adverse effect on the market price of HEI Common Stock.
The Company does not expect to pay any dividends in the foreseeable future. The Company does not currently intend to pay dividends on HEI Common Stock and currently intends to retain future earnings, if any, to fund the development and growth of the Company’s business. In addition, the terms of certain existing and any future debt agreements may preclude the Company from paying dividends. As a result, capital appreciation, if any, of HEI Common Stock may be your sole source of gain for the foreseeable future.
Tax Legislation Risk-Adverse tax rulings or developments or changes in tax legislation could result in significant increases in tax payments and/or expense. Governmental taxing authorities could challenge a tax return position taken by HEI or its subsidiaries and if the taxing authorities prevail, HEI’s consolidated tax payments and/or expense, including applicable penalties and interest, could increase significantly. Additionally, changes in tax legislation or IRS interpretations could increase the Company’s tax burden and adversely affect the Company’s financial position, results of operations, and cash flows.
Geographic Concentration Risk-The Company is subject to the risks associated with the geographic concentration of its businesses and current lack of interconnections that could result in service interruptions at the Utilities. The business of the Utilities is concentrated on the individual islands they serve in the State of Hawaii. Their operations are more vulnerable to service interruptions than that of many U.S. mainland utilities because none of the systems of the Utilities are interconnected with the systems on the other islands they serve. Because of this lack of interconnections, it is necessary to maintain higher generation reserve margins than are typical for U.S. mainland utilities to help ensure reliable service. Service interruptions, including, in particular, extended interruptions that could result from a natural disaster or terrorist activity, could adversely impact the revenues and costs of some or all of the Utilities.
Competitive and Technological Risk-Increasing competition and technological advances could cause HEI’s businesses to lose customers or render their operations obsolete. Certain aspects of the electric utility industry are competitive. The success of HEI’s subsidiaries in meeting competition and responding to technological advances will continue to have a direct impact on HEI’s consolidated financial performance. For example:
•The Utilities face competition from IPPs; customer self-generation, with or without cogeneration; customer energy storage; and the potential formation of community-based, cooperative ownership or municipality structures for electrical service on all islands it serves. With the exception of certain identified projects, the Utilities are required to use competitive bidding to acquire a future generation resource unless the PUC finds competitive bidding to be unsuitable. The PUC sets policies for distributed generation interconnection agreements and standby rates. The results of competitive bidding, competition from IPPs, customer self-generation, and potential cooperative ownership or municipality structures for electric utility service, and the rate at which technological developments facilitating nonutility generation of electricity, combined heat and power technology, off-grid microgrids, and customer energy storage may render the operations of the Utilities less competitive or outdated and adversely affect the Utilities and the results of their operations.
Cybersecurity Risk-The Company is subject to information technology and operational system failures, network disruptions, cyber attacks and breaches in data security that could materially and adversely affect its businesses and reputation. The Company and its subsidiaries rely on information technology systems, some of which are managed or hosted by third party service providers, to manage its business data, communications, and other business processes. Such information technology systems are vulnerable to cyberattacks or other security incidents, which could result in unauthorized access to confidential data, ransomware demands or disruptions to operations. In addition, there is increasing cybersecurity risk associated with the broad adoption of a remote working environment. If the Company is unable to prevent or adequately
respond to and resolve an incident, it may have a material impact on the Company’s business, financial condition, results of operations and reputation.
Utilities. The Utilities rely on evolving and complex operational and information systems, networks and other technologies, which are interconnected with the systems and network infrastructure owned by third parties to support a variety of business processes and activities, including procurement and supply chain, invoicing and collection of payments, customer relationship management, human resource management, the acquisition, generation and delivery of electrical service to customers, and to process financial information and results of operations for internal reporting purposes and to comply with regulatory financial reporting and legal and tax requirements. The Utilities use their systems and infrastructure to create, collect, store, and process sensitive information, including personal information regarding customers, employees and their dependents, retirees, and other individuals. Their systems are vulnerable to disability, failures or unauthorized access caused by natural disasters, cybersecurity incidents, security breaches, user error, unintentional defects created by system changes, military or terrorist actions, nation-state threat actors, criminal organizations, power or communication failures or similar events. Any such failure could have a material adverse impact on the Utilities’ ability to process transactions and provide service, as well the Utilities’ financial condition and results of operations. Further, a data breach involving theft, improper disclosure, or other unauthorized access to or acquisition of confidential information could subject the Utilities to penalties for violation of applicable privacy laws, claims by third parties, and enforcement actions by government agencies. A data breach could also reduce the value of proprietary information, and harm the reputation of the Utilities.
Private and public entities, such as the North American Electric Reliability Corporation, and the U.S. federal government, including the Departments of Defense, Homeland Security and Energy, and the White House, have noted that cyberattacks targeting utility systems are increasing in sophistication, magnitude, and frequency. The Utilities’ systems have been, and will likely continue to be, a target of attacks. Further, the Utilities’ operational networks may be subject to unforeseen operational/cybersecurity risks due to the reliance on legacy operational components or modernizing and interconnecting existing infrastructure with new technologies and control systems, including those owned by third parties, such as independent power producers, distributed energy resource aggregators and customers. Although the Utilities have not experienced a material cybersecurity breach to date, such incidents may occur and may have a material adverse effect on the Utilities and the Company in the future. The Utilities continue to make investments in their cybersecurity program, including personnel, technologies, cyber insurance and training of Utilities personnel; however, there can be no assurance that these systems or their expected functionality will be implemented, maintained, or expanded effectively; nor can security measures completely eliminate the possibility of a cybersecurity breach. The Utilities maintain cyber liability insurance that covers certain damages caused by cyber incidents. However, there is no guarantee that adequate insurance will continue to be available at rates the Utilities believe are reasonable or that the costs of responding to and recovering from a cyber incident will be covered by insurance or recoverable in rates. If the Utilities’ operational technologies or networks were to malfunction or fail or cybersecurity measures were to be breached, the Utilities could suffer financial loss, business disruptions, liability to customers, regulatory intervention or damage to their reputations.
Due to the size, scope and complexity of the Utilities’ business, the development and maintenance of information technology systems to process and track information is critical and challenging. The Utilities often rely on third-party vendors to host, maintain, modify, and update its systems and these third-party vendors could cease to exist, fail to establish adequate processes to protect the Utilities systems and information, experience supply chain compromises or other internal or external security incidents. In addition, the Utilities are pursuing complex business transformation initiatives, which include the implementation of new systems and the upgrade or replacement of existing systems. Significant system changes increase the risk of system interruptions, which may occur. Further, delay or failure to complete the integration of information systems and processes may result in delays in regulatory cost recovery, or the failure to realize the benefits anticipated to be derived from these initiatives.
The Utilities’ disaster recovery plans may not be successful in preventing the loss of customer data, service interruptions and disruptions to operations or damage to important facilities. If any of these systems fail to operate properly or become disabled and the Utilities’ disaster recovery plans do not effectively resolve the issues in a timely manner, the Utilities could suffer financial loss, business disruptions, liability to customers, regulatory intervention or damage to their reputations, any of which could have a material adverse effect on the Utilities’ and the Company’s financial condition and results of operations.
Uninsured Losses-HEI’s businesses could suffer losses that are uninsured due to a lack of affordable insurance coverage, unavailability of insurance coverage or limitations on the insurance coverage the Company does have. In the ordinary course of business, HEI and its subsidiaries purchase insurance coverages (e.g., property and liability coverages) to protect against loss of, or damage to, their properties and against claims made by third parties and employees for property damage or personal injuries. However, the protection provided by such insurance is limited in significant respects and, in some instances, there is no coverage. Some of the insurance coverages have substantial deductibles or have limits on the maximum amounts that may be recovered. In common with other companies in its line of business, the Utilities’ overhead and underground transmission and distribution systems (with the exception of substation buildings and contents), which have a replacement value roughly
estimated at $13 billion, are largely not insured against loss or damage because the amount of transmission and distribution system insurance capacity is limited and the premiums are cost prohibitive. Similarly, the Utilities have no business interruption insurance as the premiums for such insurance would be cost prohibitive, particularly since the Utilities are not interconnected to other systems. If a hurricane or other uninsured catastrophic natural disaster were to occur, and if the PUC did not allow the affected Utilities to recover from ratepayers restoration costs and revenues lost from business interruption, the lost revenues and repair expenses could result in a significant decrease in HEI’s consolidated net income or in significant net losses for the affected periods.
Related to damages and costs incurred as a result of the Maui windstorm and wildfires, the Company has property insurance with a total policy limit of $500 million, subject to a $1 million retention, for wildfire damages related to Utility-owned non-generating assets, including overhead transmission and distribution assets within 1,000 feet of such assets. The Company also has $165 million of excess liability insurance and $25 million of miscellaneous professional liability insurance for third party claims, including claims related to wildfires, with a retention of $0.3 million and $0.1 million, respectively, and $145 million directors and officers liability insurance to cover claims related to shareholder and derivative lawsuits, with a retention of $1.0 million. The aggregate damages and costs associated with the Maui windstorm and wildfires could significantly exceed the Company’s policy limits.
Environmental Regulation-Increased federal and state environmental regulation will require an increasing commitment of resources and funds and could result in construction delays or penalties and fines for non-compliance. HEI and its subsidiaries are subject to federal, state and local environmental laws and regulations relating to air quality, water quality, hazardous substances, waste management, natural resources and health and safety, which regulate, among other matters, the operation of existing facilities, the construction and operation of new facilities and the proper cleanup and disposal of hazardous and toxic wastes and substances. These laws and regulations could result in increased capital, operating, and other costs. HEI or its subsidiaries are currently involved in investigatory or remedial actions at current, former or third-party sites and there is no assurance that the Company will not incur material costs relating to these sites. In addition, compliance with these legal requirements requires the Utilities to commit significant resources and funds toward, among other things, environmental monitoring, installation of pollution control equipment and payment of emission fees. These laws and regulations, among other things, require that certain environmental permits be obtained in order to construct or operate certain facilities, and obtaining such permits can entail significant expense and cause substantial construction delays. Also, these laws and regulations may be amended from time to time, including amendments that increase the burden and cost of compliance. For example, emission and/or discharge limits may be tightened, more extensive permitting requirements may be imposed and additional substances may become regulated. In addition, significant regulatory uncertainty exists regarding the impact of federal or state greenhouse gas emission limits and reductions.
If HEI or its subsidiaries fail to comply with environmental laws and regulations, even if caused by factors beyond their control, that failure may result in civil or criminal penalties and fines or the cessation of operations that could have a material adverse on the Company’s financial condition or results of operations.
Electric utility risks.
The following risks are generally specific to Hawaiian Electric, but could have a material adverse effect on the Company’s consolidated results of operations, financial condition and liquidity.
Regulatory Risk-Actions of the PUC are outside the control of the Utilities and could result in inadequate or untimely rate increases, rate reductions or refunds or unanticipated delays, expenses or writedowns in connection with the construction of new projects. The rates the Utilities are allowed to charge for their services and the timeliness of permitted rate increases are among the most important items influencing the Utilities’ results of operations, financial condition and liquidity. The PUC has broad discretion over the rates that the Utilities charge their customers. On December 23, 2020, as part of the D&O establishing the PBR Framework, the PUC established a five-year Multi-year Rate Period (MRP) during which there will be no general rate cases. In the fourth year of the MRP, the PUC will comprehensively review the PBR Framework to determine if any modifications or revisions are appropriate. The PUC is currently evaluating the Utilities’ proposal to rebase the rates in the form of a tri-company rate case with a 2026 test year.
Any adverse decision by the PUC concerning the level or method of determining electric utility rates at the end of the MRP, including the items and amounts that may be included in rate base, the returns on equity or rate base found to be reasonable, the potential consequences of exceeding or not meeting such returns, the denial of exceptional project recovery applications during the MRP, adverse impact of adjustments made to the PBR Framework, decisions on recovery of exogenous items under the PBR Framework, or any prolonged delay in rendering a decision in a rate or other proceeding could have a material adverse effect on Hawaiian Electric’s consolidated results of operations, financial condition and liquidity.
To improve the timing and certainty of the recovery of their costs, the Utilities have proposed and/or received approval of various cost recovery mechanisms, including an ECRC (includes a PUC-ordered 98%/2% risk-sharing split between customers and the Utilities for fossil fuel price variations from baseline prices, with a current annual aggregate exposure cap of +/- $3.7 million), a PPAC, and pension and OPEB tracking mechanisms, as well as a decoupling mechanism, an exceptional project recovery mechanism (EPRM) (formerly Major Project Interim Recovery (MPIR) adjustment mechanism), and a Renewable Energy Infrastructure Program surcharge. A change in, or the elimination of, any of these cost recovery mechanisms, could have a material adverse effect on the Utilities. See “Regulatory mechanisms” in Electric Utility’s Business.
Under the PBR Framework, the Utilities’ annual revenue adjustment (ARA) includes a customer dividend consisting of a negative adjustment of 0.22% compounded annually and a flow through of the “pre-PBR” savings commitment from the management audit recommendations developed in the 2020 test year rate case. The ability of the Utilities to recover increasing costs and earn a reasonable return on capital investments not covered by the ARA or not achieving the customer dividend and cost savings commitment could have a material adverse effect on the Utilities. Under the PBR Framework, the existing PIMs continue, and the PUC established new PIMs and is working on additional PIMs with stakeholders. The assessment of penalties for not achieving performance goals or the failure to achieve PIMs rewards could affect the Utilities’ ability to achieve their allowed ROACEs and have a material adverse effect on the Utilities.
Related to the Maui windstorm and wildfires, the Utilities obtained PUC approval to defer certain non-labor expenses incurred from August 8, 2023 through December 31, 2025 that are not already a part of base rates. If the PUC denies recovery of any deferred costs, such costs would be charged to expense in the period that those costs are no longer considered probable of recovery. Additionally, on August 31, 2023, the PUC issued an order temporarily suspending the ESM until further notice. The intent of the order is to address the unintended consequence of customers potentially bearing the costs associated with the Maui windstorm and wildfires through the operation of the ESM without prior PUC review. See “Performance-based regulation framework” and “Regulatory assets for Maui windstorm and wildfires related costs” in Note 4 of the Consolidated Financial Statements.
Based on the current operations of the Utilities and regulatory framework, including the impact of the approved PBR Framework, the Utilities continue to follow regulatory accounting under Accounting Standards Codification (ASC) 980. Continued accounting in this manner requires that certain criteria relating to the recoverability of such costs through rates be met, including achieved financial results that support the recovery of costs. If events or circumstances should change, such that the criteria are no longer satisfied, the Utilities expect that their regulatory assets (amounting to $227 million as of December 31, 2024), net of regulatory liabilities (amounting to $1,218 million as of December 31, 2024), would be charged to the statement of income in the period of discontinuance. See “Performance-based regulation framework” in Note 4 of the Consolidated Financial Statements.
The Utilities could be required to refund to their customers, with interest, revenues that have been or may be received under interim rate orders in their rate case proceedings and other proceedings, if and to the extent they exceed the amounts allowed in final orders.
Many public utility projects require PUC approval and various permits (e.g., environmental and land use permits) from other governmental agencies. Difficulties in obtaining, or the inability to obtain, the necessary approvals or permits, or any adverse decision or policy made or adopted, or any prolonged delay in rendering a decision, by an agency with respect to such approvals and permits, can result in significantly increased project costs or even cancellation of projects. In the event a project does not proceed, or if the PUC disallows cost recovery for all or part of a project, or if project costs exceed caps imposed by the PUC in its approval of the project, project costs may need to be written off in amounts that could result in significant reductions in Hawaiian Electric’s consolidated net income. In addition, as the Utilities may retire fossil fuel generating units before the full recovery of its investment, if the PUC disallows cost recovery of the undepreciated cost, the write-offs of such amounts could have an adverse impact on the Utilities’ results of operations.
Weather Conditions Risk-Electric utility operations are significantly influenced by weather conditions and natural disasters. The Utilities’ results of operations can be affected by the weather and natural disasters. Weather conditions, particularly temperature and humidity, directly impact the demand for electricity. Additionally, severe weather and natural disasters may become more intense and/or frequent because of global climate changes. Recent natural disasters such as the Kilauea eruption in 2018, Mauna Loa eruption in 2022, and the Maui windstorm and wildfires in 2023, have disrupted electric utility operations. These types of events can cause outages, property damage and result in significant additional expenses that may not always be recoverable.
Climate Change Risk-Electric utility operations may be significantly influenced by climate change. While the timing, extent and ultimate effects of climate change cannot be determined with any certainty, climate change is predicted to cause sea level rise, which could impact coastal and low-lying areas where much of the Utilities’ electric infrastructure is located. Potential consequences include erosion of beaches, saltwater intrusion into aquifers and surface ecosystems, higher water tables
and increased flooding and storm damage due to heavy rainfall. Climate change may also intensify extreme weather conditions including floods, hurricanes, heat waves and drought which could increase wildfire risk. These factors along with changes in sea levels, water availability and water quality have the potential to materially and adversely affect the Utilities’ results of operations, financial condition, and liquidity. For example, severe weather and its related impacts could cause significant harm to the Utilities’ physical facilities.
Third Party Performance Risk-Electric utility operations depend heavily on third-party suppliers of fuel and purchased power. The Utilities rely on fuel suppliers and shippers, and IPPs to deliver fuel and power, respectively, in accordance with contractual agreements. Approximately 75% of the net energy generated or purchased by the Utilities in 2024 was generated from the burning of fossil fuel oil, and purchases of power by the Utilities provided about 40% of their total net energy generated and purchased for the same period. Failure or delay by fuel suppliers and shippers to provide fuel pursuant to existing contracts, or failure by a major IPP to deliver the firm capacity anticipated in its PPA, could disrupt the ability of the Utilities to deliver electricity, affect the Utilities’ maintenance schedules that could affect future reliability and require the Utilities to incur additional expenses to meet the needs of their customers that may not be recoverable. In addition, as the IPP contracts near the end of their terms, there may be less economic incentive for the IPPs to make investments in their units to ensure the availability of their units. Also, as these contractual agreements end, the Utilities may not be able to purchase fuel and power on terms equivalent to the current contractual agreements.
Capacity Risk-The capacity provided by the Utilities’ generating resources and third-party purchased power may not be sufficient to meet customers’ energy requirements. The Utilities rely upon their generating resources and purchased power from third parties to meet their customers’ energy requirements. The Utilities update their generation capacity evaluation each year to determine the Utilities’ ability to meet reasonably expected demands for service and provide reasonable reserves for emergencies and other unplanned events. These evaluations are impacted by a variety of factors, including customer energy demand, energy conservation and efficiency initiatives, economic conditions, and weather patterns. If the capacity provided by the Utilities’ generating resources and third-party purchased power is not adequate relative to customer demand, the Utilities may have to contract to buy more power from third parties, invest in additional generating facilities over the long-term, or extend the operating life of existing utility units. Any failure to meet customer energy requirements could negatively impact the satisfaction of the Utilities’ customers, which could have an adverse impact on the Utilities’ business, reputation and results of operations.
The Energy Reserve Margin, the planning criteria used to determine generation adequacy, is the percentage which the system generation capacity must exceed the system load in each hour. The Utilities’ Energy Reserve Margin is satisfied from 2025 through 2029 with the addition of planned generation and storage resource additions for all islands except for Hawaii Island and Lanai, which forecasts are near or slightly below target levels by less than one percent for 2025. The Utilities have plans to address these issues through managing maintenance schedules of existing generations, and if necessary, may request for voluntary customer conservation during periods of high power demands. The environment for resource planning has increased in complexity and uncertainty and the Utilities will continue using a portfolio approach to meet its obligation to serve. This includes increased renewable energy, energy storage, and other potential options, both supply side and customer programs. If the Utilities are unable to meet customer energy requirements, it could negatively impact the satisfaction of the Utilities’ customers, which could have an adverse impact on the Utilities’ business, reputation and results of operations.
Stakeholder Activism Risk-Electric utility and third-party purchased power projects may be significantly impacted by stakeholder activism. The potential impact of stakeholder activism could increase total utility project costs, and delay the permitting, construction and overall timing or preclude the completion of third-party or utility projects that are required to meet electricity demand, resilience and reliability objectives, and RPS and other climate related goals. If a utility project cannot be completed, the project costs may need to be written off in amounts that could result in significant reductions in Hawaiian Electric’s consolidated net income and negatively impact its financial condition and liquidity.
Operational Risk-Electric utility generating facilities are subject to operational risks that could result in unscheduled plant outages, unanticipated and/or increased operation and maintenance expenses, increased power purchase costs, and decreased reliability. Operation of electric generating facilities involves certain risks which can adversely affect energy output, efficiency levels, and reliability. Included among these risks are facility shutdowns or power interruptions due to insufficient generation or a breakdown or failure of equipment or processes. In addition, operations could be negatively impacted by interruptions in fuel supply, inability to negotiate satisfactory collective bargaining agreements when existing agreements expire or other labor disputes, inability to comply with regulatory or permit requirements, disruptions in delivery of electricity, operator error, adverse weather or environmental conditions and catastrophic events such as earthquakes, tsunamis, hurricanes, fires, explosions, lava flows, floods or other similar occurrences affecting the Utilities’ generating facilities or transmission and distribution systems.
Legislative Risk-The Utilities may be adversely affected by new legislation, executive orders or administrative actions. The Utilities operations are subject to regulations under a wide variety of federal and state regulations and policies. Changes to
federal and state laws, rules, regulations and policies are continuous and ongoing and the federal administration, the U.S. Congress, state legislatures and state administrations may enact and implement new laws, regulations and policies that could adversely and materially affect us. The new federal administration has indicated its intent to implement material changes to the federal government’s structure and operations and to advocate material changes to federal laws, regulations and policies. The Utilities cannot predict future changes in laws,regulations and policies, how they will be implemented and interpreted, or the ultimate effect that this changing environment will have on us. There can be no assurance that laws, regulations and policies will not be changed in ways that have a material adverse effect on the Utilities’ operations, financial condition, results of operations, and cash flows. The federal and state executive branches, Congress, the Hawaii legislature and governmental agencies have adopted, or are considering adopting, a number of measures that will significantly affect the Utilities, as described below.
Renewable Portfolio Standards law. The 2001 Hawaii Legislature adopted a law requiring the Utilities to meet a renewable portfolio standard, which has been amended over the years. The most recent amendment to Hawaii’s RPS law occurred in July 2022, which 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. The change in the definition is to be applied prospectively to future milestone measurements and will require that the Utilities acquire more renewable energy than under the previous RPS calculation to comply with the RPS milestones. The Utilities are committed to achieving these goals and met the 2015 and 2020 RPS; however, due to the exclusion of energy savings in calculating RPS after 2014 and risks such as potential delays in IPPs being able to deliver contracted renewable energy, it is possible the Utilities may not attain the required renewable percentages in the future, and management cannot predict the future consequences of failure to do so (including potential penalties to be assessed by the PUC). On December 19, 2008, the PUC approved a penalty of $20 for every megawatt-hour (MWh) that an electric utility is deficient under Hawaii’s RPS law. The PUC noted, however, that this penalty may be reduced, in the PUC’s discretion, 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, as described in the RPS law and in an RPS framework adopted by the PUC. In addition, the PUC ordered that the Utilities will be prohibited from recovering any RPS penalty costs through rates.
Renewable energy. In 2007, a measure was passed by the Hawaii legislature stating that the PUC may consider the need for increased renewable energy in rendering decisions on utility matters. Due to this measure, it is possible that, if energy from a renewable source is more expensive than energy from fossil fuel, the PUC may still approve the purchase of energy from the renewable source, resulting in higher costs.
Executive orders. In January 2025, President Trump issued multiple Executive Orders (EOs) that impact both IIJA and IRA funding. EO 14154 entitled Unleashing American Energy ordered to immediately pause disbursement of funds appropriated through IIJA and IRA grants, which is causing delays in processing the Utilities’ requests for reimbursement for the Resilience Program and may potentially lead to project delays and economic uncertainty. The EO entitled Ending Radical and Wasteful Government DEI Programs and Preferencing resulted in the federal contracting officer ordering recipients to cease all diversity, equity and inclusion and community benefits plan activities funded by federal grants as of January 28, 2025, which could potentially impact the Utilities’ existing community benefits agreements with some third parties and commitments included in the Resilience Program project costs. The Utilities are unable to predict the timing or amount of the funding the Utilities may receive as a result of the two EOs mentioned above.
Global climate change and greenhouse gas emissions reduction. National and international concern about climate change and the contribution of greenhouse gas (GHG) emissions (including carbon dioxide emissions from the combustion of fossil fuels) to climate change have led to federal legislative and regulatory proposals and action by the state of Hawaii to reduce GHG emissions.
Hawaii Revised Statutes (HRS) § 269-6(b) requires that “in making determinations of the reasonableness of the costs pertaining to electric or gas utility system capital improvements and operations, the PUC shall explicitly consider, quantitatively or qualitatively, the effect of the state’s reliance on fossil fuels on price volatility, export of funds for fuel imports, fuel supply reliability risk, and greenhouse gas emissions.” Based on HRS § 269-6(b) and recent case law discussing the scope of this section, the Utilities are performing GHG analyses to quantitatively or qualitatively describe the GHG emissions of proposed projects that are submitted to the PUC for approval. On June 20, 2024, House Bill 2390 was signed into law as Act 54 and took effect on July 1, 2024. Act 54 authorizes the PUC to waive a lifecycle GHG analysis for energy projects that do not involve combustion. On September 18, 2024, the PUC approved the Utilities’ waiver requests for the Stage 3 solar plus storage and wind projects.
In June 2018, House Bill 2182 was signed into law as Act 15 and took effect on July 1, 2018. Among its provisions, Act 15 aligned the state’s clean energy and carbon sequestration efforts with climate initiative goals and established a statewide carbon
neutral goal by 2045. Under this Act, efforts would be made to “sequester more atmospheric carbon and greenhouse gases than emitted within the state as quickly as practicable, but no later than 2045.” The Hawaii Climate Change Mitigation and Adaptation Commission, administratively placed under the State Department of Land and Natural Resources, was charged with endeavoring to achieve the target, and giving consideration to the impact of its plans, decisions and strategies on the state’s ability to attain the goal. The general functions, duties and powers of the Hawaii Climate Change Mitigation and Adaptation Commission are set forth in HRS § 225P-3. To achieve its mandates, the Hawaii Climate Change Mitigation and Adaptation Commission may recommend plans, decisions and strategies that could have an impact on various entities including the Utilities. In July 2022, House Bill 1800 was signed into law as Act 238 and took effect on July 1, 2022. The Act established a goal for the statewide greenhouse gas emissions limit to be at least 50% below 2005 levels by 2030.
The Utilities have taken, and continue to identify opportunities to take, direct action to reduce GHG emissions from their operations, including, but not limited to, supporting demand-side management programs that foster energy efficiency, using renewable resources for energy production and purchasing power from IPPs generated by renewable resources, and burning renewable biodiesel at selected Hawaiian Electric and Maui Electric generating units. In November 2021, the Utilities committed to a 70% reduction in power generation GHG emissions by 2030 compared to a 2005 baseline and achievement of net zero carbon emissions from power generation by 2045. While the reduction is not mandated by law, the Utilities could suffer reputational harm if it fails to achieve its commitments, which may negatively impact its business. Since the time the 2030 goal was established, delays and cancellations in the commercial operation of new renewable third-party generation resources and higher costs as a result of supply chain disruptions and inflationary pressures, as well as federal policies related to solar panel imports, have slowed the pace of progress toward reducing GHG emissions. The downgrade of Hawaiian Electric’s credit ratings after the Maui windstorm and wildfires is anticipated to be an additional impediment to completion of new renewable energy and storage projects. As a result of these challenges, the Utilities expect the planned 70% reduction in carbon emissions to be achieved later than the original 2030 target date. However, the Utilities will continue to replace significant amounts of fossil fuel generation with renewable energy between now and 2030 and expect to meet or exceed the State of Hawaii’s RPS goals.
The foregoing legislation or legislation that now is, or may in the future be, proposed, such as potential carbon “cap and trade” legislation that, if applicable, may fundamentally alter costs to produce electricity and accelerate the move to renewable generation, present risks and uncertainties for the Utilities.
Renewable Transition Risk-The Utilities may be subject to increased operational challenges and their results of operations, financial condition and liquidity may be adversely impacted in meeting the commitments and objectives of clean energy initiatives, Renewable Portfolio Standards (RPS) and other climate related goals. The far-reaching nature of the Utilities’ renewable energy commitments and the RPS and other climate related goals present risks to the Company. Among such risks are: (1) the potential delay by the Public Utilities Commission of the State of Hawaii (PUC) in considering (and potential disapproval of actual or proposed) renewable energy proposals and related costs; (2) the dependence on outside parties, such as the state, developers and third-party suppliers of renewable purchased energy, which if the Utilities are unsuccessful in negotiating purchased power agreements with such IPPs or if a major IPP delays or fails to deliver the anticipated capacity and/or energy in its purchased power agreement, could impact the Utilities’ achievement of their commitments to RPS and other climate related goals, eligibility for performance incentive mechanisms associated with the speed of increasing renewable generation, the ability to retire fossil fuel units, and/or the Utilities’ ability to deliver reliable service; (3) delays in acquiring or unavailability of non-fossil fuel supplies for renewable generation; (4) the impact of intermittent power to the electrical grid and reliability of service if appropriate supporting infrastructure is not installed or does not operate effectively; (5) the inability to recover the undepreciated cost of fossil fuel generating units if they are required to be retired before the end of their expected useful life; (6) uncertainties surrounding current and future renewable technologies, such as solar power, wind power, biofuels, battery storage, hydro, hydrogen, as well as related environmental assessments required to meet RPS and other climate related goals; (7) the impacts of implementation of the renewable energy proposals on future costs of electricity and potential penalties imposed by the PUC for delays in the commercial operations of renewable energy projects; (8) the likelihood that the Utilities may need to make substantial investments in related infrastructure, which could result in increased borrowings and, therefore, materially impact the financial condition and liquidity of the Utilities; (9) the imputed debt related to the pending renewable power purchase agreements under the stage 1, stage 2, stage 3 and other RFPs could result in a credit rating downgrade for the Utilities and the Company; and (10) the commitment to support a variety of initiatives, which, if approved by the PUC, may have a material impact on the results of operations and financial condition of the Utilities depending on their design and implementation. These initiatives include, but are not limited to, programs to enable more customer-sited generation. The implementation of these or other programs may adversely impact the results of operations, financial condition and liquidity of the Utilities.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
ITEM 1B. UNRESOLVED STAFF COMMENTS
HEI: None.
Hawaiian Electric: Not applicable.

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ITEM 2. PROPERTIES
ITEM 2. PROPERTIES
HEI and Hawaiian Electric: See the “Properties” sections under “HEI” and “Electric utility” in Item 1. Business above.

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ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
HEI and Hawaiian Electric: HEI and Hawaiian Electric (including their direct and indirect subsidiaries) may be involved in ordinary routine PUC proceedings, environmental proceedings and/or litigation incidental to their respective businesses. See the descriptions of legal proceedings (including judicial proceedings and proceedings before the PUC and environmental and other administrative agencies) in “Item 1. Business,” in HEI’s MD&A and in the Notes 2 and 4 of the Consolidated Financial Statements. The outcomes of litigation and administrative proceedings are necessarily uncertain and there is a risk that the outcome of such matters could have a material adverse effect on the financial position, results of operations or liquidity of HEI or one or more of its subsidiaries for a particular period in the future.

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ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURE
HEI and Hawaiian Electric: Not applicable.
INFORMATION ABOUT OUR EXECUTIVE OFFICERS (HEI)
The executive officers of HEI are listed below. Ms. Kimura is an officer of an HEI subsidiary rather than of HEI, but is deemed to be an executive officer of HEI under SEC Rule 3b-7 promulgated under the 1934 Exchange Act. HEI executive officers serve from the date of their initial appointment and are reappointed annually by the HEI Board (or annually by the applicable HEI subsidiary board), and thereafter are appointed for one-year terms or until their successors have been duly appointed and qualified or until their earlier resignation or removal. HEI executive officers may also hold offices with HEI subsidiaries and affiliates in addition to their current positions listed below.
Name Age Business experience for last 5 years and prior positions with the Company
Scott W. H. Seu 59 HEI President and Chief Executive Officer since 1/22
HEI Director since 1/22
ASB Director 1/22 to 12/24, Chair 1/22 to 8/23
ASB Hawaii Director since 1/22
· Hawaiian Electric President and Chief Executive Officer, 2/20 to 12/21
· Hawaiian Electric Director, 2/20 to 12/21
· Hawaiian Electric Senior Vice President, Public Affairs, 1/17 to 2/20
· Hawaiian Electric Vice President, System Operation, 5/14 to 12/16
· Hawaiian Electric Vice President, Energy Resources and Operations, 1/13 to 4/14
· Hawaiian Electric Vice President, Energy Resources, 8/10 to 12/12
· Hawaiian Electric Manager, Resource Acquisition Department, 3/09 to 8/10
· Hawaiian Electric Manager, Energy Projects Department, 5/04 to 3/09
· Hawaiian Electric Manager, Customer Installations Department, 1/03 to 5/04
· Hawaiian Electric Manager, Environmental Department, 4/98 to 12/02
· Hawaiian Electric Principal Environmental Scientist, 1/97 to 4/98
· Hawaiian Electric Senior Environmental Scientist, 5/96 to 12/96
· Hawaiian Electric Environmental Scientist, 8/93 to 5/96
Scott T. DeGhetto
61 HEI Executive Vice President, Chief Financial Officer and Treasurer, since 10/23
· Prior to joining the Company in October 2023: Moelis & Company, Managing Director, Power, Utilities & Renewable Energy, 2011-2023.
Kurt K. Murao 55 HEI Executive Vice President, General Counsel, Chief Administrative Officer and Corporate Secretary since 1/20
· HEI Vice President - Legal & Administration and Corporate Secretary, 10/16 to 12/19
· HEI Associate General Counsel, 3/11 to 10/16
Shelee M. T. Kimura 51 Hawaiian Electric President and Chief Executive Officer since 1/22
· Hawaiian Electric Senior Vice President, Customer Service and Public Affairs, 3/21 to 12/21
· Hawaiian Electric Senior Vice President, Customer Service, 2/19 to 3/21
· Hawaiian Electric Senior Vice President, Business Development & Strategic Planning, 1/17 to 2/19
· Hawaiian Electric Vice President, Corporate Planning & Business Development, 5/14 to 1/17
· HEI Director, Investor Relations, Strategic Planning & Budget, 11/09 to 5/14
· HEI Manager, Corporate Finance and Investments, 8/04 to 11/09
Family relationships; executive arrangements
There are no family relationships between any HEI executive officer and any other HEI executive officer or any HEI director or director nominee. There are no arrangements or understandings between any HEI executive officer and any other person pursuant to which such executive officer was selected.
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER PURCHASES OF EQUITY SECURITIES
HEI:
Certain of the information required by this item is disclosed in Note 15, “Regulatory restrictions on net assets” and “Equity compensation plan information” under “Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters” of this Form 10-K.
HEI’s common stock is traded on the New York Stock Exchange under the ticker symbol “HE.” As of February 14, 2025, HEI had 4,587 registered shareholders (i.e., holders of record of HEI common stock), 16,267 DRIP participants and total record shareholders of 20,854. The HEI Board of Directors evaluates the dividend quarterly and considers many factors in the evaluation including, but not limited to, the Company’s results of operations, the long-term prospects for the Company, and the current and expected future economic conditions. 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 of 2023 dividend. This action is intended to allow the Company to maximize liquidity and allocate cash to rebuilding and restoring power and help ensure a strong future for the Utility and Bank (prior to its sale on December 31, 2024).
Purchases of HEI common shares were made during the fourth quarter to satisfy the requirements of certain plans as follows:
ISSUER PURCHASES OF EQUITY SECURITIES
Period* Total Number
of Shares Purchased **
Average
Price Paid
per Share ** Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
October 1 to 31, 2024
37,236 $ 9.70 - NA
November 1 to 30, 2024
28,641 10.22 - NA
December 1 to 31, 2024
24,228 10.20 - NA
Total 90,105 - NA
NA Not applicable.
* Trades (total number of shares purchased) are reflected in the month in which the order is placed.
** The purchases were made to satisfy the requirements of the HEI Dividend Reinvestment and Stock Purchase Plan (DRIP), the Hawaiian Electric Industries Retirement Savings Plan (HEIRSP), and the ASB 401(k) Plan, prior to the sale of ASB, for shares purchased for cash or, if applicable, by the reinvestment of dividends by participants under those plans and none of the purchases were made under publicly announced repurchase plans or programs. Average prices per share are calculated exclusive of any commissions payable to the brokers making the purchases for the DRIP, the HEIRSP and the ASB 401(k) Plan, prior to the sale of ASB. Of the “Total number of shares purchased,” 31,970 of the 90,105 shares were purchased for the DRIP; 47,096 of the 90,105 shares were purchased for the HEIRSP; and the remaining of the 11,039 shares were purchased for the ASB 401(k) Plan, prior to the sale of ASB. The repurchased shares were issued for the accounts of the participants under registration statements registering the shares issued under these plans.
Hawaiian Electric:
Since a corporate restructuring on July 1, 1983, all the common stock of Hawaiian Electric has been held solely by its parent, HEI, and is not publicly traded. Accordingly, information required with respect to “Market information” and “holders” is not applicable to Hawaiian Electric.
The dividends declared and paid on Hawaiian Electric’s common stock for the quarters of 2024 and 2023 were as follows:
Quarters ended 2024 2023
(in thousands)
March 31 $ 13,000 $ 32,250
June 30 13,000 32,250
September 30 - 32,250
December 31 - 32,250
Total $ 26,000 $ 129,000
Also, see “Liquidity and capital resources” in HEI’s MD&A.
See the discussion of regulatory and other restrictions on dividends or other distributions in Note 15 of the Consolidated Financial Statements.

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ITEM 6. SELECTED FINANCIAL DATA
ITEM 6. [RESERVED]
HEI and Hawaiian Electric: Not applicable.

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
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 will be used to primarily strengthen the Company’s balance sheet and promote long-term financial stability which may include partially paying down its long-term debt, funding the wildfire settlement amount, and/or for other corporate purposes. 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. However, subsequent to the Maui windstorm and wildfires, HEI and Pacific Current have suspended any new investments while undertaking a comprehensive review of strategic options for certain assets of Pacific Current.
While a major focus of HEI’s financial strategy is to grow core earnings/profitability at the Utilities and Pacific Current in a controlled risk manner and optimize operating, capital and tax efficiencies in order to support its dividend and deliver shareholder value, HEI is working on strategic financing plans to raise capital necessary to fund the settlement of wildfire tort claims.
Recent developments. On August 8, 2023, a number of brush fires in the West Maui (Lahaina) and Upcountry Maui areas caused widespread property damage, including damage to property of the Utilities, and 102 confirmed fatalities in Lahaina (the Maui windstorm and wildfires). The Maui windstorm and wildfires were fueled by extreme winds and drought-like conditions in those parts of Maui.
As of February 14, 2025, HEI and the Utilities have each been named in approximately 783 lawsuits related to the Maui windstorm and wildfires. These civil and putative class action lawsuits are pending in the Maui Circuit Court against HEI, the Utilities, and other defendants, including the County of Maui, the State of Hawaii and related state entities, private landowners and developers, and telecommunications companies (collectively, tort-related legal claims). One putative class action is also pending in federal court. Most of these lawsuits allege that the defendants were responsible for, and/or negligent in failing to prevent or respond to, the wildfires that led to the property destruction and loss of life. Other claims include, among other things, personal injury, wrongful death, emotional distress and inverse condemnation. One lawsuit asserting similar theories and claims was filed by the County of Maui against HEI and the Utilities, one lawsuit was filed by Spectrum Oceanic, LLC against HEI and the Utilities and other defendants, and other lawsuits were filed by approximately 160 subrogation insurers against HEI, the Utilities, a private landowner, and telecommunications companies. Additional lawsuits may be filed against the Company and other defendants in the future. The plaintiffs seek to recover damages and other costs, including punitive damages. Defendants have asserted cross-claims against one another for indemnification, contribution, and subrogation.
Effective November 1, 2024, HEI and Hawaiian Electric entered into two definitive settlement agreements (collectively, the Settlement Agreements) to settle the tort-related legal claims in the litigation arising out of the Maui windstorm and wildfires (expressly excluding securities and derivative actions) on a global basis without any admission of liability. Under the Settlement Agreements, subject to certain conditions (including those described below), HEI and Hawaiian Electric, along with other defendants (the State of Hawaii, the County of Maui, Kamehameha Schools, entities affiliated with the West Maui Land
Co., Hawaiian Telcom, and Spectrum/Charter Communications) have agreed to settle the claims of those who filed lawsuits in state and federal courts, or who may have claims but have not yet filed lawsuits, in connection with the Maui windstorm and wildfires. One Settlement Agreement is between the defendants, class counsel, and class plaintiffs (the Class Settlement Agreement), and the other is between the defendants and over 30 lawyers representing numerous individual plaintiffs who have brought their own lawsuits (the Individual Settlement Agreement). The 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 (described below) is a condition that must be satisfied before any payment is due from the defendants. Both Settlement Agreements remain subject to court approval and other conditions, including those set out below.
Under the Settlement Agreements, HEI and Hawaiian Electric are obligated to contribute a total of $1.99 billion (out of a total defendant contribution of approximately $4.04 billion), which includes $75 million previously contributed for the One ‘Ohana Initiative (a humanitarian aid fund to provide payments outside of litigation to the beneficiaries of those who died, as well as compensation for personal injury damages). The total settlement amount is to be divided between two settlement funds, one for the benefit of individual plaintiffs, and the other for the benefit of the class plaintiffs. HEI and Hawaiian Electric must pay such amounts in four equal annual installments of approximately $479 million, with the first installment expected to be made no earlier than the fourth quarter of 2025. HEI and Hawaiian Electric have the option to accelerate the payments, in whole or in part, with such accelerated payments to be discounted at a rate of 5.5% per annum. HEI transferred the amount of the first payment, $479 million, into a new subsidiary, which is restricted from disbursing such funds except in connection with the initial payment to the settlement funds. Additionally, under the Settlement Agreements, HEI and Hawaiian Electric are obligated to contribute a share to the settlement administration fees only if certain other sources are exhausted when those fees are due, for which $3.5 million was accrued as of December 31, 2024 based on the best estimate at that time.
The Settlement Agreements are intended to resolve all of the tort-related legal claims related to the Maui windstorm and wildfires. The Class Settlement Agreement provides releases by plaintiffs to the defendants, and among defendants, for acts and omissions relating to the Maui windstorm and wildfires. The Individual Settlement Agreement provides that individual plaintiffs who elect to accept the settlement will sign releases. The releases in the Settlement Agreements, including those among defendants (subject to certain conditions), are effective on the initial payment due date. The Settlement Agreements also provide that $500 million of the total settlement payments will be reserved and made available to defendants to defray the cost to resolve any claims brought by plaintiffs who do not release claims as part of the settlements. Defendants have the right to terminate the Settlement Agreements under certain circumstances, including if more than specified thresholds of plaintiffs choose not to participate in the settlement.
The Settlement Agreements contain multiple conditions that must be met before any payment from HEI and Hawaiian Electric to the settlement funds are due. Those conditions include, among others, resolving claims of the insurers (either through agreement or a final court order stating that the insurers cannot maintain independent lawsuits against the defendants), legislation appropriating money from the state, and court approval of the Settlement Agreements.
The Settlement Agreements do not resolve claims with insurers who have asserted subrogation claims in separate lawsuits, and such insurers are not parties to the Settlement Agreements. However, the Settlement Agreements provide that all subrogation claims by insurers that have been or could be brought against defendants arising out of the Maui windstorm and wildfires must be resolved in order for HEI and Hawaiian Electric’s payment obligation to arise. The Settlement Agreements include a condition to the defendants’ obligations providing that by May 19, 2025, either (a) insurers that have brought claims arising out of the Maui windstorm and wildfires enter into a written agreement that provides for releases of all claims against the defendants, or (b) that there is a final and unappealable court order providing that if the final definitive agreement between the plaintiffs and the defendants becomes effective, then those same insurers’ exclusive remedy for any claims against the defendants would be limited to asserting liens against the settlement amounts obtained by the individual plaintiffs. On February 6, 2025, after briefing was complete, the Supreme Court of Hawaii heard argument on three reserved questions regarding the scope of Hawaii subrogation law concerning the condition described in this paragraph in the manner described in (b) above. On February 10, 2025, the Hawaii Supreme Court issued an order regarding the reserved questions providing that, once the settlement becomes final, the exclusive remedy for insurers seeking to recover amounts paid to settling plaintiffs is to assert liens against their policyholders pursuant to HRS 663-10. The Hawaii Supreme Court is expected to issue a written opinion providing further detail on its decision in the coming weeks.
The Company intends to vigorously defend itself in the litigation if a definitive settlement is ultimately not achieved. There is no assurance that the Company will be successful in the defense of the litigation or that insurance will be available or adequate to fund any potential settlements, judgments, or costs associated with the litigation. If additional liabilities were to be incurred, the loss could be material to the Company’s results of operations, financial position and cash flows and could result in violations of the financial covenants in the Company’s debt agreements. If any such losses were to be sufficiently high, the
Company may not have liquidity or the ability to access liquidity at levels necessary to satisfy such losses. However, any possible loss in excess of the amount recorded cannot reasonably be estimated at this time.
The foregoing descriptions of the Settlement Agreements do not purport to be complete and are qualified in their entirety by reference to the full text of the Settlement Agreements attached as exhibits to the Form 8-K that was filed with the SEC on November 5, 2024.
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 HEI’s and the Utilities’ Consolidated Balance Sheets. The Settlement Agreements contain no admission of any liability by HEI or the Utilities and reflect the collective efforts of the State, HEI and the Utilities, and other defendants to seek a comprehensive resolution of the litigation arising out of the Maui windstorm and wildfires. The Utilities have recorded an additional $40 million in “Accounts receivable and unbilled revenues, net” and “Other accounts receivable, net” on HEI’s and the Utilities’ Consolidated Balance Sheets, respectively, as of December 31, 2024, based on the amounts expected to be remaining under the applicate insurance policies at time of settlement payment.
In an effort to finance the first settlement payment, 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. In addition, on September 19, 2024, HEI filed with the SEC an at-the-market (ATM) 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. HEI is working with its financial advisors on additional financing plans to raise capital necessary to fund the remaining $1.44 billion settlement amount.
The Company is also named in securities class action and shareholder lawsuits related to the Maui windstorm and wildfires. An unsuccessful mediation was held on January 22, 2025. There is no assurance that the Company will be successful in the defense of the litigation or that insurance will be available or adequate to fund any potential settlement or judgment or the litigation costs of the action. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
On April 16, 2024, the County of Maui Department of Fire and Public Safety (MFD) released its After-Action Report (AAR) on the Maui windstorm and wildfires, the purpose of which was to enable future enhancements to mitigate the impact of future similar major events. The AAR identified 17 issues that the MFD faced during the Maui windstorm and wildfires or needs to address and provided 111 recommendations to consider for addressing these challenges. The issues and recommendations focus on the MFD. Some of the key areas for improvement include addressing the lack of apparatus, personnel and fire stations and the need for mutual aid and communication programs. The AAR did not address the cause or origin of the fires.
On April 17, 2024, the Hawaii Attorney General released the first of three reports regarding its investigation into the Maui windstorm and wildfires (the first AG report). The first AG report chronologically details the major events and response efforts related to the Maui windstorm and wildfires, with a focus on the events concerning the Lahaina area between 2:55 p.m. on August 8, 2023, and 8:30 a.m. on August 9, 2023. It did not address the cause or origin of the fires.
On September 13, 2024, the Hawaii Attorney General released the second of three reports, concerning the timeline and facts of the Maui windstorm and wildfires (the second AG report). The second AG report focused on the events that occurred prior to, during, and immediately following the fire in Lahaina in the afternoon of August 8, 2023, including preparedness efforts, weather and its impact to infrastructure, and other fires occurring on Maui. It did not address the cause or origin of the fires.
On October 2, 2024, the MFD released its Origin and Cause Report on the fires in Lahaina on August 8, 2023, incorporating the investigative report by the Bureau of Alcohol, Tobacco, Firearms and Explosives (ATF). The MFD/ATF reports conclude that the afternoon Lahaina fire on August 8, 2023 was a rekindle of the morning fire, and that the morning fire was caused by a damaged Maui Electric powerline that emitted sparks that ignited overgrown vegetation. The MFD/ATF reports classified the cause of the fire as “accidental.”
On January 14, 2025, the Hawaii Attorney General released the third of three reports, which, according to a press release issued the same day by the Attorney General, “organizes the findings from the first AG report and the second AG report and prioritizes a list of action items the state and all counties can use to make improvements to Hawaii’s future preparation for and response to wildfires, including recommendations on how to address each priority.”
In 2024, Governor Josh Green announced the creation of a Hawaii Climate Advisory Team (CAT), which the Governor’s office stated in a news release would “recommend steps to create a durable fund to mitigate the impacts of dynamic climate change and to develop a fair and comprehensive structure to resolve claims related to future disasters” including “develop[ing] a customized go-forward fund structure and related claims settlement mechanics.”
In January 2025, the CAT released a report titled “Policy Recommendations on Climate Disaster Resilience, Recovery and Funding.” The report recommends the creation of a $500 million disaster recovery fund, which would provide funding to certain low-income individuals for wildfires, hurricanes, floods, or other natural disasters that meet an aggregate damages threshold. Separately, the report notes that the CAT is “supportive of efforts to establish a separate disaster mitigation fund that would provide benefits to Hawaii residents,” with participation by utilities.
See “Recent developments” in Hawaiian Electric’s MD&A for additional updates.
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 is 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 a changing climate, which is 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 also focused on ensuring that sustainability considerations are appropriately integrated into governance structures, strategies and risk management. This includes:
•integration of Board oversight of important sustainability matters into its existing governance structures and processes across companies. 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, climate change policy and strategy, and risk and environmental management.
•sustainability goals as part of HEI and Utility executive incentive compensation.
•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 objectives and contribute to 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 climate change, 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-wide GHG emissions inventory, providing the basis to further guide the Company's strategies and enable greater transparency around its progress on
climate issues. 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) 2024 % change 2023 % change 2022
Revenues $ 3,220 (2) $ 3,288 (4) $ 3,421
Operating income (loss)
(1,707) NM 275 (2) 280
Income (loss) from continuing operations for common stock $ (1,323) NM $ 146 (9) $ 161
Income (loss) from discontinued operations1
(103) NM 53 (33) 80
Net income (loss) for common stock
$ (1,426) NM $ 199 (17) $ 241
Net income (loss) by segment:
Electric utility $ (1,226) NM $ 194 3 $ 189
Other (96) (100) (48) (73) (28)
Income (loss) from continuing operations for common stock $ (1,323) NM $ 146 (9) $ 161
Continuing operations - Basic earnings (loss) per common share
$ (10.42) NM $ 1.33 (10) $ 1.47
Discontinued operations - Basic earnings (loss) per common share1
(0.81) NM 0.49 (33) 0.73
Basic earnings (loss) per share
$ (11.23) NM $ 1.82 (17) $ 2.20
Continuing operations - Diluted earnings (loss) per common share $ (10.42) NM $ 1.33 (10) $ 1.47
Discontinued operations - Diluted earnings (loss) per common share1
(0.81) NM 0.48 (34) 0.73
Diluted earnings (loss) per share
$ (11.23) NM $ 1.81 (18) $ 2.20
Dividends per share $ - (100) $ 1.08 (23) $ 1.40
Weighted-average number of common shares outstanding (millions) 126.9 16 109.7 - 109.4
Dividend payout ratio - % 59 % 60 %
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: Total may not foot due to rounding.
In 2024, net 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. In 2023, income from continuing operations decreased 9% to $146 million ($1.33 diluted earnings per share), compared to $161 million ($1.47 diluted earnings per share) in 2022, due to $20 million higher net loss at the “All Other” segment, partly offset by $5 million higher net income at the Utilities. The decrease in the “All Other” segment’s 2023 net income compared to 2022 was primarily due to Maui windstorm and wildfires related costs and higher operating expenses at Pacific Current. The increase in the Utilities’ 2023 net income compared to 2022 was principally due to higher ARA revenues, which included the customer dividend delivered to customers, partially offset by higher operating expenses. 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 at 26% tax benefit in 2024, compared to 19% tax expense in 2023, primarily due to the substantial pretax loss resulting from the accrual of the loss contingencies related to the Maui windstorm and wildfires tort-related claims and the impact of permanent items on the effective tax rates including federal research and development tax credit claims in 2024, partially offset by an increase in excess taxes related to vesting of share-based awards and lower amortization in 2024 of the Utilities’ regulatory liability related to certain excess deferred income taxes resulting from the Tax Act’s decrease in the federal income tax rate.
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, 2024 and 2023 were as follows:
Year ended December 31, 2024
(in thousands) Electric utility All Other segment
HEI Consolidated4
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 claims1
1,915,000 - 1,915,000
Other expense2
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 PUC3
(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 Consolidated4
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 PUC3
(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 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.
2 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.
3 Related to the PUC’s order, received on December 27, 2023, approving deferred accounting treatment for the Utilities’ incremental non-labor expenses related to the August 2023 Maui windstorm and wildfires. Amounts were reclassified to a regulatory asset. See “Risk Factors” in Item 1A. for further discussion of regulatory risks. See Note 2 of the Consolidated Financial Statements.
4 Excludes expenses related to discontinued operations amounting to $1.3 million and $11.3 million for the years ended December 31, 2024 and 2023, respectively.
Note: All Other segment Maui windstorm and wildfires related expenses - legal, outside services and other 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, 2024, HEI and its subsidiaries have incurred approximately $2.2 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 and the One ‘Ohana Initiative contribution. Certain of these costs are reimbursable under excess liability insurance, professional liability and directors and officers liability insurance policies. As of December 31, 2024, HEI and its subsidiaries have approximately $13 million, nil and $122 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 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, 2024, the Company expects the Electric utility and HEI to use the remaining $13 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, the average daily passenger count was 4.2% higher 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 18.9% below 2019 pre-COVID-19 levels. Due to the weak yen, Japanese visitors are 41.8% below 2019 pre-COVID-19 levels.
Hawaii’s seasonally adjusted unemployment rate in December 2024 was 3.0%, consistent with the rate observed in December 2023. The national unemployment rate in December 2024 was 4.1% compared to 3.8% in December 2023. According to the most recent forecast by UHERO, issued on December 13, 2024, job growth in the state will decrease to 0.7% for 2025 and 0.6% for 2026. Although visitor recovery after the wildfires was somewhat stronger than expected, that recovery has now stalled as Maui hotels are seeing historically low occupancy rates. Similarly, the labor market on Maui remains constrained by post-fire disruptions and outmigration, with employment remaining well below pre-wildfire levels. Unemployment in Maui County is predicted to recede to 3.2% in 2025 and 2026.
Hawaii real estate activity through December 2024, as indicated by Oahu’s home resale market, resulted in an increase in the median sales price of 1.3% for condominiums and an increase of 4.8% for single-family homes compared to the same period in 2023, with the December median single-family home price of $1,054,500, below the record $1,153,500 set in May 2022. The number of closed sales through December 2024 decreased 2.5% for condominiums and increased 9.1% for single-family residential homes compared to the same period in 2023.
Hawaii’s petroleum product prices relate to the crude oil in international markets. The price of crude oil has decreased about 10.9% over the same quarter in the prior year.
At its December 18, 2024 meeting, the Federal Open Market Committee (FOMC) decided to lower the federal funds rate target range by 1/4 percentage point to 4.25% - 4.5%. The FOMC’s decision reflects their judgement that the risks to achieving its goals of maximum employment and an inflation rate of 2 percent over the longer run, are roughly in balance. The Federal Reserve stated that it will continue to reduce its holdings of Treasury securities, agency debt, and agency mortgage-backed securities.
UHERO forecasts full year 2025 real GDP growth of 2.9%, an increase in total visitor arrivals of 2.8%, an increase in real personal income of 1.7%, and an unemployment rate of 2.8% for the state. The post-wildfire recovery of the Maui visitor industry has stalled, while tourism across the rest of the state has been flat. Although the 2024 U.S. economy continued to expand, supported by consumer and government spending, some deceleration is expected as consumers face weakening employment conditions and rising financial stress.
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.
(in millions) 2024 2023 Change
Primary reason(s)
Revenue1
$ 13 $ 18 $ (5) Decrease in other sales at Pacific Current subsidiaries.
Operating loss1
(95) (27) (68) Higher HEI corporate operating loss ($40 million in 2024 vs. $24 million in 2023) primarily due to $10 million higher Maui windstorm and wildfires related costs ($15 million in 2024 vs. $5 million in 2023), and increases in incentive compensation, legal and insurance expenses. Higher Pacific Current operating loss ($55 million in 2024 vs $3 million in 2023) primarily due $35.2 million impairment loss on certain long-lived assets at Pacific Current in the third quarter of 2024, $4.9 million in leased turbine repair costs at Hamakua Energy, $3.5 million impairment loss on damaged assets in a March 2024 fire at Mahipapa, and lower Pacific Current asset performances mainly at Hamakua Energy and Mahipapa due to unexpected plant shut downs in the first quarter of 2024 as compared to the prior year period.
Interest expense & other, net
(45) (40) (5) Primarily due to higher average long-term debt balances in 2024 than in 2023.
Interest income
13 3 10 Primarily due to interest income from common stock offering proceeds.
Loss on sale of equity-method investment
- (1) 1 Prior year loss on sale of an equity-method investment at Pacific Current.
Income tax benefit 31 17 14 Higher pretax loss
Net loss $ (96) $ (48) $ (48)
1 Hamakua Energy’s sales to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation.
Note: Total may not foot due to rounding.
In late February 2024, Hamakua Energy’s first combustion turbine (CT1) and its leased combustion turbine (leased CT) unexpectedly sustained damages resulting in a plant shut down on Hawaii Island. Due to the generation capacity shortfall on Hawaii Island, unit age and extensive timeline and cost to repair CT1, in April 2024, Hamakua Energy purchased a new combustion turbine and installed the unit in May 2024 at a total cost of approximately $8.3 million. The new CT1 was placed into service in June 2024. 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. Pursuant to the lease pool program agreement, Hamakua Energy is reimbursing the lessor for damages of the leased CT and accordingly, accrued $4.9 million of estimated repair costs as of December 31, 2024. Hamakua Energy’s second combustion turbine (CT2) is currently in a scheduled overhaul which has incurred delays due to supply shortages. The CT2 overhaul is expected to be completed and the unit placed back into service in the first quarter of 2025. After conducting an investigation into the root cause of the damages, it was determined that contaminated fuel led to the turbine damages. Hamakua Energy is currently working with its legal counsel and insurance company on seeking recovery of its losses related to damages sustained to its plant facilities.
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 with an expectation to ramp up to full capacity in the first quarter of 2025. As of December 31, 2024, Mahipapa has received initial insurance proceeds of $0.8 million under its business interruption policy. In addition to working with its insurance company, Mahipapa is 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 February 7, 2025, Pacific Current entered into a Securities Purchase Agreement to sell all the membership interests in Hamakua Holdings, LLC, a wholly owned subsidiary of Pacific Current, to an unaffiliated third party for cash consideration to be determined under the provisions of the agreement. Hamakua Holdings, LLC has two wholly-owned subsidiaries: Hamakua Energy, LLC, which owns a 60-MW combined cycle power plant that sells power to Hawaii Electric Light under an existing power purchase agreement, and HAESP, LLC (created in connection with the current on-going Stage 3 RFP process). Upon closing, both Hamakua Energy and HAESP, LLC as wholly-owned subsidiaries of Hamakua Holdings will no longer be owned by Pacific Current. The close of the transaction is subject to the satisfaction of certain customary closing conditions and is expected to be finalized in March 2025. The sale transaction is not expected to have a material impact to the Company’s consolidated financial statements.
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 recent 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. In August 2023, HEI and Hawaiian Electric fully drew down $175 million and $200 million, respectively, on their existing revolving credit facilities. The cash proceeds were primarily invested in highly liquid short-term investments and used for general corporate purposes. 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. Some of these proactive measures include suspending the quarterly cash dividend on HEI’s common stock after payment of the second quarter dividend in September 2023 and reducing or eliminating discretionary costs.
As of December 31, 2024, HEI and Hawaiian Electric had $173 million and $166 million, respectively, drawn on their revolving credit facilities and no commercial paper outstanding. As of December 31, 2024, the total amount of available borrowing capacity under HEI’s and Hawaiian Electric’s revolving credit facilities was $2 million and $34 million, respectively (see Note 6 of the Consolidated Financial Statements for additional information). As of December 31, 2024, HEI consolidated had $2.8 billion of long-term debt, net, of which $110 million is due within 12 months and $263 million is due within 24 months (see Note 7 of the Consolidated Financial Statements for additional information).
As of December 31, 2024, 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 claims (see Note 2 of the Consolidated Financial Statements). For 2024, HEI and its subsidiaries incurred net losses from continuing operations of approximately $1.32 billion.
When preparing financial statements for each annual and interim reporting period, management has the responsibility to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about the Company’s ability to continue as a going concern within one year after the date that the financial statements are issued. In making their evaluation, the Company considers, among other things, risks and/or uncertainties related to their results of operations, contractual obligations, near-term debt maturities, dividend requirements, debt covenant compliance, or other factors impacting the Company’s liquidity and capital resources.
The Company previously concluded that as of June 30, 2024, conditions existed that raised substantial doubt about its ability to continue as a going concern, and that while the Company was working with its financial advisors on a financing plan to raise the capital necessary to mitigate those conditions, there was no assurance that management’s plans would be successful. As a result, the Company disclosed in the condensed consolidated financial statements included in the Company’s Quarterly Report on Form 10-Q for the quarter ending June 30, 2024 there was substantial doubt about the Company’s, including the Utilities’, ability to continue as a going concern.
In the third quarter of 2024, the Company 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 Consolidated Balance Sheet. 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 addition, HEI filed with the SEC an at-the-market (ATM) 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 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 of the first installment payment is classified as restricted cash on the Consolidated Balance Sheet as of December 31, 2024.
On December 31, 2024, HEI completed the sale of 90.1% of the common stock of ASB, amounting to $405.5 million, to various investors including certain officers and directors of ASB, while retaining a 9.9% noncontrolling investment in ASB amounting to $44.6 million. No investor acquired more than 9.9% of the common stock of ASB. The proceeds from the sale will be used to pay down HEI’s debt in 2025.
At December 31, 2024, the Company’s consolidated total available liquidity, was approximately $1,153 million. The following table provides the components of available liquidity at December 31, 2024. See “Liquidity and capital resources” in Hawaiian Electric’s MD&A below for components of its available credit.
As of December 31, 2024
(in millions)
Capacity
Outstanding
Undrawn
Electric Utility
Total credit
$ 564 $ 216 $ 348
Restricted credit
(198)
Total available credit - Electric Utility1
$ 150
All Other
Unsecured revolving line of credit
$ 175 $ 173 $ 2
ATM program
250 - 250
Total credit - All Other
425 173 252
Restricted credit
-
Total available credit - All Other
$ 252
Consolidated cash and cash equivalents
Total available liquidity $ 1,153
1 The Electric Utilities’ total undrawn credit amounts to $348 million; however, due to certain financial covenant requirements, the temporary available credit is limited to approximately $150 million. The Utilities subsequently paid off $47 million of long-term debt that became due on January 1, 2025, which would increase the total available credit to $200 million.
Management believes the Company’s cash and cash equivalents amount of $751 million and GLST1’s restricted cash amount of $479 million, both as of December 31, 2024, the available capacity on Hawaiian Electric’s asset-based lending facility (ABL Facility) (see Note 6 of the Consolidated Financial Statements), additional liquidity under HEI’s recently registered ATM program as well as expenditure reduction efforts effectively alleviate any conditions that caused there to be substantial doubt regarding HEI’s and Utilities’ ability to continue as a going concern. 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 earlier than the fourth quarter of 2025 and its other cash obligations for the next 12 months following the issuance of its December 31, 2024 financial statements. The plans that have been implemented have mitigated the conditions that previously caused the substantial doubt about the Company’s ability to continue as a going concern since the date of filing its 2024 second quarter 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 prevents 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 in a timely manner and on acceptable 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.
For the Utilities, while fuel prices have moderated from their highs in 2022, they remain elevated and have increased the cost of carrying fuel inventory and higher customer accounts receivable balances as fuel is consumed and billed to customers. While the accounts receivable balance has decreased since December 2023, it remains elevated coming out of the pandemic and has led to higher bad debt expense and higher write-offs in 2023 and 2024, following the end of the moratorium on disconnections. The higher bad debt expense is expected to continue until the Utilities return to pre-pandemic accounts receivable balances, along with a decrease in volume, for delinquent accounts. The Maui windstorm and wildfires have not and are not anticipated to materially impact accounts receivable, however, it has and will continue to lead to higher bad debt expense. As of December 31, 2024, approximately $18.3 million of the Utilities’ accounts receivables were over 30 days past due, which is a decrease of approximately 17% since December 2023. In addition to the cash flow impact from delayed collection of accounts receivable, lower kWh sales relative to the level of kWh sales approved in the last rate case generally result in delayed timing of cash flows, resulting in higher working capital requirements (see “Recent Developments” in the Electric utility section below).
If further liquidity is deemed necessary in the short term, Hawaiian Electric could also use its available capacity on its $250 million ABL Facility, 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 sustainable infrastructure investments.
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, 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 addition to the funds required for the Utilities’ construction programs and debt maturities, with respect to HEI, approximately $50 million will be required in the fourth quarter of 2025 to repay maturing long-term debt if not refinanced. 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 or Pacific Current; 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 miscellaneous 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, 2024, HEI and the Utilities have approximately $13 million, nil and $122 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 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, 2024 Payments due by period
(in millions) 2025
After five years
Total
Contractual obligations
Short-term borrowings $ 49 $ - $ - $ - $ - $ - $ 49
Long-term debt
110 153 435 274 51 1,790 2,813
Interest on short-term and long-term debt
130 120 103 88 80 703 1,224
Settlement Agreements
479 479 479 478 - - 1,915
Operating and finance leases
PPAs classified as leases 50 50 50 45 45 672 912
Other leases
13 13 7 5 5 24 67
Hawaiian Electric open purchase order obligations1
191 163 41 14 6 23 438
Hawaiian Electric fuel oil purchase obligations (estimate based on fuel oil price at December 31) 5 - - - - - 5
Hawaiian Electric purchase power obligations-minimum fixed capacity charges not classified as leases
101 102 106 105 105 800 1,319
Liabilities for uncertain tax positions 1 - 7 - - - 8
Total (estimated) $ 1,129 $ 1,080 $ 1,228 $ 1,009 $ 292 $ 4,012 $ 8,750
1Includes 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, potential settlements of securities class action and shareholder lawsuits, and potential refunds of amounts collected from ratepayers (e.g., under the earnings sharing mechanism). As of December 31, 2024, the fair value of the assets held in trusts to satisfy the obligations of the Company’s retirement benefit plans did not exceed the retirement benefit plans’ benefit obligation. Minimum funding requirements for retirement benefit plans have not been included in the table above; however, see Note 11 of the Consolidated Financial Statements for 2025 estimated retirement benefit plan obligations and contributions.
See Note 4 of the Consolidated Financial Statements for a discussion of the Utilities’ commitments.
Operating activities provided net cash of $487 million in 2024, $551 million in 2023 and $454 million in 2022, of which operating activities from continuing operations provided net cash of $428 million in 2024, $443 million in 2023 and $334 million in 2022. Investing activities provided net cash of $258 million in 2024 and used net cash of $257 million in 2023 and $1,129 million in 2022, of which investing activities from continuing operations used net cash of $334 million in 2024, $436 million in 2023 and $351 million in 2022. In 2024, 2023 and 2022, net cash used in investing activities from continuing activities was primarily due to capital expenditures.
Financing activities provided net cash of $155 million in 2024, $196 million in 2023 and $568 million in 2022, of which financing activities from continuing operations provided net cash of $498 million in 2024, $203 million in 2023 and $6 million in 2022. 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. In 2022, net cash provided by financing activities from continuing operations included proceeds from long-term debt and short-term debt and net increases in short-term borrowings, partly offset by repayment of long-term debt 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) 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” sections below.) During 2024, Hawaiian Electric and ASB (through ASB Hawaii prior to its sale) paid cash dividends to HEI of $26 million and nil, respectively.
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. This action is intended to allow the Company to provide additional liquidity and allocate cash to rebuilding and restoring power and help ensure a strong future for the Utilities and the Bank it previously owned. The ASB Board of Directors suspended its quarterly cash dividends to HEI, starting after the second quarter 2023 dividend, and the Hawaiian Electric Board of Directors suspended its quarterly dividends to HEI, starting with the second quarter 2024 dividend, which would have been paid in the third quarter of 2024. The decision of the Hawaiian Electric Board of Directors to suspend its dividend to HEI was based upon the size of the proposed settlement of wildfire tort litigation and the fact that, although HEI and the Utilities have sufficient liquidity to fund the first settlement payment, no definitive funding plan currently exists for the remaining settlement payment liability.
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 electric 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 2024 2023
(dollars in millions)
Short-term borrowings, net
$ 49 1 % $ - - %
Long-term debt, net
2,800 64 2,842 54
Preferred stock of subsidiaries 34 1 34 1
Common stock equity 1,479 34 2,345 45
$ 4,362 100 % $ 5,221 100 %
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, 2024. 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 credit ratings will impact HEI’s ability to access capital markets and other sources of debt and equity financing, if at all, in a timely manner and on acceptable terms.
See Notes 6 and 7 of the Consolidated Financial Statements for a brief description of the Company’s loans.
In August 2023, the credit ratings of HEI and Hawaiian Electric were subject to multiple downgrades, including to ratings below investment grade, by Fitch, Moody’s and S&P. These rating actions were primarily due to the uncertainty facing the Company due to the damages caused by the Maui windstorm and wildfires. As of February 14, 2025, the Fitch, Moody’s and S&P ratings of HEI were as follows:
Fitch Moody’s S&P
Long-term issuer default, long-term corporate family and issuer credit, respectively
B B1
B-
Short-term issuer default, commercial paper and commercial paper, respectively B NP B
Outlook Stable
Stable
Negative
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 capital markets and other sources of debt and equity financing, if at all, in a timely manner and on acceptable terms. 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 earlier than the fourth quarter of 2025. 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 capital markets and other sources of debt and equity financing, if at all, in a timely manner and on HEI’s acceptable terms.
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 with the SEC an at-the-market (ATM) 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 2024, 2023 or 2022 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 2023 through September 4, 2023, December 6 through December 31, 2023, in 2024 or in 2022 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 Dividend Reinvestment Program (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
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, 2024, the discount rates for HEI and the Utilities’ pension and other benefits plans were 5.77% and 5.72%, 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, 2024, 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 $(116)/$129
$(113)/$126
Other benefits
Discount rate +/-50 $(7)/$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 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.
HEI and Hawaiian Electric evaluated various financing plans to pay the amounts included in the Settlement Agreements (refer to “Recent Developments” and Note 2 of the Consolidated Financial Statements) 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. The Utilities recorded a settlement accrual of $1.92 billion which reflects their best estimate of the loss contingency. The Utilities also recorded an additional $40 million in other accounts receivable, net as shown on the Utilities’ Consolidated Balance Sheet as of December 31, 2024, based on the amounts expected to be remaining under the applicable insurance policies at time of settlement payment.
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 within the next five years before the loss expires. Therefore, a valuation allowance totaling $66.4 million for federal and state was recorded in 2024 for HEI consolidated, related to the capital loss.
The Company has 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 seventeen-year period for HEI consolidated and thirteen-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.
Electric utility
Executive overview and strategy. The Utilities provide electricity on all the principal islands in the state, other than Kauai, to approximately 95% of the state’s population, and operate five separate grids. The Utilities’ mission is to provide innovative energy leadership for Hawaii, to meet the needs and expectations of customers and communities, and to empower them with safe, reliable, affordable clean energy. The goal is to create a safe, modern, resilient, flexible, and dynamic electric grid that protects Hawaii from impacts of climate change and enables an optimal mix of distributed energy resources, such as private rooftop solar, demand response, and grid-scale resources to enable the creation of smart, sustainable, resilient communities and achieve their decarbonization goals that are aligned with the statutory goal to achieve a 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.
In 2024, 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). For the full year 2024, the Utilities incurred net losses of approximately $1.23 billion.
For the full year 2024, operation and maintenance expenses were higher by approximately $76 million, or 14%, as compared to 2023. The increase was mainly due to an agreement to settle indemnification claims asserted by the State of Hawaii, higher property and general liability insurance costs, wildfire mitigation program expenditures primarily related to inspections, and higher outside services for legal, engineering and grant management, partially offset by labor and associated costs for the Maui windstorm and wildfires incurred in 2023.
For the full year 2024, kWh sales volume decreased 0.1% from 2023 levels. The slight decrease reflects the impacts of the Maui windstorm and wildfires. Maui consumption showed a year-over-year decrease of 6.0% in the first half of 2024 due to the reduction in sales after the wildfires, and a 4.3% increase over the second half due to the partial recovery relative to the months immediately following the wildfires.
The price of crude oil has decreased about 2.4% 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 2024, the consumer price index increased 2.9% over the last 12 months. In Hawaii, the November 2024
Urban Hawaii (Honolulu) Consumer Price Index (CPI) increased 3.5% over the last 12 months. Under the PBR framework, inflation risk for the Utilities is partially mitigated by an Annual Rate Adjustment (ARA), which is based on a formula that includes a compounded and non-compounded portion.
•The compounded portion of the ARA adjustment includes an adjustment for the annual change in inflation based on the estimated change in Gross Domestic Product Price Index (GDPPI) for the upcoming year, less a predetermined annual productivity factor (currently set at zero), less a 0.22% customer dividend, applied to a basis equal to test year target revenues plus the RAM Revenue adjustments in effect prior to the implementation of PBR, plus the prior adjustment year’s compounded portion of the ARA adjustment. The inflation factor percentage is the consensus projection of annual percentage change in GDPPI for the following calendar year published by Blue Chip Economic Indicators each October. For the 2024 calendar year, the forecasted 2024 GDPPI was 2.18% (net of the 0.22% customer dividend), measured in October 2023, and became effective in rates on January 1, 2024. 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.
•The non-compounded portion of the ARA adjustment includes a subtractive component, representing the management audit savings commitment, or refund to customers, which was approved by the PUC for the years 2021 through 2025.
Customer accounts receivable decreased in 2024 by $44 million, or 18% with the number of accounts past due greater than 90 days decreasing by 29% since December 31, 2023. The decrease in accounts receivables was primarily driven by receipt of government and other program assistance, higher cash receipts associated with increased disconnection efforts and a change in bill due date from 19 days to 15 days in March 2024, along with lower customer bills resulting from lower fuel prices. At this time, while accounts receivable balances continue to remain elevated compared to pre-pandemic levels, it has been trending down closer to pre-pandemic levels, with the exception for Maui County, and the decrease in accounts receivable balances since the beginning of the year has reduced working capital requirements and benefited the Utilities’ liquidity. See “Financial Condition-Liquidity and capital resources” for additional information.
System reliability. On March 25, 2024, the Utilities called on Hawaii Island customers to reduce or shift their electricity usage, and in certain instances initiated rolling outages due to a generation capacity shortfall. The situation was due to Hamakua Energy’s unexpected plant shutdown in late February 2024 and also due to the unavailability of generators that have experienced mechanical problems, were at reduced output, or were undergoing maintenance. During that time, generation margins were below targeted levels, especially when wind, solar and hydroelectric output were lower than forecasted. On April 24, 2024, the Utilities lifted their request to conserve electricity as several of the Utilities’ large generators returned to service and on June 3, 2024 Hamakua Energy completed replacement of one combustion turbine and returned it to service. The second combustion turbine returned to service on September 9, 2024. See above in “HEI MD&A-“All Other” segment” for discussion relating to Hamakua Energy’s unexpected plant shutdown. While Hamakua Energy has returned to service, their total output remains restricted due to needed fuel system inspections and repairs that will not be completed until mid Q1 2025. However, adequate generation margins are expected based on forecasted load and maintenance schedules.
Since the August 2023 Maui windstorm and wildfires, the Utilities have developed a set of Interim Wildfire Safety Measures (IWSM) to mitigate the risk of wildfires in areas identified as having higher risk of wildfire in all service territories (Oahu, Maui County, and Hawaii Island). These interim measures represent actions the Utilities have performed in 2024. On January 10, 2025, the Utilities filed its 2025-2027 Wildfire Safety Strategy, which outlines its plans to reduce wildfire risk throughout its service territories over the next three years. In the near term, it is anticipated that these measures will result in disruptions to service and negatively impact T&D SAIDI and SAIFI. While the Utilities work to refine these measures over time to mitigate customer impacts, the Utilities are currently focused on taking immediate steps to keep island communities safe during extreme weather events. For a discussion regarding the launch of the Public Safety Power Shutoff (PSPS) program, see discussion below under “Wildfire Safety Measures.”
Regulatory developments. On November 15, 2021, former President Biden signed into law the $1.2 trillion Infrastructure Investment and Jobs Act (IIJA), which includes approximately $550 billion of new federal spending to be allocated over the next five years through various programs. The funding will help the State of Hawaii achieve its sustainability goals, including renewable energy, resilience, and decarbonization, while also prioritizing economic development, equity and affordability. The Utilities have been pursuing potential grant funding of projects under various programs as primary applicant as well as in partnership with other organizations. On August 7, 2024, the Utilities received a notification from the U.S. Department of Energy that their Climate Adaption Transmission and Distribution Resilience Program (Resilience Program) application for $95 million in federal funds under IIJA was officially awarded. See “Utility projects” in Note 4 of the Consolidated Financial Statements for additional discussions.
On August 16, 2022, former President Biden signed into law the Inflation Reduction Act of 2022 (IRA) that provides for $258 billion in energy-related provisions over a 10-year period. The provisions of the IRA are intended to, among other things, lower gasoline and electricity prices, incentivize clean energy investment and promote reductions in carbon emissions. The
Utilities are exploring clean energy tax incentives included in the IRA that may further reduce the Utilities’ recovery under the EPRM and cost to customers. See Note 13 of the Consolidated Financial Statements for additional information.
In January 2025, President Trump issued multiple Executive Orders (EOs) that impact both IIJA and IRA funding. EO 14154 entitled Unleashing American Energy ordered to immediately pause disbursement of funds appropriated through IIJA and IRA grants, which is causing delays in processing the Utilities’ requests for reimbursement for the Resilience Program and may potentially lead to project delays and economic uncertainty. The EO entitled Ending Radical and Wasteful Government DEI Programs and Preferencing resulted in the federal contracting officer ordering recipients to cease all diversity, equity and inclusion and community benefits plan activities funded by federal grants as of January 28, 2025, which could potentially impact the Utilities’ existing community benefits agreements with some third parties and commitments included in the Resilience Program project costs. The Utilities are unable to predict the timing or amount of the funding the Utilities may receive as a result of the two EOs mentioned above.
For a discussion regarding the impact of the Maui windstorm and wildfires on the Utilities’ liquidity and capital resources, see discussion under “Financial Condition-Liquidity and capital resources.”
Performance-based regulations. On December 23, 2020, the PUC issued a D&O (PBR D&O) approving a new performance-based regulation framework (PBR Framework). See “Regulatory proceedings” in Note 4 of the Consolidated Financial Statements.
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 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, while simultaneously working to develop a more comprehensive strategy. These actions included wildfire risk analysis, operation procedures and grid design changes, enhanced inspection and vegetation management plans, and system hardening. In January 2025 the Utilities developed and filed with the Hawaii PUC a 2025-2027 Wildfire Safety Strategy, which identifies risk mitigation strategies to perform over the next three years across its service territories. 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. The Wildfire Safety Strategy is estimated at $450 million to implement over the 2025-2027 period. The Utilities are planning to submit a PUC application for EPRM cost recovery in the first quarter of 2025.
One of the interim measures is the Public Safety Power Shutoff (PSPS) program, which calls for the Utilities to preventatively de-energize circuits in areas identified as high fire risk during certain weather conditions. The PSPS program launched on July 1, 2024 and is ready to use, if and when it is needed, and as the last line of defense to protect customers, communities and employees. The initial PSPS protocols and operational procedures represent an early-stage iteration, which will evolve over time as more analytical, forecast, and situational awareness capabilities and wildfire mitigations are deployed. De-energizing circuits in high wildfire risk areas will lead to extended interruptions for many customers, even if not in a high wildfire risk area. The Utilities will continue to work with key stakeholders in balancing the risk of utility-related wildfires with the public consequences of not having electricity.
Transition to a decarbonized and sustainable energy future. The Utilities are fully committed to leading and enabling pathways to a decarbonized and sustainable energy future for Hawaii. A sustainable energy future is one that focuses on delivering electricity safely, reliably and affordably, strengthening resilience and shifting away from fossil-fueled resources. The Utilities believe that a holistic approach to climate change is needed, working on both climate mitigation efforts along with climate adaptation efforts. Climate mitigation requires achieving the Utilities’ decarbonization and renewable energy commitments, facilitating and promoting beneficial electrification, and deploying carbon removal and offsets among other levers to reduce statewide emissions.
In the fourth quarter of 2021, the Utilities outlined their Climate Action Plan to cut carbon emissions from power generation 70% by 2030, compared to a 2005 baseline. The emissions covered by this goal include stack emissions from generation owned by Hawaiian Electric and IPPs who sell electricity to the Utilities. Since that time, delays and cancellations in the commercial operation of new renewable third-party generation resources and higher costs as a result of supply chain disruptions and inflationary pressures, as well as federal policies related to solar panel imports have slowed the pace of progress toward reducing GHG emissions. Also, see the “Developments in renewable energy efforts-New renewable PPAs” section below. The downgrade of Hawaiian Electric’s credit ratings after the Maui windstorm and wildfires is anticipated to be an additional impediment to completion of new renewable energy and storage projects due to concerns of independent power producers regarding their ability to procure low-cost financing. Therefore, legislation was introduced in the 2025 Hawaii State Legislature to alleviate concerns of independent power producers and their financing parties with regards to the Company’s credit rating. As a result of these challenges, the Utilities expect the planned 70% reduction in carbon emissions to be achieved later than the original 2030 target date. However, the Utilities will continue to replace significant amounts of fossil fuel
generation with renewable energy between now and 2030 and expect to meet or exceed the State of Hawaii’s RPS goals.
Hawaiian Electric has also committed to achieving net zero carbon emissions from power generation by 2045 or sooner. While the timing of the Utilities’ carbon reduction goals will be adjusted, key elements of the 2030 plan have already been completed or remain on track to be completed by 2030, including the closure of the state’s last coal-fired IPP plant that occurred in September 2022, increasing rooftop solar by more than 50% over 2021 levels, retiring six fossil fuel generating units, increasing grid-scale and customer-owned storage, expanding geothermal resources, and creating customer incentives for using clean, lower-cost energy at certain times of the day and using less fossil-fueled energy at night. The retirement of fossil-fueled generating units is consistent with state policy and supported by Hawaii State law.
In January 2025, the State of Hawaii issued two key policy documents and an alternative fuel study. The Hawaii 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 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 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. The Utilities are currently evaluating how their existing plans fit within these policies. 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 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 2024, 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 2024, the Utilities achieved a 35.8% RPS accruing a reward of $1.9 million based on $10/MWh in exceedance of 34.0% RPS. In 2025, the Utilities are eligible for a reward of $10/MWh in exceedance of 35.0% 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’ continued transformation, and are updated regularly to adapt to changing technology, costs, and other factors. While there is no financial penalty for failure to achieve the Utilities’ long-range aspirational objectives, the Utilities recognize that there are environmental and social costs from the continued use of fossil fuels.
The State of Hawaii’s policy is supported by the regulatory framework and includes a number of mechanisms designed to maintain the Utilities’ financial stability during the transition toward the State’s decarbonized future. Under the sales decoupling mechanism, the Utilities are allowed to recover from customers, target test year revenues, independent of the level of kWh sales, which have generally trended lower over time as privately-owned DER have been added to the grid and energy efficiency measures have been put into place. Other regulatory mechanisms under the PBR framework reduce some of the regulatory lag during the multi-year rate plan (MRP), such as the annual revenue adjustment to provide annual changes in utility revenues, including inflationary adjustments, and the exceptional project recovery mechanism, which allows the Utilities to recover and earn on certain approved eligible projects placed into service. See “Regulatory proceedings” in Note 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 IGP Stakeholder Council, Technical Advisory Panel and Working groups have been established and meet regularly to provide feedback and input on specific issues and process steps in the IGP. On March 7, 2024, the PUC accepted the Utilities’ final Integrated Grid Plan. The Integrated Grid Plan proposes actionable steps to decarbonize the electric grid on the State of Hawaii’s timeline, with a flexible framework that can adapt to future technologies. The Integrated Grid Plan is the culmination of more than five years of partnership with stakeholders and community members across the islands. Together, they forecasted future energy needs and identified strategies to meet Hawaii’s growing energy demand with 100% renewable resources.
Demand response programs. Pursuant to PUC orders, the Utilities are developing an integrated Demand Response (DR) Portfolio Plan that will enhance system operations and reduce costs to customers. The reduction in cost for the customer will take the form of either rates or incentive-based programs that will compensate customers for their participation individually, or by way of engagements with turnkey service providers that contract with the Utilities to aggregate and deliver various grid services on behalf of participating customers and their distributed assets.
On June 8, 2021, the PUC approved the Emergency Demand Response Program (EDRP), a battery storage incentive program to dispatch electricity between 6 p.m. to 8 p.m. daily from participating residential and commercial customers, to address the potential reserve shortfalls following the AES coal plant retirement. The battery bonus on Oahu is officially closed to new applications. As of December 31, 2024, the Utilities have received and approved applications totaling 47.95 MW on Oahu.
On March 30, 2022, the Utilities filed with the PUC to request expanding the EDRP for up to 15 MW on the island of Maui and received PUC approval on May 20, 2022. The EDRP on Maui became effective as of June 1, 2022. Subsequently, on June 23, 2022, the PUC approved the cost recovery of the additional incentives for both Oahu and Maui through the Demand Side
Management Surcharge. As of December 31, 2024, the battery bonus program on Maui has officially closed to new applications, and the Utilities have received and approved the applications totaling approximately 10.55 MW on Maui.
Grid modernization. The overall goal of the Grid Modernization Strategy (GMS) is to deploy modern grid investments at an appropriate priority, sequence and pace to cost-effectively maximize flexibility, minimize the risk of redundancy and obsolescence, deliver customer benefits and enable greater DER and renewable energy integration. On March 25, 2019, the PUC approved a plan for the Utilities to implement GMS Phase 1, which is the proportional deployment of advanced metering infrastructure (AMI). On February 28, 2022, the PUC expanded the scope of Phase 1 to the full service territory with a completion date set for the third quarter of 2024. The Utilities completed the formal GMS Phase 1 project on September 30, 2024, and deployed about 447,000 advanced meters, servicing approximately 95% of total customers. Approximately $129 million of capital and deferred software costs were incurred under Phase 1 and is currently being recovered under the MPIR mechanism until such costs are included in base rates. Since formal GMS Phase 1 Project completion, the Utilities continue to deploy advanced meters as part of normal Meter Shop operations under the existing Annual Revenue Adjustment (ARA) budget.
The Utilities filed an application with the PUC on September 30, 2019 for an Advanced Distribution Management System (ADMS) as part of Phase 2 of their GMS implementation. On March 31, 2021, the Utilities filed a supplement and update to the GMS Phase 2 ADMS application to include broad deployment of field devices, which the PUC suspended on November 16, 2021, to focus the Utilities’ attention on completing Phase 1. On April 17, 2023, the Utilities filed a motion with the PUC, requesting the suspended docket to be reopened and to allow the Utilities to file an updated and supplemented application for updated project costs (net of Department of Energy “DOE” Infrastructure Investment Jobs Act “IIJA” Grid Resilience and Innovation Partnerships “GRIP” Round 1 grant funding) and expansion of the Phase 2 scope to also include Operational Technology Cybersecurity Monitoring. Given the Utilities were unsuccessful in obtaining GRIP Round 1 grant funding, on May 31, 2024, the Utilities filed another updated and supplemented application for updated project costs (net of GRIP Round 2 funding), as well as the addition of Private Long-Term Evolution (PLTE) expansion and Supervisory Control and Data Acquisition (SCADA) expansion to the prior GMS Phase 2 scope (ADMS, Field Devices, and Operational Technology Cybersecurity Monitoring). In light of the Utilities finding out that they were not awarded GRIP Round 2 funding, 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 first quarter of 2025.
Community-based renewable energy. In December 2017, the PUC adopted a community-based renewable energy (CBRE) program framework which allows customers who cannot, or chose not to, take advantage of private rooftop solar to receive the benefits of renewable energy to help offset their monthly electric bills and support clean energy for Hawaii. The program has two phases.
The first phase, which commenced in July 2018, totaling 8 MW of solar photovoltaic (PV) only with one credit rate for each island, closed on April 9, 2020. Two phase 1 projects (28.32 kW on Maui and 270 kW on Oahu) have been operational for three years and one Phase 1 project (3,000 kW on Oahu) achieved commercial operations on October 1, 2023. Two additional phase 1 projects achieved commercial operations on April 1, 2024 (Hawaii Island: 750kW and Molokai: 250kW).
The second phase, which commenced on April 9, 2020 and subsequently expanded on July 27, 2021, allows over 250 MW across all Hawaiian Electric service territories in two tranches for small (under 250 kW), mid-tier and large system sizes to encourage a variety of system sizes. To provide opportunities for low-to-moderate income (LMI) customers to participate in the program, 23 MW of capacity for dedicated-LMI projects were awarded on November 15, 2022 through three island specific RFPs for Oahu, Maui and Hawaii Island. LMI projects do not have a size cap nor do they decrease the 250 MW capacity available to other projects. Three projects have since been withdrawn by the selected CBRE developers and the remaining 14 MW of dedicated-LMI projects are expected to become operational in 2026.
The Utilities issued the CBRE Tranche 1 RFPs for Oahu, Maui and Hawaii on April 14, 2022. The RFPs closed on August 17, 2022, and proposals were evaluated. Tranche 1 projects, which are greater than or equal to 250 kW, were awarded on February 22, 2023. Two projects on Hawaii Island were subsequently withdrawn by the developer on October 18, 2023. Two additional Hawaii Island projects were disqualified on May 13, 2024. On June 14, 2024, a project on Oahu was withdrawn by the developer. There are no remaining Tranche 1 projects in development.
For Lanai, the Utilities combined the previously issued Variable Renewable Dispatchable Generation Paired with Energy Storage RFP and the CBRE RFP to optimize the benefits of procuring renewable energy, spur development and increase the likelihood of success of the CBRE Program on Lanai. See “Developments in renewable energy efforts-Requests for renewable proposals, expressions of interest, and information” for additional information.
One CBRE proposal for Lanai was selected but negotiations were terminated on June 15, 2022. With the concurrence of the independent observer, a replacement proposal was selected on July 1, 2022. On July 25, 2022, the Utilities announced the selection of a new developer for the Lanai CBRE RFP. On September 21, 2022, the Utilities were informed by Pulama Lanai of
a project being planned on Lanai to remove the two large resorts from the grid, which represent approximately 40% of the load of the island and raises great uncertainty around the future energy needs for Lanai. On September 28, 2022, the Utilities notified the PUC that ongoing negotiations for the Lanai CBRE project would continue, but the Utilities did not execute a PPA at this time given the uncertainty due to the Pulama Lanai notification. Unfortunately, due to the lapse in time from selection, the parties were unable to reach an agreement on a PPA and on October 23, 2024, the developer submitted a withdrawal letter to the Utilities. The Utilities are considering options for procuring renewable energy on Lanai. On Molokai, proposals were only received from a single community co-op group. After evaluation of these proposals and with concurrence of the independent observer, the Utilities filed a letter on September 9, 2022, proposing to close the Molokai CBRE RFP and to work with the lone bidder to improve certain aspects of their two proposed projects outside of the RFP process for the benefit of the residents of Molokai. After successful negotiations, two contracts for solar plus storage facilities were executed and on September 29, 2023, the Utilities filed two applications with the PUC requesting approval of the contracts. On January 8, 2024, the PUC approved the two contracts.
The Utilities CBRE Phase 2 Rule 29 became effective on March 10, 2022. The Utilities are currently accepting project applications for small CBRE projects less than 250 kW in size. The PUC reserved 45 MW as well as a small amount of unallocated capacity from Phase 1 for small projects in Phase 2 on Oahu, Maui and Hawaii Island. The Utilities have developed a CBRE Portal where Subscriber Organizations can apply for small project capacity and manage subscribers for all CBRE projects in the program. Customers can also use the CBRE Portal to solicit subscription quotes, compare, and subscribe to a project once the Subscriber Organization has added their project to the portal.
Microgrid services tariff proceeding. In enacting Act 200 of 2018, the Hawaii legislature found that Hawaii’s residents and businesses were vulnerable to disruptions in the islands’ energy systems caused by extreme weather events or other disasters, and stated its belief that the use of microgrids would build energy resiliency into Hawaii’s communities, thereby increasing public safety and security. The purpose of Act 200 was therefore to encourage and facilitate the development and use of microgrids through the establishment of a standard microgrid services tariff. In July 2018, pursuant to Act 200, the PUC opened a proceeding to investigate the establishment of a microgrid services tariff. In August 2019, the PUC issued an order prioritizing items for resolution in the docket and directed the Parties to establish working groups (the Working Group) to address issues identified by the PUC.
On May 27, 2021, the Utilities filed the Microgrid Service Tariff. On September 21, 2021, the PUC provided guidance for Phase 2 of the Microgrid Tariff proceeding, specifically identifying the objective for Phase 2 to promote self-sufficiency and resilience among microgrid project operators, as well as to further streamline the Microgrid Services Tariff where applicable. Furthermore, the PUC instructed Parties to recommend priority topics, along with supporting rationale to better inform the topics that will be discussed during this phase of the proceeding, which the parties submitted by October 21, 2021.
On April 1, 2022, the PUC established its Prioritized Issues for Resolution for Phase 2 of the Microgrid proceeding, which includes the following: 1) Microgrid Compensation and Grid Services; 2) Utility Compensation; 3) Customer Protection and Related Considerations; 4) Interconnection; and 5) Working Group coordination with related microgrid and resilience Initiatives at Hawaiian Electric and government agencies. Furthermore, the PUC established a procedural schedule to consist of quarterly status conference meetings with the PUC, a Phase 2 Working Group Report, draft of a revised Microgrid Service Tariff, Party comments to the proposed Microgrid Service Tariff, followed by a PUC D&O.
On June 30, 2022, the PUC provided further guidance to the Working Group to prioritize discussion of the microgrid types in the following order: 1) Hybrid Microgrid - Third Party Developer using Utility lines/infrastructure; 2) Hybrid Microgrid - Utility Project with Partners; and 3) Customer Microgrid. Additionally, the PUC instructed the Working Group to discuss microgrid compensation and continue the involvement of microgrid developers in working group meetings.
The Working Group met from April 2022 through October 2022 to discuss the PUC’s objectives and respond to the Phase 2 priority issues. On October 31, 2022, the PUC issued a guidance letter and advised that the Working Group propose a new timeline for the Report. The Utilities and the Consumer Advocate filed a joint letter with a revised timeline on November 10, 2022. On November 21, 2022, the PUC issued an order to suspend the Phase 2 procedural schedule of the microgrid docket.
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 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. The PUC scopes the first three Phases of this docket, as follows: Phase 1: Stakeholder Outreach on Intragovernmental Wheeling; Phase 2: Docket Proceeding on Intragovernmental Wheeling; Phase 3: PUC decision making step. The Wheeling proceeding is currently in Phase 1. On December 9, 2024, the PUC convened an initial Stakeholder Meeting, at which Hawaiian Electric provided a presentation on the requirements and technical feasibility to implement electricity wheeling. The Stakeholder Meeting included
a discussion on the development of a working definition of electricity wheeling and focused on intragovernmental wheeling, in particular. Discussion during the Stakeholder Meeting also addressed the topics and schedule for future Stakeholder Meetings.
Decoupling. See “Decoupling” in Note 4 of the Consolidated Financial Statements for a discussion of decoupling.
Regulated returns. As part of the PBR Framework’s annual review cycle, the Utilities track their rate-making ROACEs as calculated under the earnings sharing mechanism, which includes only items considered in establishing rates. At year-end, each utility’s rate-making ROACE is compared against its ROACE allowed by the PUC to determine whether earnings sharing has been triggered. The D&O in the PBR proceeding modified the earnings sharing mechanism to a symmetric arrangement. Effective with annual earnings for 2021, the earnings sharing will be triggered for achieved rate-making ROACE outside of a 300 basis points dead band above and below the current authorized rate-making ROACE of 9.5% for each of the Utilities. Earnings sharing credits or recoveries will be included in the biannual report (formally known as annual decoupling filing) to be filed with the PUC in the spring of the following year.
On August 31, 2023, the PUC issued an order temporarily suspending the ESM until further notice. The intent of the order is to address the unintended consequence of customers potentially bearing the costs associated with the Maui windstorm and wildfires through the operation of the ESM without prior PUC review. In accordance with the order, the earnings sharing adjustment is zero, for both 2024 and 2023 until the PUC lifts the suspension.
Actual and PUC-allowed returns, as of December 31, 2024, were as follows:
% Rate-making
Return on rate base (RORB)*
Book ROACE**
Rate-making ROACE***
Year ended December 31, 2024
Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric
Utility returns 7.18 6.23 4.25 (90.47) (38.56) (41.81) 9.09 7.48 3.54
PUC-allowed returns 7.37 7.52 7.43 9.50 9.50 9.50 9.50 9.50 9.50
Difference (0.19) (1.29) (3.18) (99.97) (48.06) (51.31) (0.41) (2.02) (5.96)
* Based on recorded operating income and average rate base, both adjusted for items not included in determining electric rates.
** Recorded net income divided by average common equity.
*** ROACE adjusted to remove items not included by the PUC in establishing rates, such as incentive compensation.
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.
If the Utilities were to exclude the impact of the Settlement Agreements, the book ROACE as of December 31, 2024 would be 8.70%, 6.46% and 2.65% for Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively, resulting in 7.27% on a consolidated basis.
The gap between PUC-allowed ROACEs and the ROACEs achieved is generally due to the exclusion of certain expenses from rates (for example, incentive compensation and charitable contributions), and depreciation, O&M expense and return on rate base that are in excess of what is currently being recovered through rates (the last rate case plus authorized RAM adjustments and ARA revenues).
Results of operations.
2024 vs. 2023
2024 2023 Increase (decrease) (dollars in millions, except per barrel amounts)
$ 3,207 $ 3,270 $ (63) Revenues. Net decrease largely due to:
$ (148) lower fuel oil prices and lower kWh generated1
3 higher other revenue and one-time true-up of billable costs
3 gain on sale of property
5 higher PIMs accrual
6 higher DSM revenue
7 higher MPIR revenue
25 higher revenue from ARA adjustments
34 higher kWh purchased and higher PPAC revenues, partially offset by lower purchased power energy prices2
1,078 1,211 (133) Fuel oil expense1. Net decrease largely due to lower fuel oil prices and lower kWh generated, offset in part by worse heat rate performance, impacted by battery storage round trip efficiency loss and the loss of more efficient generator units on Oahu and Hawaii Island
703 672 31 Purchased power expense1,2. Net increase largely due to higher kWh purchased, along with the addition of Stage 1 and Stage 2 renewable projects, offset in part by lower purchased power energy prices and the recovery of compensable curtailment energy payments in 2023
610 534 76 Operation and maintenance expense. Net increase largely due to:
17 the settlement of indemnification claims asserted by the State of Hawaii 3
14 higher property and general liability insurance costs
14 wildfire mitigation program related to inspections
9 higher outside services for legal, engineering and grant management
5 higher Demand Response cost
5 higher payroll and employee benefits costs
4 higher transmission and distribution operation and maintenance expense
4 accrual for settlement administrative fees
3 write-off of preliminary engineering costs
3 more generation maintenance work performed
2 amortization of Honolulu generating units 8 and 9 net book value at retirement
2 higher claim and liability reserves
2 higher scope of generating facility overhauls performed
(11) labor and associated costs for the Maui windstorm and wildfires response incurred and recognized in 2023
1,875 - 1,875 Wildfire tort-related claims, net. Increase 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
552 551 1 Other expenses. Increase due to higher depreciation expense due to increasing investments to integrate more renewable energy and improve customer reliability and system efficiency, partially offset by lower revenue and payroll taxes
(continued)
2024 2023 Increase (decrease) (dollars in millions, except per barrel amounts)
(1,612) 302 (1,914) Operating income (loss). Decrease largely due to wildfire tort-related claims, higher operation and maintenance expenses along with higher depreciation expenses, offset in part by higher ARA and MPIR revenue
(1,664) 247 (1,911) Income (loss) before income taxes. Decrease largely due to operating loss operating loss and lower AFUDC due to lower AFUDC equity rate, partially offset by lower interest expense and higher interest income earned
(1,226) 194 (1,420) Net income (loss) for common stock. Decrease due to loss before income taxes. See below for effective tax rate explanation
NM 8.2 % NM Return on average common equity
$ 115.00 $ 126.73 $ (11.73) Average fuel oil cost per barrel
8,219 8,227 (8) Kilowatt-hour sales (millions)4
2,518 2,564 (46) Number of full-time employees (at December 31)
1The rate schedules of the electric utilities currently contain ECRCs through which changes in fuel oil prices and certain components of purchased energy costs are passed on to customers.
2The rate schedules of the electric utilities currently contain PPACs through which changes in purchased power expenses (except purchased energy costs) are passed on to customers.
3Pursuant to an agreement to settle indemnification claims with the State of Hawaii. See Note 2 of the Consolidated Financial Statements.
4kWh sales were slightly lower compared to the prior year. The decrease in sales can be primarily attributed to 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 2024 and 2023 was 26%.
For a discussion of 2022 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 2023 Form 10-K.
For more information of the Utilities’ incremental expenses related to the Maui windstorm and wildfires for the year ended December 31, 2024, 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, 2024 amounted to $5.6 billion, of which approximately 20% related to generation PPE, 65% related to transmission and distribution PPE, and 15% related to other PPE. Approximately 6% of the total net book value relates to generation PPE that has been deactivated or that the Utilities plan to deactivate or decommission by 2046.
Regulatory proceedings. On December 23, 2020, the PBR D&O was issued, establishing the PBR Framework. The PBR Framework implemented a five-year multi-year rate period (MRP), during which there will be no general rate case applications. In the fourth year of the MRP, the PUC will comprehensively review the PBR Framework to determine if any modifications or revisions are appropriate. See also “Regulatory proceedings” in Note 4 of the Consolidated Financial Statements. The PUC is currently evaluating the Utilities’ proposal to rebase the rates in the form of a tri-company rate case with a 2026 test year.
Developments in renewable energy efforts. The Utilities’ renewable energy goals depend, in large part, on the success of renewable projects developed and operated by independent power producers. Beginning in 2017, the Utilities embarked on an ambitious procurement effort, selecting multiple solar plus storage projects to help reach the Utilities’ renewable portfolio standards goals as well as to assist the Utilities in retiring fossil fuel generation. Several of the Stage 1 and Stage 2 projects have experienced delays as a result of supply chain disruptions caused by impacts from the COVID-19 pandemic, solar product detentions at U.S. ports of entry ordered by the U.S. Customs and Border Protection agency, and unforeseen site conditions which resulted in unanticipated project costs or in some cases the inability to effectively use previously identified project sites. These impacts have resulted in five Stage 2 projects declared null and void by the independent power producers and one Stage 1 project and one Stage 2 project mutually terminating their PPAs with the Utilities. The Utilities have negotiated amendments with several project developers regarding requests to increase previously approved prices and extend guaranteed commercial operations dates for those projects in order to ensure their viability given the impact of these recent market conditions. All of these amendments have been approved. Significant project delays or failures of these projects increase the risk of the Utilities not meeting the renewable portfolio standards or other climate related goals, eligibility for performance incentive mechanisms associated with the speed of increasing renewable generation, and the ability to retire fossil fuel units. Developments in the Utilities’ efforts to further their renewable energy strategy include renewable energy projects discussed in Note 4 of the Consolidated Financial Statements and the following:
New renewable PPAs.
•On December 31, 2019, Hawaii Electric Light and Puna Geothermal Ventures entered into an Amended and Restated Power Purchase Agreement (PGV ARPPA). The PGV ARPPA extends the term of the existing PPA by 25 years to 2052, expands the firm capacity of the facility to 46 MW and delinks the pricing for energy delivered from the facility from fossil fuel prices to reduce cost to customers. On March 16, 2022, the PUC issued a D&O, approving the PGV ARPPA, subject to conditions, that include requiring completion of a final environmental review prior to construction. On March 28, 2022, Puna Pono Alliance filed a Motion for Reconsideration seeking reconsideration, modification and/or vacation of the D&O. On June 6, the PUC denied Puna Pono’s Motion for Reconsideration. PGV notified the Utilities that changes in market conditions that transpired since the terms of the PGV ARPPA were negotiated impacted the financial viability of the Project, and that an amendment to the PGV ARPPA was necessary to mitigate the impacts. On March 27, 2023, the Utilities and PGV executed the First Amendment to the PGV ARPPA which increases the capacity payment and extends the GCOD. An application requesting approval of the First Amendment to the PGV ARPPA was filed on April 4, 2023. On June 13, 2023, PGV notified the Utilities of concerns of its ability to timely deliver on the terms of the ARPPA. PGV has been working to re-establish its capacity generation and has continued drilling and plans to drill additional wells, however, this process has taken longer than anticipated and PGV has become increasingly concerned about timely achieving the Contract Firm Capacity of 46 MW. In light of receiving this information and to allow the Utilities and PGV to determine the best path forward, on July 6, 2023 the Utilities asked the PUC to put the procedural schedule on hold for approval of the First Amendment to the PGV ARPPA. In order to address PGV’s concerns, the parties executed a Second Amendment to the PGV ARPPA, which among other things lowered the capacity needed to reach commercial operations and preserves the full contract capacity, effectuating a partial commissioning. On October 2, 2023 the Utilities filed a letter requesting the docket be reopened and seeking approval of the First and Second Amendments to the PGV ARPPA by the end of 2023. On December 29, 2023, the PUC issued a D&O conditionally approving the First and Second Amendments to the PGV ARPPA. As directed, on January 12, 2024, the Utilities filed a supplemental brief explaining their request for cost recovery. On September 30, 2024, the PUC approved the Utilities’ request for cost recovery.
•Under a request for proposal process governed by the PUC and monitored by independent observers, in February 2018, the Utilities issued Stage 1 Renewable RFPs for 220 MW of renewable generation on Oahu, 50 MW of renewable generation on Hawaii Island, and 60 MW of renewable generation on Maui. To date, the Utilities filed seven requests with the PUC for approval of amendments related to previously-approved PPAs for changes in pricing and/or guaranteed commercial operations dates to support completion of the projects while maintaining system reliability. The PUC has approved all seven amendments. AES West Oahu Solar project on Oahu and AES Kuihelani Solar project on Maui reached commercial operations on March 28, 2024 and May 31, 2024, respectively. See also “Purchase commitments” in Note 4 of the Consolidated Financial Statements. To date, five projects reached commercial operations.
A summary of the remaining seven PPAs is as follows:
Utilities Number of contracts Total photovoltaic size (MW) BESS Size (MW/MWh) Guaranteed commercial operation dates Contract term (years) Total projected annual payment (in millions)
Hawaiian Electric 4 139.5 139.5/558 7/31/22, 1/11/23, 3/28/24 & 10/31/24*
20 & 25 $ 34.0
Hawaii Electric Light 2 60 60/240 4/21/23 & 10/11/24*
25 19.2
Maui Electric 1 60 60/240
5/31/24 25 13.2
Total 7 259.5 259.5/1038
$ 66.4
* Project delays have resulted in Guaranteed Commercial Operations Date being missed.
The Utilities have received PUC approvals to recover the total projected annual payment of $66.4 million for the seven PPAs through the PPAC to the extent such costs are not included in base rates.
•In continuation of their February 2018 request for proposal process, the Utilities issued their Stage 2 Renewable RFPs for Oahu, Maui and Hawaii Island and Grid Services RFP on August 22, 2019. To date, the Utilities had filed 11 PPAs. Of the 11 filed PPAs, six PPAs were declared null and void by the independent power producers and one PPA was mutually terminated. The four remaining projects have received PUC approval. To date, the Utilities filed three requests with the PUC for approval of amendments related to previously-approved PPAs for changes in pricing and/or guaranteed commercial operations dates to support completion of the projects while maintaining system reliability. The PUC has approved all three amendments. The Kupono Solar project on Oahu reached commercial operations on June 7, 2024. See also “Purchase commitments” in Note 4 of the Consolidated Financial Statements. To date, two projects reached commercial operations. Additionally, two GSPAs and two applications for commitments of funds for capital expenditures for approval of the utility self-build projects were filed with the PUC. The two GSPAs were
approved by the PUC in December 2020. As of December 31, 2024, the GSPA contracts have not yet achieved the contractual target. One of the aggregators has had financial difficulties where continuing the GSPA contract is now difficult. The Utilities are working towards planning and implementing an alternative solution for the two GSPA contracts.
A summary of the remaining four approved Stage 2 PPAs, is as follows:
Utilities Number of contracts Total photovoltaic size (MW) BESS Size (MW/MWh) Guaranteed commercial operation dates Contract term (years) Total projected annual payment (in millions)
Hawaiian Electric 3 79 79 / 443 5/17/24*, 6/7/24 & 9/1/24*
20 & 25 $ 31.4
Hawaiian Electric 1 N/A 185 / 565 12/19/23 20 24.0
Total 4 79 264 / 1,008 $ 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.
A summary of the GSPAs that were approved by PUC in December 2020 is as follows:
Utilities Fast Frequency Response - 1
(MW) Fast Frequency Response - 2
(MW) Capacity -
Load Build
(MW) Capacity -
Load Reduction
(MW)
Hawaiian Electric - 26.7 14.5 19.4
Hawaii Electric Light 6.0 - 3.2 4.0
Maui Electric 6.1 - 1.9 4.7
Total 12.1 26.7 19.6 28.1
A summary of the utility Stage 2 self-build projects is as follows:
Utilities Number of projects
BESS Size (MW/MWh) Guaranteed commercial operation dates
Hawaii Electric Light 1 * 12/12 12/30/22
Maui Electric 1 40/160 11/30/26
Total 2 52/172
* The utility Self-Build project was denied by the PUC on May 25, 2022 and the Utilities filed a motion for reconsideration with the PUC. On January 26, 2024, the PUC granted the Utilities’ November 15, 2023 request to suspend the docket to focus on identified priorities. The Utilities provided the PUC with an updated assessment of the project on April 30, 2024 and requested to withdraw the application because the need that was to be served by the project can now be met by Stage 3 RFP resources. On July 8, 2024, the Utilities received approval from the PUC to withdraw the project.
Tariffed renewable resources.
•As of December 31, 2024, there were approximately 648 MW, 147 MW and 154 MW of installed distributed renewable energy technologies (mainly PV) at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively, for tariff-based private customer generation programs, namely Standard Interconnection Agreement, Net Energy Metering, Net Energy Metering Plus, Customer Grid Supply, Customer Self Supply, Customer Grid Supply Plus and Interim Smart Export. As of December 31, 2024, an estimated 43% of single-family homes on the islands of Oahu, Hawaii and Maui have installed private rooftop solar systems, and approximately 24% of the Utilities’ total customers have solar systems.
•The Utilities began accepting energy from feed-in tariff projects in 2011. As of December 31, 2024, there were 44 MW, 2 MW and 6 MW of installed feed-in tariff capacity from renewable energy technologies at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.
Biofuel sources.
•On 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 are in negotiations with the bidders.
•On June 30, 2021, the Utilities issued an RFP for all fuels, including biodiesel, for supply commencing January 1, 2023. The Utilities and Pacific Biodiesel Technologies, LLC (PBT) signed an agreement on December 13, 2021 for supply of biodiesel on all islands commencing January 1, 2023, which was approved by the PUC on December 1, 2022. Hawaiian Electric also has a spot buy contract with PBT to purchase additional quantities of biodiesel at or
below the price of diesel. Some purchases of “at parity” biodiesel have been made under the spot purchase contract, which was extended through June 2025.
•Hawaiian Electric has a contingency supply contract with REG Marketing & Logistics Group, LLC to also supply biodiesel to any generating unit on Oahu in the event PBT is not able to supply necessary quantities. This contingency contract has been extended to November 2025, and will continue with no volume purchase requirements.
Requests for renewable proposals, expressions of interest, and information.
•On November 22, 2021, CBRE RFPs for Molokai and Lanai were opened. The RFP for Lanai sought a single PV paired with storage project, which included a 3 MW portion, reserved for CBRE. The Lanai RFP closed on February 14, 2022 and the Molokai RFP closed on March 1, 2022. A project was selected in the Lanai RFP, but negotiations were terminated. On July 1, 2022, a replacement project was selected and negotiations commenced. On October 23, 2024 the developer submitted a withdrawal letter to the Utilities. The RFP for Molokai sought 2.75 MW of new PV paired with storage projects for CBRE generation. No projects were selected in the Molokai RFP. However, with the concurrence of the independent observer, the Utilities worked with the lone bidder outside of the RFP process and filed two PPAs with a total of 2.45 MW of PV paired with 11.1 MWh of battery energy storage on September 29, 2023. The PUC approved both PPAs on January 8, 2024. See “Transition to a decarbonized and sustainable energy future-Community-based renewable energy” for additional information.
•On March 17, 2022, the CBRE LMI RFPs for Oahu, Maui and Hawaii Island were opened and proposals were received. In November 2022, seven projects were selected consisting of one standalone PV project on Oahu, three paired PV with storage projects on Maui, and three paired PV with storage projects on Hawaii Island. One project on Maui was subsequently withdrawn by the developer on April 11, 2024. The Utilities opened the CBRE Tranche 1 RFPs for Oahu, Maui and Hawaii Island on April 14, 2022. In March 2023, five projects were selected consisting of one paired PV with storage project on Oahu and four standalone PV projects on Hawaii Island. Two projects on Hawaii Island were subsequently withdrawn by the developer on October 18, 2023 and an additional project on Oahu was subsequently withdrawn by the developer on June 14, 2024. Two projects on Hawaii Island were disqualified on May 13, 2024. See “Transition to a decarbonized and sustainable energy future-Community-based renewable energy” for additional information.
•The Hawaii Island Stage 3 RFP, seeking 325 gigawatt-hours (GWh) per year of energy and 65 MW of renewable firm capacity, was issued on November 21, 2022. Proposals were received on April 20, 2023. The Stage 3 RFPs for Oahu and Maui opened for bids on January 20, 2023. For Oahu, the Utilities sought 500 to 700 MW of renewable firm capacity, and at least 965 GWh of renewable dispatchable energy annually. For Maui, the Utilities sought at least 40 MW of renewable firm capacity, and at least 425 GWh of renewable dispatchable energy annually. 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. Negotiations for the remaining projects are ongoing.
A summary of the Stage 3 PPAs is as follows:
Utilities Number of contracts
Total photovoltaic size (MW)
BESS Size (MW/MWh) Firm Generation (MW)
Hawaiian Electric
5 126
Hawaii Electric Light 3 86
Maui Electric 4 90 240 40
Total 12 302 1,124 407
A summary of the utility Stage 3 self-build project is as follows:
Utilities Number of projects
Firm Generation (MW)
Hawaiian Electric
1 253
Total 1 253
•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 589 GWh per year of energy and 270 MW of grid forming resources by December 2029, and 50 MW of renewable firm capacity by December 2032. The Hawaii Island portion of the IGP RFP seeks 134 GWh per year of energy by December 2029 and 60 MW of renewable firm capacity by December 2031. On January 9, 2025, the PUC issued an Order converting the docket into a contested case proceeding and opened a period for interested parties to move to intervene or participate.
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.
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 decision and order (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 create savings in fuel costs. The second amendment must be approved by the PUC to become effective. 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 are in negotiations with the bidders.
On March 3, 2022, as part of economic sanctions amid the Russia-Ukraine war, PAR Hawaii announced that it was suspending all purchases of Russian crude oil, which accounts for at least 25% of Hawaii’s supply. The Utilities are taking additional measure to ensure adequate supply of fuel by entering into a backup fuel supply contract with Vitol Inc. (Vitol) commencing on December 1, 2022 through June 30, 2025 with annual extensions if mutually agreed by both parties. The PUC issued the final D&O approving the Vitol backup fuels supply contract on December 1, 2022 and the costs incurred under the contract with Vitol are recovered in the Utilities’ respective ECRCs.
Liquidity and capital resources. As of December 31, 2024, 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). For the full year 2024, the Utilities incurred net losses of approximately $1.23 billion.
When preparing financial statements for each annual and interim reporting period, management has the responsibility to evaluate whether there are conditions or events, considered in the aggregate, that raise substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern within one year after the date that the financial statements are issued. In making their evaluation, the Utilities consider, among other things, risks and/or uncertainties related to their results of operations, contractual obligations, near-term debt maturities, dividend requirements, debt covenant compliance, or other factors impacting the Utilities’ liquidity and capital resources.
The Company previously concluded that as of June 30, 2024, conditions existed that raised substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern, and that while HEI and the Utilities were working with their financial advisors on a financing plan to raise the capital necessary to mitigate those conditions, there was no assurance that management’s plans would be successful. As a result, HEI and the Utilities disclosed in the condensed consolidated financial statements included in the Company’s Quarterly Report on Form 10-Q for the quarter ending June 30, 2024 there was substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern.
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 Sheet. 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 filed with the SEC an at-the-market (ATM) 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 and the Utilities’ current cash and cash equivalents balances, as of September 30, 2024, amounting to $677.7 million and $147.6 million, respectively, the available capacity on Hawaiian Electric’s ABL Facility (see Note 6 of the Consolidated Financial Statements), the additional liquidity from HEI’s recently registered ATM program, and expenditure reduction efforts, provided sufficient liquidity to alleviate the conditions that caused the substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern in the third quarter of 2024. As discussed in Note 2 of the Consolidated Financial Statements, HEI transferred the amount of the first payment, $479 million, into a new subsidiary, which
is restricted from disbursing such funds except in connection with the initial payments to the settlement funds. HEI expects to make this initial payment no earlier than the fourth quarter of 2025 and HEI and the Utilities have sufficient resources to fund their operations and satisfy their other obligations for the next 12 months following the issuances of their financial statements. The plans that have been implemented in the third quarter of 2024 have mitigated the conditions that previously caused the substantial doubt about HEI’s and the Utilities’ ability to continue as a going concern as of the date of filing their 2024 second quarter 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 (including recent litigation noted above).
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. Longer term, the Utilities entered into an asset-based credit facility that allows borrowing up to $250 million and are also evaluating other sources of liquidity that could include securitization, re-prioritizing capital spending and reducing O&M, issuing secured debt, and conducting asset sales, among others.
Although accounts receivable balances has been decreasing, it remains elevated coming out of the pandemic and has led to higher bad debt expense and higher write-offs in 2023 and 2024, following the end of the moratorium on disconnections. The higher bad debt expense is expected to continue until the Utilities return to pre-pandemic accounts receivable balances, along with a decrease in volume, for delinquent accounts. The Maui windstorm and wildfires have not and are not anticipated to materially impact accounts receivable, however, it has and will continue to lead to higher bad debt expense. As of December 31, 2024, approximately $18.3 million of the Utilities’ accounts receivables were over 30 days past due, which is a decrease of approximately 17% since December 2023. In addition to the cash flow impact from delayed collection of accounts receivable, lower kWh sales relative to the level of kWh sales approved in the last rate case generally result in delayed timing of cash flows, resulting in higher working capital requirements.
With the exception of Maui, the Utilities are continuing the disconnection process on a tiered basis, expanding the targeted balances, which is expected to reduce delinquent accounts receivable balances and accelerate cash collections. Service disconnections on Maui have been suspended through April 5, 2025, in accordance with the extension of Governor Josh Green’s emergency proclamation; however, efforts are ongoing to educate and inform customers impacted by the Maui windstorm and wildfires on the availability of financial assistance to manage delinquencies accordingly. See also “Regulatory assets and liabilities” in Note 4 of the Consolidated Financial Statements.
The rebuilding of Lahaina will be a community-led effort and will occur over an extended period of time. The cost of rebuilding the electric utility infrastructure is not yet known, but could be significant because the infrastructure that may be required is expected to be different than what previously existed. For example, to mitigate wildfire risk, grid hardening strategies, such as undergrounding of lines in high-risk locations will be significantly more expensive than using overhead lines and will thus result in increased costs.
At December 31, 2024, the Utilities’ total available liquidity was approximately $334 million. The following table provides the components of available liquidity at December 31, 2024.
As of December 31, 2024
(in millions)
Capacity
Outstanding
Undrawn
Unsecured revolving line of credit
$ 200 $ 166 $ 34
ABL Facility
239 - 239
Borrowing from HEI - standing commitment letter
75 - 75
Short-term credit facility
50 50 -
Total credit
$ 564 $ 216 348
Restricted credit
(198)
Total available credit1
Cash and cash equivalents
Total available liquidity
$ 334
1 Total undrawn credit amounts to $348 million; however, due to certain financial covenant requirements, the temporary available credit is limited to approximately $150 million. The Utilities subsequently paid off $47 million of long-term debt that became due on January 1, 2025, which would increase the total available credit to $200 million.
Additionally, as of December 31, 2024, Hawaiian Electric had no commercial paper outstanding, and Hawaii Electric Light and Maui Electric had short-term borrowings from Hawaiian Electric of nil and $62.2 million, respectively, which intercompany borrowings are eliminated in consolidation.
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 2024 2023
(dollars in millions)
Short-term borrowings, net $ 49 1 % $ - - %
Long-term debt, net 1,901 61 1,934 44
Preferred stock 34 1 34 1
Common stock equity 1,157 37 2,409 55
$ 3,141 100 % $ 4,377 100 %
As of December 31, 2024, the Utilities are in compliance with all applicable financial covenants. For the year ended December 31, 2024, the Utilities accrued liabilities related to wildfire tort-related claims totaling $1.92 billion. As a result, as of December 31, 2024 the amount of additional debt that the Utilities could incur will be temporarily limited to approximately $150 million due to certain financial covenants. The amount of additional debt that could be incurred by the Utilities will increase over time as earnings are generated or when HEI contributes equity related to the settlement payments or for capital expenditures. The Utilities believe that with the cash on hand, availability on the ABL Facility, and potential equity contributions from HEI, they have sufficient financial flexibility 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.
Prior to the Maui windstorm and wildfires, Hawaiian Electric utilized short-term debt, typically commercial paper, to support normal operations, to refinance short-term debt and for other temporary requirements. Hawaiian Electric may also borrow short-term from HEI for itself and on behalf of Hawaii Electric Light and Maui Electric, and Hawaiian Electric may borrow from or loan to Hawaii Electric Light and Maui Electric on a short-term basis. The intercompany borrowings among the Utilities, but not the borrowings from HEI, are eliminated in the consolidation of Hawaiian Electric’s financial statements. The Utilities also historically utilized long-term debt, borrowings of the proceeds of special purpose revenue bonds (SPRBs) issued by the State of Hawaii Department of Budget and Finance (DBF) and the issuance of privately placed unsecured senior notes bearing taxable interest, to finance the Utilities’ capital improvement projects, or to repay short-term borrowings used to finance such projects. The downgrades of Hawaiian Electric’s credit ratings will continue to adversely impact the Utilities’ ability to access capital markets and other sources of debt and equity financing, if at all, in a timely manner and on acceptable terms.
Credit ratings. On October 25, 2024, Fitch revised Hawaiian Electric’s outlook to “Stable” from “Watch Negative” and affirmed the “B” issuer credit rating. On November 22, 2024, S&P revised Hawaiian Electric’s outlook to “Negative” from “CreditWatch” and affirmed the “B-” issuer credit rating. As of February 14, 2025, the Fitch, Moody’s and S&P ratings of Hawaiian Electric were as follows:
Fitch Moody’s S&P
Long-term issuer default, long-term and issuer credit, respectively B Ba3
B-
Short-term issuer default, commercial paper and commercial paper, respectively
B NP B
Senior unsecured debt/special purpose revenue bonds B+ Ba3 *
Cumulative preferred stock (selected series) * B3 *
Outlook Stable
Stable
Negative
* Not rated.
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 capital markets and other sources of debt financing, if at all, in a timely manner and on acceptable terms. In addition, the downgrades of Hawaiian Electric’s credit ratings triggered certain cash or payment requirements with the Utilities’ vendors. However, the Utilities believe additional vendor collateral or payment requirements will not have a material impact on the Utilities’ liquidity.
Asset-based lending facility credit agreement. On May 17, 2024, Hawaiian Electric, through a special-purpose subsidiary, entered into an 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. The ABL Facility remains undrawn as of December 31, 2024.
Credit agreement. On August 23, 2023, Hawaiian Electric fully drew down $200 million on its existing revolving credit facilities. The cash proceeds were invested in highly liquid short-term investments and will be used for general corporate purposes. As of December 31, 2024, $166 million was outstanding on Hawaiian Electric’s revolving credit facility with $34 million remaining available borrowing capacity. See Note 6 of the Consolidated Financial Statements for additional information.
Taxable debt. On December 20, 2022, the Utilities received PUC approval to issue, over a four-year period from January 1, 2023 to December 31, 2026, unsecured obligations bearing taxable interest (Hawaiian Electric up to $230 million, Hawaii Electric Light up to $65 million and Maui Electric up to $105 million), to finance capital expenditures, repay long-term and/or short-term debt used to finance or refinance capital expenditures, and/or to reimburse funds used for payment of capital expenditures. Pursuant to the approval, on January 10, 2023, the Utilities executed through a private placement, $150 million in unsecured senior notes (2023 Notes). The 2023 Notes had a delayed draw feature and the Utilities drew down all the proceeds on February 9, 2023. See summary table below for remaining authorized amounts as of December 31, 2024 for each respective utility.
(in millions) Hawaiian Electric Hawaii Electric Light Maui Electric
Total “up to” amounts of taxable debt authorized from 2023 through 2026 $ 230 $ 65 $ 105
Less: taxable debt executed on January 10, 2023, but issued on February 9, 2023
100 25 25
Remaining authorized amounts $ 130 $ 40 $ 80
As of December 31, 2024, the Utilities have $1.9 billion of long-term debt, net, of which $47.0 million and $125.0 million are due within 12 and 24 months, respectively.
On January 17, 2025, the Utilities requested 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 capital expenditures, and/or to reimburse funds used for payment of capital expenditures. If approved, the Utilities would forgo the remaining authorized amounts noted in the table above. The Utilities requested PUC approval by July 31, 2025.
Equity. On December 20, 2022, the Utilities received PUC approval to issue and sell each utility’s common stock over a four-year period from January 1, 2023 through December 31, 2026 (Hawaiian Electric’s sale/s to HEI of up to $75 million, Hawaii Electric Light sale/s to Hawaiian Electric of up to $25 million, and Maui Electric sale/s to Hawaiian Electric of up to $55 million) and the purchase of Hawaii Electric Light and Maui Electric common stock by Hawaiian Electric from 2023 through December 31, 2026. As of December 31, 2024, Hawaiian Electric, Hawaii Electric Light, and Maui Electric have $75 million, $25 million, and nil, respectively, of unused common stock authorization.
On January 27, 2025, the Utilities requested 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 from 2025 through December 31, 2027. If approved, the Utilities would forgo the unused common stock authorization noted above. The Utilities requested PUC approval by October 31, 2025.
Cash flows. The following table reflects the changes in cash flows for the year ended December 31, 2024 compared to the year ended December 31, 2023:
Years ended December 31
(in thousands) 2024 2023 Change
Net cash provided by operating activities $ 465,733 $ 474,367 $ (8,634)
Net cash used in investing activities (317,631) (432,599) 114,968
Net cash provided by (used in) financing activities (72,031) 27,067 (99,098)
Net cash provided by operating activities: The decrease in net cash provided by operating activities was primarily driven by higher vendor payments, higher income taxes paid, partially offset by higher insurance proceeds received in 2024.
Net cash used in investing activities: The decrease in net cash used in investing activities was primarily driven by a decrease in capital expenditures related to construction activities.
Net cash used in financing activities: The decrease in net cash provided by financing activities was driven by lower net cash from long-term and short-term borrowings due to fully drawing on the $200 million revolving credit facilities in August 2023.
For a discussion of 2022 operating, investing and financing activities, please refer to the “Liquidity and capital resources” section in Item 7, “Management Discussion and Analysis of Financial Condition and Results of Operations-Electric utility,” in the Company’s 2023 Form 10-K.
Material cash requirements. Material cash requirements of the Utilities include payments related to settlement of tort-related legal claims and cross claims, legal and consulting costs related to the Maui windstorm and wildfires (see further information in Note 2 of the 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 capital markets and other sources of debt and equity financing, if at all, in a timely manner and on acceptable terms. 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 earlier than the fourth quarter of 2025. 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 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. The following table presents aggregated information about total payments due from the Utilities during the indicated periods under the specified contractual obligations and commitments:
December 31, 2024 Payments due by period
(in millions) 2025
2026 2027
2028 2029
After
five years
Total
Short-term borrowings $ 49 $ - $ - $ - $ - $ - $ 49
Long-term debt 47 125 266 68 35 1,367 1,908
Interest on short-term loan and long-term debt
89 83 73 63 61 623 992
Settlement Agreements
479 479 479 478 - - 1,915
Operating and finance leases
PPAs classified as leases 50 50 50 45 45 672 912
Other leases 12 12 6 5 5 16 56
Open purchase order obligations 1
191 163 41 14 6 23 438
Fuel oil purchase obligations (estimate based on fuel oil price at December 31) 5 - - - - - 5
Purchase power obligations-minimum fixed capacity charges not classified as leases 101 102 106 105 105 800 1,319
Liabilities for uncertain tax positions - - 1 - - - 1
Total (estimated) $ 1,023 $ 1,014 $ 1,022 $ 778 $ 257 $ 3,501 $ 7,595
1 Includes 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, 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, 2024, the fair value of the assets held in trusts to satisfy the obligations of the Utilities’ retirement benefit plans did not exceed 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 retirement benefit plan obligations and estimated contributions for 2025.
See “Biofuel sources” in the “Developments in renewable energy efforts” section above for additional information for fuel oil purchase obligation. See Notes 4 and 9 of the Consolidated Financial Statements for a discussion of power purchase commitments and operating leases obligations, respectively.
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, which remains pending with the PUC.
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 clean energy and decarbonized goals, while ensuring reliability and resilience as the Utilities adapt to a changing climate. Technologies that the Utilities are evaluating include the commercial development of advanced protection schemes that would monitor, detect, and isolate falling overhead distribution and transmission lines to reduce wildfire risks and improve public/
employee safety, 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 start to utilize 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, 2024, the consolidated regulatory liabilities and regulatory assets of the Utilities amounted to $1,244 million and $281 million, respectively, compared to $1,151 million and $295 million as of December 31, 2023, respectively. Regulatory liabilities and regulatory assets are 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, 2024 and December 31, 2023, the Utilities’ AROs totaled $12.5 million and $12.0 million, respectively.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
HEI and Hawaiian Electric (in the case of Hawaiian Electric, only the information related to Hawaiian Electric and its subsidiaries is applicable):
The Company manages various market risks in the ordinary course of business, including credit risk and liquidity risk. The Company believes the electric utility and the “All Other” segment’s exposures to these two risks were not material as of December 31, 2024.
The Utilities are exposed to some commodity price risk primarily related to their fuel supply and IPP contracts. The Utilities’ commodity price risk is substantially mitigated so long as they have their current ECRCs in their rate schedules, but have limited exposure through the fuel cost risk-sharing mechanism, which apportions 2% of the fuel cost risk to the utilities
(and 98% to ratepayers) and has a maximum exposure (or benefit) of $3.7 million. The Utilities currently have no hedges against its commodity price risk.
The Company currently has no direct exposure to market risk from trading activities nor foreign currency exchange rate risk.
The Company considers interest rate risk to be a very significant market risk as it could potentially have a significant effect on the Company’s results of operations, financial condition and liquidity, but also as it may affect the discount rate used to determine retirement benefit liabilities and minimum contributions, the market value of retirement benefit plans’ assets, borrowing costs and the Utilities’ allowed rates of return. Interest rate risk can be defined as the exposure of the Company’s earnings to adverse movements in interest rates.
Interest rate risk
The Company’s general policy is to manage interest rate risk through use of a combination of short-term debt, long-term debt and preferred securities. As of December 31, 2024, the Company was exposed to interest rate risk because of its restricted access to capital markets and other sources of debt and equity financings, including the impact of interest rates on the revolving credit facility draws, the impact of interest rates on the discount rate and the market value of plan assets used to determine retirement benefits expenses and obligations (see “Pension and other postretirement benefits obligations” in HEI’s MD&A and “Retirement benefits” in Notes 1 and 11 of the Consolidated Financial Statements) and the possible effect of interest rates on the electric utilities’ allowed rates of return. Other than these exposures, management believes its exposure to interest rate risk is not material. However, continued restricted access to capital markets and other sources of debt and equity financings for an extended period of time may adversely impact the Company’s financial condition, liquidity, cash flows and results of operations. The Company’s long-term debt, in the form of borrowings of proceeds of revenue bonds, privately-placed senior notes and bank term loans, is predominately at fixed rates (see Note 17 of the Consolidated Financial Statements for the fair value of long-term debt, net).

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
HEI and Hawaiian Electric:
Index to Consolidated Financial Statements Page
Reports of Independent Registered Public Accounting Firms (PCAOB ID No. 34) - HEI
Reports of Independent Registered Public Accounting Firms (PCAOB ID No. 34) - Hawaiian Electric
Consolidated Financial Statements
HEI
Consolidated Statements of Income for the years ended December 31, 2024, 2023 and 2022
Consolidated Statements of Comprehensive Income for the years ended December 31, 2024, 2023 and 2022
Consolidated Balance Sheets at December 31, 2024 and 2023
Consolidated Statements of Changes in Shareholders’ Equity for the years ended December 31, 2024, 2023 and 2022
Consolidated Statements of Cash Flows for the years ended December 31, 2024, 2023 and 2022
Hawaiian Electric
Consolidated Statements of Income for the years ended December 31, 2024, 2023 and 2022
Consolidated Statements of Comprehensive Income for the years ended December 31, 2024, 2023 and 2022
Consolidated Balance Sheets at December 31, 2024 and 2023
Consolidated Statements of Capitalization at December 31, 2024 and 2023
Consolidated Statements of Changes in Common Stock Equity for the years ended December 31, 2024, 2023 and 2022
Consolidated Statements of Cash Flows for the years ended December 31, 2024, 2023 and 2022
Notes to Consolidated Financial Statements 86
Report of Independent Registered Public Accounting Firm
To the shareholders and the Board of Directors of Hawaiian Electric Industries, Inc.
Opinions on the Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Hawaiian Electric Industries, Inc. and subsidiaries (the “Company”) as of December 31, 2024 and 2023, the related consolidated statements of income, comprehensive income, changes in shareholders' equity, and cash flows, for each of the three years in the period ended December 31, 2024, and the related notes and the schedules listed in the Index at Item 15(a)(2) (collectively referred to as the “financial statements”). We also have audited the Company’s internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024, in conformity with accounting principles generally accepted in the United States of America. Also, in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2024, based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO.
Emphasis of Matter
As discussed in Notes 1 and 5 to the financial statements, the financial statements have been retrospectively adjusted for discontinued operations of American Savings Bank, F.S.B.
Basis for Opinions
The Company’s management is responsible for these financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Annual Report on Internal Control over Financial Reporting. Our responsibility is to express an opinion on these financial statements and an opinion on the Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material respects.
Our audits of the financial statements included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures to respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control over Financial Reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Electric Utility Segment - Certain Regulatory Assets and Liabilities - Refer to Notes 1 and 4 to the financial statements
Critical Audit Matter Description
Hawaiian Electric Company, Inc. (“Hawaiian Electric” or the “Utility”) is subject to rate regulation by the Hawaii Public Utility Commission (the “PUC”) and accounts for the effects of regulation under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 980, “Regulated Operations,” as management believes that the operations of the Utility satisfy the criteria for regulatory accounting. The Company’s continued accounting under ASC Topic 980 generally requires that rates are established by an independent, third-party regulator; rates are designed to recover the costs of providing service; and it is reasonable to assume that rates can be charged to, and collected from, customers.
Hawaiian Electric’s rates are subject to regulatory rate-setting processes and earnings oversight. Rates are determined and approved in regulatory proceedings based on an analysis of the Utility’s costs to provide utility service and a return on, and recovery of, Hawaiian Electric’s investment in the utility business.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management to support its assertions about the applicability of the specialized rules and to evaluate the likelihood of (1) recovery in future rates of certain incurred costs and (2) the refund to customers of certain amounts. Performing audit procedures related to these judgments required significant auditor judgement and specialized knowledge.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the application of specialized rules to account for rate regulation included the following, among others:
•We tested the effectiveness of management’s controls over (1) the evaluation of the application of specialized rules to account for rate regulation and (2) for certain regulatory assets and liabilities the evaluation of the likelihood of (a) the recovery in future rates of costs deferred as regulatory assets and (b) refunds to customers reported as regulatory liabilities.
•We evaluated the Company’s conclusion that it should apply the specialized rules to account for the effects of rate regulation.
•We evaluated the Company’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory developments.
•We read relevant regulatory orders issued by the PUC for the Utility to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the PUC’s treatment of similar costs under similar circumstances.
•For certain regulatory assets and liabilities we evaluated whether the amounts recorded were in accordance with ASC Topic 980.
Contingencies - Tort-Related Legal Claims - Refer to Notes 1 and 2 to the financial statements
Critical Audit Matter Description
Multiple civil and class action lawsuits (collectively the “tort-related legal claims”) have been filed against the Company, its subsidiaries, and other defendants related to a number of brush fires that occurred on August 8, 2023, on the island of Maui. Most of these lawsuits allege that the defendants were responsible for, and/or negligent in failing to prevent or respond to the wildfires that led to the property destruction and loss of life. Other claims include, among other things, personal injury, wrongful death, emotional distress and inverse condemnation.
The Company reviews loss contingencies at least quarterly. When a loss is probable and reasonably estimable, a liability is recorded in the amount of the estimable loss. If it is reasonably possible that a loss may have been incurred and the effect on the financial statements could be material, the Company discloses the nature of the loss contingency and an estimate of the possible loss or range of loss or a statement that such an estimate cannot be made within the notes to the financial statements.
We identified the evaluation of the loss contingencies related to the tort-related legal claims, and related disclosures, as a critical audit matter because auditing management’s judgments in determining the appropriate accounting and disclosures for the tort-related legal claims required significant auditor judgment.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the loss contingency involving the tort-related legal claims included the following, among others:
•We obtained an understanding, evaluated the design, and tested the operating effectiveness of internal controls over management’s evaluation of the tort-related legal claims, including controls related to the Company's assessment of the probability of loss, measurement and classification of the contingent liability, and related disclosures based on the facts and circumstances.
•We inquired of the Company’s management and internal and external legal counsel to understand the nature and status of the tort-related legal claims and the status of the settlement agreements described in Note 2 to the Consolidated Financial Statements.
•We read the settlement agreements regarding the tort-related legal claims.
•We requested written responses from internal and external counsel regarding (1) a description of the nature of the tort-related legal claims, (2) progress of the tort-related legal claims, (3) the status of the Company’s response, and (4) an evaluation of the likelihood of an unfavorable outcome and an estimate, if one can be made, of the amount of range of potential loss, and received written responses.
•We evaluated management’s measurement of the recorded loss contingency for the tort-related legal claims and the balance sheet classification of that liability in the Consolidated Balance Sheets.
•We consulted with professionals in our firm with expertise related to accounting for loss contingencies.
•We evaluated any events subsequent to December 31, 2024, that might impact our evaluation of the tort-related claims loss contingency.
•We obtained written representations from executives of the Company.
•We read the Company’s related disclosures and evaluated them for consistency with the evidence obtained from our audit procedures.
/s/ Deloitte & Touche LLP
Honolulu, Hawaii
February 24, 2025
We have served as the Company’s auditor since 2017.
Report of Independent Registered Public Accounting Firm
To the shareholder and the Board of Directors of Hawaiian Electric Company, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets and statements of capitalization of Hawaiian Electric Company, Inc. and subsidiaries (the “Company”) as of December 31, 2024 and 2023, the related consolidated statements of income, comprehensive income, changes in common stock equity, and cash flows, for each of the three years in the period ended December 31, 2024, and the related notes and the schedules listed in the Index at Item 15(a)(2) (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2024 and 2023, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2024, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matters
The critical audit matters communicated below are matters arising from the current-period audit of the financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.
Certain Regulatory Assets and Liabilities - Refer to Notes 1 and 4 to the financial statements
Critical Audit Matter Description
The Company is subject to rate regulation by the Hawaii Public Utility Commission (the “PUC”) and accounts for the effects of regulation under Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) Topic 980, “Regulated Operations,” as management believes that the operations of the Company satisfy the criteria for regulatory accounting. The Company’s continued accounting under ASC Topic 980 generally requires that rates are established by an independent, third-party regulator; rates are designed to recover the costs of providing service; and it is reasonable to assume that rates can be charged to, and collected from, customers.
The Company’s rates are subject to regulatory rate-setting processes and earnings oversight. Rates are determined and approved in regulatory proceedings based on an analysis of the Company’s costs to provide utility service and a return on, and recovery of, the Company’s investment in the utility business.
We identified the impact of rate regulation as a critical audit matter due to the significant judgments made by management to support its assertions about the applicability of the specialized rules and to evaluate the likelihood of (1) recovery in future rates
of certain incurred costs and (2) the refund to customers of certain amounts. Performing audit procedures related to these judgments required significant auditor judgement and specialized knowledge.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the application of specialized rules to account for rate regulation included the following, among others:
•We tested the effectiveness of management’s controls over (1) the evaluation of the application of specialized rules to account for rate regulation and (2) for certain regulatory assets and liabilities the evaluation of the likelihood of (a) the recovery in future rates of costs deferred as regulatory assets and (b) refunds to customers reported as regulatory liabilities.
•We evaluated the Company’s conclusion that it should apply the specialized rules to account for the effects of rate regulation.
•We evaluated the Company’s disclosures related to the impacts of rate regulation, including the balances recorded and regulatory developments.
•We read relevant regulatory orders issued by the PUC for the Company to assess the likelihood of recovery in future rates or of a future reduction in rates based on precedents of the PUC’s treatment of similar costs under similar circumstances.
•For certain regulatory assets and liabilities we evaluated whether the amounts recorded were in accordance with ASC Topic 980.
Contingencies - Tort-Related Legal Claims - Refer to Notes 1 and 2 to the financial statements
Critical Audit Matter Description
Multiple civil and class action lawsuits (collectively the “tort-related legal claims”) have been filed against the Company, its subsidiaries, and other defendants related to a number of brush fires that occurred on August 8, 2023, on the island of Maui. Most of these lawsuits allege that the defendants were responsible for, and/or negligent in failing to prevent or respond to the wildfires that led to the property destruction and loss of life. Other claims include, among other things, personal injury, wrongful death, emotional distress and inverse condemnation.
The Company reviews loss contingencies at least quarterly. When a loss is probable and reasonably estimable, a liability is recorded in the amount of the estimable loss. If it is reasonably possible that a loss may have been incurred and the effect on the financial statements could be material, the Company discloses the nature of the loss contingency and an estimate of the possible loss or range of loss or a statement that such an estimate cannot be made within the notes to the financial statements.
We identified the evaluation of the loss contingencies related to the tort-related legal claims, and related disclosures, as a critical audit matter because auditing management’s judgments in determining the appropriate accounting and disclosures for the tort-related legal claims required significant auditor judgment.
How the Critical Audit Matter Was Addressed in the Audit
Our audit procedures related to the loss contingency involving the tort-related legal claims included the following, among others:
•We obtained an understanding, evaluated the design and tested the operating effectiveness of internal controls over management’s evaluation of the tort-related legal claims, including controls related to the Company's assessment of the probability of loss, measurement and classification of the contingent liability, and related disclosures based on the facts and circumstances.
•We inquired of the Company’s management and internal and external legal counsel to understand the nature and status of the tort-related legal claims and the status of the settlement agreements described in Note 2 to the Consolidated Financial Statements.
•We read the settlement agreements regarding the tort-related legal claims.
•We requested written responses from internal and external counsel regarding (1) a description of the nature of the tort-related legal claims, (2) progress of the tort-related legal claims, (3) the status of the Company’s response, and (4) an evaluation of the likelihood of an unfavorable outcome and an estimate, if one can be made, of the amount of range of potential loss, and received written responses.
•We evaluated management’s measurement of the recorded loss contingency for the tort-related legal claims and the balance sheet classification of that liability in the Consolidated Balance Sheets.
•We consulted with professionals in our firm with expertise related to accounting for loss contingencies.
•We evaluated any events subsequent to December 31, 2024, that might impact our evaluation of the tort-related claims loss contingency.
•We obtained written representations from executives of the Company.
•We read the Company’s related disclosures and evaluated them for consistency with the evidence obtained from our audit procedures.
/s/ Deloitte & Touche LLP
Honolulu, Hawaii
February 24, 2025
We have served as the Company’s auditor since 2017.
Consolidated Statements of Income
Hawaiian Electric Industries, Inc. and Subsidiaries
Years ended December 31 2024 2023 2022
(in thousands, except per share amounts)
Revenues
Electric utility $ 3,206,700 $ 3,269,521 $ 3,408,587
Other 13,150 17,982 12,330
Total revenues 3,219,850 3,287,503 3,420,917
Expenses
Electric utility (includes $1,875 million of provision, net, for Wildfire tort-related claims recorded in 2024) (Note 2)
4,818,558 2,967,363 3,109,396
Other (includes $35 million of impairment recorded in 2024) (Note 3)
108,052 45,148 31,966
Total expenses 4,926,610 3,012,511 3,141,362
Operating income (loss)
Electric utility (1,611,858) 302,158 299,191
Other (94,902) (27,166) (19,636)
Total operating income (loss) (1,706,760) 274,992 279,555
Retirement defined benefits credit-other than service costs 3,754 4,014 3,688
Interest expense, net
(127,207) (125,532) (103,402)
Allowance for borrowed funds used during construction 5,470 5,201 3,416
Allowance for equity funds used during construction 13,786 15,164 10,574
Interest income 19,362 9,105 -
Gain (loss) on sales of equity-method investments
- (644) 8,123
Income (loss) from continuing operations before income taxes
(1,791,595) 182,300 201,954
Income tax expense (benefit) (470,962) 34,534 38,915
Income (loss) from continuing operations
(1,320,633) 147,766 163,039
Preferred stock dividends of subsidiaries 1,890 1,890 1,890
Income (loss) from continuing operations for common stock
(1,322,523) 145,876 161,149
Income (loss) from discontinued operations
(103,486) 53,362 79,989
Net income (loss) for common stock
$ (1,426,009) $ 199,238 $ 241,138
Continuing operations - Basic earnings (loss) per common share
$ (10.42) $ 1.33 $ 1.47
Discontinued operations - Basic earnings (loss) per common share
(0.81) 0.49 0.73
Basic earnings (loss) per common share $ (11.23) $ 1.82 $ 2.20
Continuing operations - Diluted earnings (loss) per common share
$ (10.42) $ 1.33 $ 1.47
Discontinued operations - Diluted earnings (loss) per common share
(0.81) 0.48 0.73
Diluted earnings (loss) per common share $ (11.23) $ 1.81 $ 2.20
Weighted-average number of common shares outstanding 126,927 109,739 109,434
Net effect of potentially dilutive shares (share-based compensation programs) - 299 344
Weighted-average shares assuming dilution 126,927 110,038 109,778
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Comprehensive Income
Hawaiian Electric Industries, Inc. and Subsidiaries
Years ended December 31 2024 2023 2022
(in thousands)
Net income (loss) for common stock
$ (1,426,009) $ 199,238 $ 241,138
Other comprehensive income (loss), net of taxes:
Net unrealized gains (losses) on available-for sale investment securities:
Net unrealized gains (losses) on available-for sale investment securities arising during the period, net of taxes of $(4,110), $7,536 and $(110,140) for 2024, 2023 and 2022, respectively
(11,227) 20,589 (300,860)
Reclassification adjustment for net realized losses included in net income, net of taxes of nil, $4,011 and nil for 2024, 2023 and 2022, respectively
- 10,954 -
Amortization of unrealized holding losses on held-to-maturity securities, net of taxes of $4,764, $5,271 and $1,462 for 2024, 2023 and 2022, respectively
13,012 14,398 3,993
Derivatives qualified as cash flow hedges:
Unrealized interest rate hedging gains (losses), net of taxes of $237, $(58) and $1,892 for 2024, 2023 and 2022, respectively
683 (167) 5,457
Reclassification adjustment to net income, net of taxes of $(70), $(65) and $60 for 2024, 2023 and 2022, respectively
(201) (186) 172
Retirement benefit plans:
Net gains arising during the period, net of taxes of $23,015, $3,778 and $65,174 for 2024, 2023 and 2022, respectively
66,355 10,854 188,020
Adjustment for amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost, net of taxes of $(597), $(535) and $6,820 for 2024, 2023 and 2022, respectively
(1,730) (1,560) 19,659
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $(22,096), $(2,846) and $(69,345) for 2024, 2023 and 2022, respectively
(63,708) (8,204) (199,936)
Other comprehensive income (loss), net of taxes 3,184 46,678 (283,495)
Comprehensive income (loss) attributable to Hawaiian Electric Industries, Inc. $ (1,422,825) $ 245,916 $ (42,357)
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Balance Sheets
Hawaiian Electric Industries, Inc. and Subsidiaries
December 31 2024 2023
(in thousands)
ASSETS
Current assets:
Cash and cash equivalents $ 750,535 $ 244,091
Restricted cash 492,317 15,028
Accounts receivable and unbilled revenues, net 457,171 546,704
Regulatory assets 53,895 68,453
Other 380,408 331,617
Total current assets
2,134,326 1,205,893
Noncurrent assets:
Property, plant and equipment, net
Land $ 63,537 $ 69,078
Plant and equipment 8,634,124 8,471,775
Right-of-use assets - finance lease 448,527 342,834
Construction in progress 366,412 320,225
9,512,600 9,203,912
Less - accumulated depreciation (3,378,282) 6,134,318 (3,240,828) 5,963,084
Operating lease right-of-use assets 66,553 79,686
Regulatory assets 227,424 226,351
Other 368,795 202,358
Total noncurrent assets
6,797,090 6,471,479
Assets of discontinued operations
- 9,566,449
Total assets $ 8,931,416 $ 17,243,821
(Continued)
Consolidated Balance Sheets (continued)
Hawaiian Electric Industries, Inc. and Subsidiaries
December 31 2024 2023
(in thousands)
LIABILITIES AND SHAREHOLDERS’ EQUITY
Current liabilities:
Accounts payable $ 203,452 $ 198,885
Interest and dividends payable 27,203 28,354
Short-term borrowings
48,623 -
Current portion of long-term debt, net
109,171 16,496
Regulatory liabilities 26,568 36,559
Wildfire tort-related claims (Note 2)
478,750 75,000
Other 430,824 403,414
Total current liabilities
1,324,591 758,708
Noncurrent liabilities:
Long-term debt, net
2,690,387 2,825,933
Deferred income taxes - 402,246
Operating lease liabilities 56,523 69,972
Finance lease liabilities 426,598 331,262
Regulatory liabilities 1,217,515 1,114,131
Defined benefit plans liability
23,213 78,200
Wildfire tort-related claims (Note 2)
1,436,250 -
Other 242,957 247,637
Total noncurrent liabilities
6,093,443 5,069,381
Liabilities of discontinued operations
- 9,036,598
Total liabilities 7,418,034 14,864,687
Preferred stock of subsidiaries - not subject to mandatory redemption 34,293 34,293
Commitments and contingencies (Notes 2 and 4)
Shareholders’ equity
Preferred stock, no par value, authorized 10,000,000 shares; issued: none
- -
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding: 172,465,608 shares and 110,151,798 shares at December 31, 2024 and 2023, respectively
2,264,544 1,707,471
Retained earnings (788,916) 926,720
Accumulated other comprehensive income (loss), net of taxes
Net unrealized losses on securities $ - $ (282,963)
Unrealized gains on derivatives 2,120 1,638
Retirement benefit plans 1,341 3,461 (8,025) (289,350)
Total shareholders’ equity 1,479,089 2,344,841
Total liabilities and shareholders’ equity $ 8,931,416 $ 17,243,821
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Changes in Shareholders’ Equity
Hawaiian Electric Industries, Inc. and Subsidiaries
Common stock Retained
earnings
(deficit) Accumulated
other
comprehensive
income (loss)
(in thousands, except per share amounts) Shares Amount Total
Balance, December 31, 2021 109,312 $ 1,685,496 $ 757,921 $ (52,533) $ 2,390,884
Net income for common stock - - 241,138 - 241,138
Other comprehensive loss, net of tax benefits - - - (283,495) (283,495)
Issuance of common stock:
Share-based plans 159 5,831 - - 5,831
Share-based expenses and other, net - 1,370 - - 1,370
Common stock dividends ($1.40 per share)
- - (153,229) - (153,229)
Balance, December 31, 2022 109,471 1,692,697 845,830 (336,028) 2,202,499
Net income for common stock - - 199,238 - 199,238
Other comprehensive income, net of taxes - - - 46,678 46,678
Issuance of common stock:
Dividend reinvestment and stock purchase plan 537 6,612 - - 6,612
Share-based plans 144 6,371 - - 6,371
Share-based expenses and other, net - 1,791 - - 1,791
Common stock dividends ($1.08 per share)
- - (118,348) - (118,348)
Balance, December 31, 2023 110,152 1,707,471 926,720 (289,350) 2,344,841
Net loss for common stock - - (1,426,009) - (1,426,009)
Other comprehensive income, net of taxes
- - - 3,184 3,184
Issuance of common stock:
Common stock offering 62,162 575,000 - - 575,000
Share-based plans 152 8,018 - - 8,018
Common stock offering expenses
- (18,621) - - (18,621)
Share-based expenses and other, net - (7,324) - - (7,324)
Discontinued operations
- - (289,627) 289,627 -
Balance, December 31, 2024 172,466 $ 2,264,544 $ (788,916) $ 3,461 $ 1,479,089
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Cash Flows
Hawaiian Electric Industries, Inc. and Subsidiaries
Years ended December 31 2024 2023 2022
(in thousands)
Cash flows from operating activities
Net income (loss) $ (1,424,119) $ 201,128 $ 243,028
Adjustments to reconcile net income (loss) to net cash provided by operating activities-continuing operations
Loss (income) from discontinued operations 103,486 (53,362) (79,989)
Depreciation of property, plant and equipment 261,701 254,990 244,477
Other amortization 31,832 27,316 25,928
Loss (gains) on sale of equity-method investment
- 644 (8,123)
Deferred income tax expense (benefit)
(486,188) 9,352 (33,157)
Share-based compensation expense 3,591 6,776 7,450
Allowance for equity funds used during construction (13,786) (15,164) (10,574)
Asset impairment 39,642 - -
Other (13,790) (2,989) (5,323)
Changes in assets and liabilities
Decrease (increase) in accounts receivable and unbilled revenues, net 96,700 (71,643) (147,327)
Decrease (increase) in fuel oil stock 49,361 43,388 (87,569)
Increase in materials and supplies
(4,177) (34,887) (7,960)
Decrease (increase) in regulatory assets (22,743) (10,613) 34,600
Increase in regulatory liabilities
48,433 54,470 44,888
Increase in accounts, interest and dividends payable
6,862 34,290 23,083
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes (25,525) (9,858) 120,738
Change in defined benefit pension and other postretirement benefit plans asset/liability
(9,358) (8,215) (4,564)
Increase in wildfire tort-related claims
1,840,000 75,000 -
Change in other assets and liabilities, net (53,812) (57,255) (25,924)
Net cash provided by operating activities-continuing operations
428,110 443,368 333,682
Net cash provided by operating activities-discontinued operations
59,371 108,103 120,794
Net cash provided by operating activities 487,481 551,471 454,476
Cash flows from investing activities
Capital expenditures (344,251) (442,727) (339,333)
Acquisition of business - - (25,706)
Other, net 10,330 6,558 14,184
Net cash used in investing activities-continuing operations
(333,921) (436,169) (350,855)
Net cash provided by (used in) investing activities-discontinued operations
592,239 178,770 (777,827)
Net cash provided by (used in) investing activities
$ 258,318 $ (257,399) $ (1,128,682)
(continued)
Consolidated Statements of Cash Flows (continued)
Hawaiian Electric Industries, Inc. and Subsidiaries
Years ended December 31 2024 2023 2022
Cash flows from financing activities
Net increase (decrease) in short-term borrowings with original maturities of three months or less
$ - $ (137,650) $ 83,652
Proceeds from issuance of short-term debt 50,000 65,000 35,000
Repayment of short-term debt - (100,000) -
Proceeds from issuance of long-term debt 5,475 625,000 227,312
Repayment of long-term debt and funds transferred for repayment of long-term debt
(97,698) (167,080) (221,910)
Withheld shares for employee taxes on vested share-based compensation (1,074) (2,371) (3,165)
Net proceeds from issuance of common stock 556,612 1,223 -
Common stock dividends - (73,957) (111,229)
Preferred stock dividends of subsidiaries (1,890) (1,890) (1,890)
Other (13,867) (5,133) (2,041)
Net cash provided by financing activities-continuing operations
497,558 203,142 5,729
Net cash provided by (used in) financing activities-discontinued operations
(342,853) (7,567) 561,942
Net cash provided by financing activities 154,705 195,575 567,671
Net increase (decrease) in cash, cash equivalents and restricted cash, including cash from discontinued operations
900,504 489,647 (106,535)
Cash, cash equivalents and restricted cash, including cash from discontinued operations, January 1
694,574 204,927 311,462
Cash, cash equivalents and restricted cash, including cash from discontinued operations, December 31
1,595,078 694,574 204,927
Less: Restricted cash (492,317) (15,028) (5,050)
Less: Cash from discontinued operations
(352,226) (435,455) (156,149)
Cash and cash equivalents from continuing operations, December 31
$ 750,535 $ 244,091 $ 43,728
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Income
Hawaiian Electric Company, Inc. and Subsidiaries
Years ended December 31 2024 2023 2022
(in thousands)
Revenues $ 3,206,700 $ 3,269,521 $ 3,408,587
Expenses
Fuel oil 1,078,045 1,211,420 1,265,614
Purchased power 703,371 671,769 793,584
Other operation and maintenance 609,672 533,557 497,601
Wildfire tort-related claims, net (Note 2)
1,875,000 - -
Depreciation 251,142 243,705 235,424
Taxes, other than income taxes 301,328 306,912 317,173
Total expenses 4,818,558 2,967,363 3,109,396
Operating income (loss) (1,611,858) 302,158 299,191
Allowance for equity funds used during construction 13,786 15,164 10,574
Retirement defined benefits credit-other than service costs
4,137 4,303 3,835
Interest expense and other charges, net (82,082) (86,140) (76,416)
Allowance for borrowed funds used during construction 5,470 5,201 3,416
Interest income
6,633 6,454 -
Income (loss) before income taxes (1,663,914) 247,140 240,600
Income tax expense (benefit) (439,547) 51,193 49,676
Net income (loss) (1,224,367) 195,947 190,924
Preferred stock dividends of subsidiaries 915 915 915
Net income (loss) attributable to Hawaiian Electric (1,225,282) 195,032 190,009
Preferred stock dividends of Hawaiian Electric 1,080 1,080 1,080
Net income (loss) for common stock $ (1,226,362) $ 193,952 $ 188,929
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Comprehensive Income
Hawaiian Electric Company, Inc. and Subsidiaries
Years ended December 31 2024 2023 2022
(in thousands)
Net income (loss) for common stock $ (1,226,362) $ 193,952 $ 188,929
Other comprehensive income (loss), net of taxes:
Retirement benefit plans:
Net gains arising during the period, net of taxes of $22,780, $3,529 and $64,925 for 2024, 2023 and 2022, respectively
65,680 10,175 187,193
Adjustment for amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost, net of taxes of $(706), $(688) and $6,550 for 2024, 2023 and 2022, respectively
(2,035) (1,983) 18,884
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $(22,096), $(2,846), and $(69,345) for 2024, 2023 and 2022, respectively
(63,708) (8,204) (199,936)
Other comprehensive income (loss), net of taxes (63) (12) 6,141
Comprehensive income (loss) attributable to Hawaiian Electric Company, Inc. $ (1,226,425) $ 193,940 $ 195,070
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Balance Sheets
Hawaiian Electric Company, Inc. and Subsidiaries
December 31 2024 2023
(in thousands)
Assets
Property, plant and equipment
Utility property, plant and equipment
Land $ 52,019 $ 52,098
Plant and equipment 8,421,501 8,232,810
Right-of-use assets - finance lease 447,101 342,174
Less accumulated depreciation (3,326,624) (3,197,514)
Construction in progress 365,709 320,223
Utility property, plant and equipment, net 5,959,706 5,749,791
Nonutility property, plant and equipment, less accumulated depreciation of $1 and $40 as of December 31, 2024 and 2023, respectively
2,792 6,942
Total property, plant and equipment, net 5,962,498 5,756,733
Current assets
Cash and cash equivalents 184,148 106,077
Restricted cash - 2,000
Customer accounts receivable, net 199,898 244,309
Accrued unbilled revenues, net 178,721 185,644
Other accounts receivable, net 69,637 111,519
Fuel oil stock, at average cost 98,903 148,237
Materials and supplies, at average cost 118,466 114,433
Prepayments and other 151,220 58,491
Regulatory assets 53,895 68,453
Total current assets 1,054,888 1,039,163
Other long-term assets
Operating lease right-of-use-assets 59,281 71,877
Regulatory assets 227,424 226,351
Defined benefit pension and other postretirement benefit plans asset
108,819 67,568
Other 200,694 121,862
Total other long-term assets 596,218 487,658
Total assets
$ 7,613,604 $ 7,283,554
(Continued)
Consolidated Balance Sheets (continued)
Hawaiian Electric Company, Inc. and Subsidiaries
December 31 2024 2023
(in thousands)
Capitalization and liabilities
Capitalization (see Consolidated Statements of Capitalization)
Common stock equity $ 1,156,955 $ 2,409,110
Cumulative preferred stock - not subject to mandatory redemption 34,293 34,293
Commitments and contingencies (Note 4)
Long-term debt, net 1,854,214 1,934,277
Total capitalization 3,045,462 4,377,680
Current liabilities
Current portion of operating lease liabilities 15,202 16,617
Current portion of long-term debt, net 47,000 -
Short-term borrowings from non-affiliate 48,623 -
Accounts payable 196,980 191,040
Interest and preferred dividends payable 21,536 22,882
Taxes accrued, including revenue taxes 272,001 291,942
Regulatory liabilities 26,568 36,559
Wildfire tort-related claims (Note 2) 478,750 75,000
Other 121,011 96,436
Total current liabilities 1,227,671 730,476
Deferred credits and other liabilities
Operating lease liabilities 49,135 62,098
Finance lease liabilities 425,625 330,978
Deferred income taxes - 399,001
Regulatory liabilities 1,217,515 1,114,131
Unamortized tax credits 76,676 84,312
Defined benefit plans liability
6,428 60,671
Wildfire tort-related claims (Note 2) 1,436,250 -
Other 128,842 124,207
Total deferred credits and other liabilities 3,340,471 2,175,398
Total capitalization and liabilities
$ 7,613,604 $ 7,283,554
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Capitalization
Hawaiian Electric Company, Inc. and Subsidiaries
December 31 2024 2023
(dollars in thousands, except par value)
Common stock equity
Common stock of $6 2/3 par value
Authorized: 50,000,000 shares. Outstanding: 17,854,278 shares
at December 31, 2024 and 2023
$ 119,048 $ 119,048
Premium on capital stock 810,955 810,955
Retained earnings 223,896 1,476,258
Additional paid-in capital
270 -
Accumulated other comprehensive income, net of taxes-retirement benefit plans
2,786 2,849
Common stock equity $ 1,156,955 $ 2,409,110
Cumulative preferred stock not subject to mandatory redemption
Authorized: 5,000,000 shares of $20 par value and 7,000,000 shares of $100 par value.
Series Par Value Shares outstanding December 31, 2024 and 2023 2024 2023
(dollars in thousands, except par value and shares outstanding)
C-4.25%
$ 20 (Hawaiian Electric) 150,000 $ 3,000 $ 3,000
D-5.00%
20 (Hawaiian Electric) 50,000 1,000 1,000
E-5.00%
20 (Hawaiian Electric) 150,000 3,000 3,000
H-5.25%
20 (Hawaiian Electric) 250,000 5,000 5,000
I-5.00%
20 (Hawaiian Electric) 89,657 1,793 1,793
J-4.75%
20 (Hawaiian Electric) 250,000 5,000 5,000
K-4.65%
20 (Hawaiian Electric) 175,000 3,500 3,500
G-7.625%
100 (Hawaii Electric Light) 70,000 7,000 7,000
H-7.625%
100 (Maui Electric) 50,000 5,000 5,000
1,234,657 34,293 34,293
(continued)
Consolidated Statements of Capitalization (continued)
Hawaiian Electric Company, Inc. and Subsidiaries
December 31 2024 2023
(in thousands)
Long-term debt
Obligations to the State of Hawaii for the repayment of Special Purpose Revenue Bonds (subsidiary obligations unconditionally guaranteed by Hawaiian Electric):
3.50%, Series 2019, due 2049
$ 80,000 $ 80,000
3.20%, Refunding series 2019, due 2039
150,000 150,000
3.10%, Refunding series 2017A, due 2026
125,000 125,000
4.00%, Refunding series 2017B, due 2037
140,000 140,000
3.25%, Refunding series 2015, due 2025
47,000 47,000
Total obligations to the State of Hawaii $ 542,000 $ 542,000
Other long-term debt - unsecured:
Taxable senior notes:
6.11%, Series 2023A, due 2030
40,000 40,000
6.25%, Series 2023A and 2023B, due 2033
90,000 90,000
6.70%, Series 2023C, due 2053
20,000 20,000
3.70%, Series 2022A, due 2032
60,000 60,000
3.51%, Series 2020C and 2020E, due 2050
70,000 70,000
3.28%, Series 2020B and 2020D, due 2040
45,000 45,000
3.96%, Series 2020A, 2020B and 2020C, due 2050
50,000 50,000
3.31%, Series 2020A and 2020B, due 2030
110,000 110,000
4.21%, Series 2019A, due 2034
50,000 50,000
4.38%, Series 2018A, due 2028
67,500 67,500
4.53%, Series 2018B, due 2033
17,500 17,500
4.72%, Series 2018C, due 2048
15,000 15,000
4.31%, Series 2017A, due 2047
50,000 50,000
4.54%, Series 2016A, due 2046
40,000 40,000
5.23%, Series 2015A, due 2045
80,000 80,000
4.84%, Series 2013A, 2013B and 2013C, due 2027
100,000 100,000
5.65%, Series 2013B and 2013C, due 2043
70,000 70,000
4.72%, Series 2012D, due 2029
35,000 35,000
5.39%, Series 2012E, due 2042
150,000 150,000
4.53%, Series 2012F, due 2032
40,000 40,000
Total taxable senior notes 1,200,000 1,200,000
Revolving credit facility SOFR +1.80%, due 2026 and 2027
166,000 200,000
Total other long-term debt - unsecured 1,366,000 1,400,000
Total long-term debt 1,908,000 1,942,000
Less unamortized debt issuance costs 6,786 7,723
Less current portion long-term debt, net of unamortized debt issuance costs 47,000 -
Long-term debt, net 1,854,214 1,934,277
Total capitalization $ 3,045,462 $ 4,377,680
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Changes in Common Stock Equity
Hawaiian Electric Company, Inc. and Subsidiaries
Common stock Premium
on
capital
stock Retained
earnings Additional paid-in capital
Accumulated
other
comprehensive
income (loss)
(in thousands) Shares Amount Total
Balance, December 31, 2021 17,753 $ 118,376 $ 798,526 $ 1,348,277 $ - $ (3,280) $ 2,261,899
Net income for common stock - - - 188,929 - - 188,929
Other comprehensive income, net of taxes
- - - - - 6,141 6,141
Issuance of common stock, net of expenses 101 672 12,429 - - - 13,101
Common stock dividends - - - (125,900) - - (125,900)
Balance, December 31, 2022 17,854 119,048 810,955 1,411,306 - 2,861 2,344,170
Net income for common stock - - - 193,952 - - 193,952
Other comprehensive loss, net of taxes
- - - - - (12) (12)
Common stock dividends - - - (129,000) - - (129,000)
Balance, December 31, 2023 17,854 119,048 810,955 1,476,258 - 2,849 2,409,110
Net loss for common stock - - - (1,226,362) - - (1,226,362)
Other comprehensive loss, net of taxes
- - - - - (63) (63)
Common stock dividends - - - (26,000) - - (26,000)
Additional paid-in capital
- - - - 270 - 270
Balance, December 31, 2024 17,854 $ 119,048 $ 810,955 $ 223,896 $ 270 $ 2,786 $ 1,156,955
The accompanying notes are an integral part of these consolidated financial statements.
Consolidated Statements of Cash Flows
Hawaiian Electric Company, Inc. and Subsidiaries
Years ended December 31 2024 2023 2022
(in thousands)
Cash flows from operating activities
Net income (loss) $ (1,224,367) $ 195,947 $ 190,924
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation of property, plant and equipment 251,142 243,705 235,424
Other amortization 31,828 26,490 25,320
Deferred income tax expense (benefit)
(481,624) 1,439 (41,415)
State refundable credit (11,914) (11,325) (10,999)
Bad debt expense 4,720 8,161 6,027
Allowance for equity funds used during construction (13,786) (15,164) (10,574)
Other (6,311) 460 (139)
Changes in assets and liabilities
Decrease (increase) in accounts receivable
88,376 (65,004) (91,742)
Decrease (increase) in accrued unbilled revenues
7,561 (3,048) (54,023)
Decrease (increase) in fuel oil stock 49,334 43,293 (87,452)
Increase in materials and supplies
(4,033) (34,865) (7,691)
Decrease (increase) in regulatory assets (22,743) (10,613) 34,600
Increase in regulatory liabilities
48,433 54,470 44,888
Increase in accounts payable
9,644 20,454 22,355
Change in prepaid and accrued income taxes, tax credits and revenue taxes (26,542) 1,878 103,198
Change in defined benefit pension and other postretirement
benefit plans asset/liability
(9,218) (8,186) (4,828)
Increase in wildfire tort-related claims 1,840,000 75,000 -
Change in other assets and liabilities (64,767) (48,725) (25,943)
Net cash provided by operating activities 465,733 474,367 327,930
Cash flows from investing activities
Capital expenditures (329,479) (438,775) (329,457)
Other 11,848 6,176 5,372
Net cash used in investing activities (317,631) (432,599) (324,085)
Cash flows from financing activities
Common stock dividends (26,000) (129,000) (125,900)
Preferred stock dividends of Hawaiian Electric and subsidiaries (1,995) (1,995) (1,995)
Proceeds from issuance of common stock/capital contribution from parent
270 - 13,101
Proceeds from issuance of long-term debt - 350,000 60,000
Repayment of long-term debt and funds transferred for repayment of long-term debt
(81,000) (100,000) (52,000)
Net increase (decrease) in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less - (87,967) 87,967
Proceeds from issuance of short-term debt 50,000 - -
Payments of obligations under finance leases (4,119) (3,128) (670)
Other (9,187) (843) (364)
Net cash provided by (used in) financing activities (72,031) 27,067 (19,861)
Net increase (decrease) in cash, cash equivalents and restricted cash 76,071 68,835 (16,016)
Cash, cash equivalents and restricted cash, January 1 108,077 39,242 55,258
Cash, cash equivalents and restricted cash, December 31 184,148 108,077 39,242
Less: Restricted cash - (2,000) -
Cash and cash equivalents, December 31 $ 184,148 $ 106,077 $ 39,242
The accompanying notes are an integral part of these consolidated financial statements.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 1 · Summary of significant accounting policies
General
Hawaiian Electric Industries, Inc. (HEI) is a holding company with direct and indirect subsidiaries principally engaged in electric utility and non-regulated renewable/sustainable infrastructure businesses operating in the State of Hawaii. HEI owns Hawaiian Electric Company, Inc. (Hawaiian Electric), ASB Hawaii, Inc. (ASB Hawaii), GLST1, LLC (GLST1) and Pacific Current, LLC (Pacific Current).
Hawaiian Electric and its wholly owned operating subsidiaries, Hawaii Electric Light Company, Inc. (Hawaii Electric Light) and Maui Electric Company, Limited (Maui Electric), are regulated public electric utilities (collectively, the Utilities) in the business of generating, purchasing, transmitting, distributing and selling electric energy on all major islands in Hawaii other than Kauai. Hawaiian Electric also owns Renewable Hawaii, Inc. (RHI), and HE AR INTER LLC. See Note 3.
ASB Hawaii, is an intermediate holding company that previously owned American Savings Bank, F.S.B. (ASB), a federally chartered, full-service Hawaii community bank. In December 2024, ASB Hawaii sold ASB but currently retains a 9.9% noncontrolling investment in ASB. See Note 5.
GLST1 is a wholly owned subsidiary of Hawaiian Electric Industries, Inc. 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 legal claims in the litigation arising out of the Maui windstorm and wildfires. See Note 2.
Pacific Current’s significant subsidiaries include Hamakua Energy, LLC (Hamakua Energy) whose sale to an unaffiliated third party is expected to close in March 2025, Mauo, LLC (Mauo), Kaʻieʻie Waho Company, LLC (Kaʻieʻie Waho) and Mahipapa, LLC (Mahipapa). See Note 3.
Basis of presentation. In preparing the consolidated financial statements in conformity with accounting principles generally accepted in the United States of America (GAAP), 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 for HEI and its subsidiaries (collectively, the Company) include the amounts reported as fair value for pension and other postretirement benefit obligations; contingencies and litigation; income taxes; regulatory assets and liabilities (Utilities only); and asset retirement obligations (Utilities only).
Consolidation. The HEI consolidated financial statements include the accounts of HEI and its subsidiaries. The Hawaiian Electric consolidated financial statements include the accounts of Hawaiian Electric and its subsidiaries. When HEI or Hawaiian Electric has a controlling financial interest in another entity (usually, majority voting interest), that entity is consolidated. Investments in companies over which the Company or the Utilities have the ability to exercise significant influence, but not control, are accounted for using the equity method. The consolidated financial statements exclude variable interest entities (VIEs) when the Company or the Utilities are not the primary beneficiaries. Significant intercompany amounts are eliminated in consolidation (see Note 3 for limited exceptions).
Sale of American Savings Bank, F.S.B. As a result of a comprehensive review of strategic options of ASB, 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 while retaining a 9.9% noncontrolling ownership position. The sale transaction closed on December 31, 2024 and no investor acquired more than 9.9% of the common stock of ASB. The sale of ASB met the accounting requirements to be disclosed as discontinued operations. Accordingly, the results of ASB, including the loss on the ASB sale, are presented as discontinued operations in the consolidated statements of income and cash flows, and have been excluded from both continuing operations and segment results for all periods presented. Further, the assets and liabilities associated with ASB have been classified as discontinued operations in the Consolidated Balance Sheet as of December 31, 2023. Unless otherwise noted, reference within the following notes to consolidated financial statements exclude discontinued operations. See Note 5.
Investment in ASB. As a result of the ASB sale transaction on December 31, 2024, the Company retained a 9.9% noncontrolling ownership interest in ASB amounting to $44.6 million as of December 31, 2024, and is included in “Other noncurrent assets” on the Company’s Consolidated Balance Sheets. The Company has elected to subsequently measure its investment in ASB at cost minus impairment, in accordance with Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) 321, Investments-Equity Securities. FASB ASC 321 allows an entity to measure investments in
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
equity securities without a readily determinable fair value using a measurement alternative that measures these securities at cost minus impairment. On a quarterly basis, the Company is required to make a qualitative assessment of whether the investment is impaired.
Cash and cash equivalents. The Company considers cash on hand, deposits in banks, money market accounts, certificates of deposit, short-term commercial paper of non-affiliates and liquid investments (with original maturities of three months or less) to be cash and cash equivalents.
Restricted cash. The Company considers cash held by trustees, related to non-recourse loans at Pacific Current subsidiaries, and cash held by GLST1, related to the first liability installment payment pursuant to the settlement agreements to settle the tort-related legal claims in the litigation arising out of the Maui windstorm and wildfires, to be restricted cash. In addition, the Utilities consider funds on deposit with Wells Fargo, which represent collateral to secure company purchasing cards, to be restricted cash because these funds are available only to finance (or reimburse payment of) approved expenditures; however, as of December 31, 2024, such funds were released. At December 31, 2024 and 2023, total restricted cash of the Company was $492.3 million and $15.0 million, respectively, and for the Utilities was nil and $2.0 million, respectively. The Company’s restricted cash as of December 31, 2024 includes $478.8 million held by GLST1.
Property, plant and equipment. Property, plant and equipment are reported at cost. Self-constructed electric utility plant includes engineering, supervision, administrative and general costs and an allowance for the cost of funds used during the construction period. These costs are recorded in construction in progress and are transferred to utility plant when construction is completed and the facilities are either placed in service or become useful for public utility purposes. Costs for betterments that make utility plant more useful, more efficient, of greater durability or of greater capacity are also capitalized. Upon the retirement or sale of electric utility plant, generally no gain or loss is recognized. The cost of the plant retired is charged to accumulated depreciation. Amounts collected from customers for cost of removal are included in regulatory liabilities. See discussion regarding “Utility projects” in Note 4.
Depreciation. Depreciation is computed primarily using the straight-line method over the estimated lives of the assets being depreciated. Electric utility plant additions in the current year are depreciated beginning January 1 of the following year in accordance with rate-making. Electric utility plant and Pacific Current generation assets have lives ranging from 16 to 51 years for production plant, from 10 to 79 years for transmission and distribution plant, and from 5 to 50 years for general plant. The Utilities’ composite annual depreciation rate, which includes a component for cost of removal, was 3.2% in 2024, 2023 and 2022.
Retirement benefits. Pension and other postretirement benefit costs are charged primarily to expense and electric utility plant (in the case of the Utilities). Funding for the Company’s qualified pension plan (Plan) is based on actuarial assumptions adopted by the Pension Investment Committee administering the Plan. The participating employers contribute amounts to pension trust for the Plan in accordance with the funding requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA), including changes promulgated by the Pension Protection Act of 2006, and considering the deductibility of contributions under the Internal Revenue Code. The Company generally funds at least the net periodic pension cost during the year, subject to ERISA minimum and Internal Revenue Code limits and targeted funded status.
Certain health care and/or life insurance benefits are provided to eligible retired employees and the employees’ beneficiaries and covered dependents. The Company generally funds the net periodic postretirement benefit costs other than pension (except for executive life) for postretirement benefits other than pension (OPEB), while maximizing the use of the most tax-advantaged funding vehicles, subject to cash flow requirements and reviews of the funded status with the consulting actuary.
Environmental expenditures. The Company and the Utilities are subject to numerous federal and state environmental statutes and regulations. In general, environmental contamination treatment costs are charged to expense. 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. Environmental costs are either capitalized or charged to expense when environmental assessments and/or remedial efforts are probable and the cost can be reasonably estimated. The Utilities review their sites and measure the liability quarterly by assessing a range of reasonably likely costs of each identified site using currently available information, including existing technology, presently enacted laws and regulations, experience gained at similar sites, and the probable level of involvement and financial condition of other potentially responsible parties.
Contingencies and litigation. The Company and the Utilities are 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
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
is based on an analysis of each individual case or proceeding often with the assistance of outside counsel. Loss contingencies are reviewed quarterly and estimates are adjusted to reflect the impact of all known information, such as new developments in each matter or changes in approach in dealing with these matters, including changes in settlement strategy. When a loss is probable and reasonably estimable, a liability is recorded in the amount of the estimable loss. If it is reasonably possible that a loss may have been incurred and the effect on the financial statements could be material, the Company and the Utilities disclose the nature of the loss contingency and an estimate of the possible loss or range of loss or a statement that such an estimate cannot be made within the notes to the 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 and the Utilities’ assets and liabilities at federal and state 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. Valuation allowances are established when necessary to reduce deferred income tax assets to the amount expected to be realized.
HEI and the Utilities’ investment tax credits are deferred and amortized over the estimated useful lives of the properties to which the credits relate (and for the Utilities, this treatment is in accordance with Accounting Standards Codification (ASC) Topic 980, “Regulated Operations”).
The Utilities are included in the consolidated income tax returns of HEI. However, income tax expense has been computed for financial statement purposes as if each utility filed a separate income tax return and Hawaiian Electric filed a consolidated Hawaiian Electric income tax return.
Governmental tax authorities could challenge a tax return position taken by the Company. The Company and the Utilities use a “more-likely-than-not” recognition threshold and measurement standard for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return.
Fair value measurements. Fair value estimates are estimates of the price that would be received to sell an asset, or paid upon the transfer of a liability, in an orderly transaction between market participants at the measurement date. The fair value estimates are generally determined based on assumptions that market participants would use in pricing the asset or liability and are based on market data obtained from independent sources. However, in certain cases, the Company and the Utilities use their own assumptions about market participant assumptions based on the best information available in the circumstances. These valuations are estimates at a specific point in time, based on relevant market information, information about the financial instrument and judgments regarding future expected loss experience, economic conditions, risk characteristics of various financial instruments and other factors. These estimates do not reflect any premium or discount that could result if the Company or the Utilities were to sell its entire holdings of a particular financial instrument at one time. Because no active trading market exists for a portion of the Company’s and the Utilities’ financial instruments, fair value estimates cannot be determined with precision. Changes in the underlying assumptions used, including discount rates and estimates of future cash flows, could significantly affect the estimates. In addition, the tax ramifications related to the realization of the unrealized gains and losses could have a significant effect on fair value estimates, but have not been considered in making such estimates.
The Company and the Utilities group their financial assets measured at fair value in three levels outlined as follows:
Level 1: Inputs to the valuation methodology are quoted prices, unadjusted, for identical assets or liabilities in active markets. A quoted price in an active market provides the most reliable evidence of fair value and is used to measure fair value whenever available.
Level 2: Inputs to the valuation methodology include quoted prices for similar assets or liabilities in active markets; inputs to the valuation methodology include quoted prices for identical or similar assets or liabilities in markets that are not active; or inputs to the valuation methodology that are derived principally from or can be corroborated by observable market data by correlation or other means.
Level 3: Inputs to the valuation methodology are unobservable and significant to the fair value measurement. Level 3 assets and liabilities include financial instruments whose value is determined using discounted cash flow methodologies, as well as instruments for which the determination of fair value requires significant management judgment or estimation.
Classification in the hierarchy is based upon the lowest level input that is significant to the fair value measurement of the asset or liability. For instruments classified in Level 1 and 2 where inputs are primarily based upon observable market data, there is less judgment applied in arriving at the fair value. For instruments classified in Level 3, management judgment is more significant due to the lack of observable market data.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The Company reviews and updates the fair value hierarchy classifications on a quarterly basis. Changes from one quarter to the next related to the observability of inputs in fair value measurements may result in a reclassification between the fair value hierarchy levels and are recognized based on period-end balances.
Fair value is also used on a nonrecurring basis to evaluate certain assets for impairment or for disclosure purposes. Examples of nonrecurring uses of fair value include asset retirement obligations (AROs).
Earnings per share (HEI only). Basic earnings per share (EPS) and Basic EPS from continuing operations are computed by dividing net income for common stock and income from continuing operations for common stock, respectively, by the weighted-average number of common shares outstanding for the period. Diluted EPS and diluted EPS from continuing operations are computed similarly, except that dilutive common shares for stock compensation is added to the denominator. Since there is a net loss, there can be no potentially dilutive shares during the year ended December 31, 2024. As of December 31, 2023, the antidilutive effect of restricted stock units (RSUs) on 65,078 shares of common stock, was not included in the computation of diluted EPS. There were no shares of antidilutive securities outstanding during the year ended December 31, 2022.
Impairment of long-lived assets and long-lived assets to be disposed of. The Company and the Utilities review long-lived assets and certain identifiable intangibles for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to future undiscounted net cash flows expected to be generated by the asset. If such assets are considered to be impaired, the impairment to be recognized is measured by the amount by which the carrying amount of the assets exceeds the fair value of the assets. When the Utilities conclude that recovery of the remaining carrying amount of long-lived generation asset upon retirement is probable of recovery in future rates the carrying amount of the long-lived generation asset is recorded as a regulatory asset. Other assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
Recent accounting pronouncements.
Segment Reporting. In November 2023, the FASB issued Accounting Standards Update (ASU) No. 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures to improve reportable segment disclosure requirements, primarily through enhanced disclosure requirements of significant segment expenses. These amendments are effective for annual periods beginning after December 15, 2023 and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. These amendments apply on a retrospective basis. The Company adopted this amendment as of December 31, 2024, which did not have a material impact on its disclosures.
Income Taxes. In December 2023, the FASB issued ASU No. 2023-09, Income Taxes (Topic 740): Improvement to Income Tax Disclosures to enhance the transparency and decision usefulness of income tax disclosures. The amendments are effective for annual periods beginning after December 15, 2024. These amendments apply on a prospective basis with a retrospective option. Early adoption is permitted. The Company is currently evaluating the impact of this amendment on the Company’s consolidated financial statements and does not expect the adoption to have a material impact on its consolidated financial statements.
Climate-related disclosures. In March 2024, the SEC issued final climate-related disclosure rules under SEC Release No. 33-11275, The Enhancement and Standardization of Climate-Related Disclosures for Investors (climate disclosure rules). The rules will require annual disclosure of material greenhouse gas emissions as well as disclosure of governance, risk management and strategy related to material climate-related risks. In addition, the rules require (i) financial statement impacts of severe weather events and other natural conditions; (ii) a roll forward of carbon offset and renewable energy credit balances if material to the Company’s plan to achieve climate-related targets or goals; and (iii) material impacts on estimates and assumptions in the financial statements. The disclosure requirements will begin phasing in for annual periods beginning with calendar year 2025. In April 2024, the SEC voluntarily stayed implementation of its climate disclosure rules pending completion of judicial review by the Court of Appeals for the Eighth Circuit. The Company is currently monitoring developments with this final rule and evaluating its impact on the Company’s consolidated financial statements.
Reclassifications. Certain prior year amounts on the Consolidated Balance Sheet have been reclassified to conform to a classified balance sheet presentation. These prior year reclassifications include presenting current and noncurrent assets and liabilities. These reclassifications did not affect net income or shareholders’ equity for the years ended December 31, 2023.
Within the consolidated balance sheet for the prior period, wildfire tort-related claims amounts were reclassified from “Other current liabilities” to current “Wildfire tort-related claims” for the Company and the Utilities, and other postretirement benefit plan asset was reclassified from noncurrent “Other asset” to noncurrent “Defined benefit pension and other postretirement benefit plans asset” for the Utilities, to conform to the current year financial statement presentation. Also, consolidated statements of cash flows of prior year wildfire tort-related claims amounts were reclassified from “Change in other
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
assets and liabilities” to “Increase in wildfire tort-related claims” for the Company and the Utilities to conform to the current year financial statement presentation. Reclassifications did not affect previously reported net income, retained earnings or net cash provided by operating activities.
Electric utility
Regulation by the Public Utilities Commission of the State of Hawaii (PUC). The Utilities are regulated by the PUC and account for the effects of regulation under FASB ASC Topic 980, “Regulated Operations.” As a result, the Utilities’ financial statements reflect assets, liabilities, revenues and expenses based on current cost-based rate-making regulations (see Note 4-“Regulatory assets and liabilities”). Their continued accounting under ASC Topic 980 generally requires that rates are established by an independent, third-party regulator; rates are designed to recover the costs of providing service; and it is reasonable to assume that rates can be charged to, and collected from, customers. Management believes that the operations of the Utilities, including the impact of the approved PBR Framework, currently satisfy the criteria under ASC Topic 980.
The rate schedules of the Utilities include energy costs recovery clauses (ECRCs) under which electric rates are adjusted for changes in the weighted-average price paid for fuel oil and certain components of purchased power, and the relative amounts of company-generated power and purchased power. The rate schedules also include purchased power adjustment clauses (PPACs) under which the remaining purchase power expenses are recovered through surcharge mechanisms. The amounts collected through the ECRCs and PPACs are required to be reconciled quarterly.
Accounts receivable. Accounts receivable are recorded at the invoiced amount. The Utilities generally assess a late payment charge on balances unpaid from the previous month. The allowance for doubtful accounts is the Utilities’ best estimate of the amount of expected credit losses in the Utilities’ existing accounts receivable. At December 31, 2024 and 2023, the allowance for customer accounts receivable, accrued unbilled revenues and other accounts receivable was $5.6 million and $4.6 million, respectively.
Electric utility revenues. Revenues related to electric service are generally recorded when service is rendered and include revenues applicable to energy consumed in the accounting period but not yet billed to the customers. The Utilities also record revenue under a decoupling mechanism. See “Decoupling” discussion in Note 4.
Repairs and maintenance costs. Repairs and maintenance costs for overhauls of generating units are generally expensed as they are incurred.
Allowance for funds used during construction (AFUDC). AFUDC represents the estimated costs of debt (i.e., interest) and equity funds used to finance plant construction. AFUDC is credited on the statement of income and charged to construction in progress on the balance sheet. If a project under construction is delayed for an extended period of time, AFUDC on the delayed project may be stopped after assessing the causes of the delay and probability of recovery. The tax gross up of the allowance for equity funds used during construction is credited to income taxes on the statement of income and charged to a regulatory asset. This gross up, net of amortization of the regulatory asset, is reflected in income tax expense.
The weighted-average AFUDC rate was 7.3% in 2024, 7.2% in 2023 and 7.1% in 2022, and reflected quarterly compounding.
Asset retirement obligations. AROs are accounted for in accordance with ASC 410-20, “Asset Retirement Obligations.” AROs are recognized at present value of expected costs to retire long-lived assets from service, provided a legal obligation exists and a reasonable estimate of the fair value and the settlement date can be made. In the subsequent period, the liability is accreted to its future value while the asset retirement cost is depreciated over the estimated useful life of the underlying asset. The Utilities’ recognition of AROs have no impact on earnings, as the cost of the AROs are recovered over the life of the asset through depreciation. AROs recognized by the Utilities relate to legal obligations with the retirement of plant and equipment, including removal of asbestos and other hazardous materials. See “Asset retirement obligations” in Note 4.
Note 2 · Maui windstorm and wildfires
On August 8, 2023, a number of brush fires in the West Maui (Lahaina) and Upcountry Maui areas caused widespread property damage, including damage to property of the Utilities, and 102 confirmed fatalities in Lahaina (the Maui windstorm and wildfires). The Maui windstorm and wildfires were fueled by extreme winds and drought-like conditions in those parts of Maui.
Restoration costs and recoveries. The Utilities are continuing restoration work to rebuild portions of the electric system in Lahaina to ensure safe and reliable power to all West Maui customers. Restoration efforts include the rebuilding of
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
transmission and distribution lines along former routes in the Lahaina area with the installation of new interim steel and wood poles and electrical equipment. To date, power has been restored to all customers that were able to have power restored in Lahaina and the rest of West Maui.
On December 27, 2023, the Public Utilities Commission of the State of Hawaii (PUC) issued an order authorizing deferred accounting treatment for the Utilities’ incremental non-labor expenses related to the Maui windstorm and wildfires. The deferred accounting treatment applies to certain non-labor expenses incurred from August 8, 2023 through December 31, 2024 that are not already a part of the base rates. The approval pertains only to deferred cost treatment; any cost recovery of deferred costs will be the subject of a separate application(s). On November 27, 2024, the Utilities filed a request with the PUC to extend the deferral accounting period to December 31, 2025, specifically limited to insurance premiums and outside services and legal costs associated with the asset-based lending facility credit agreement (see Note 6). On February 12, 2025, the PUC issued an order granting the Utilities’ request to extend. As of December 31, 2024, the Utilities have deferred $52.7 million of certain incremental costs related to the Maui windstorm and wildfires to a regulatory asset.
The Utilities are actively seeking recovery of damage to covered electrical infrastructure under their property insurance programs. The Utilities have submitted claims, received and recorded the insurance recoveries of $1 million in 2024; however, the timing and amount of any future insurance recoveries remain indeterminable at this time and as such, an insurance receivable has not been recorded as of the date of this filing. The Company’s property insurance has a total policy limit of $500 million with a $1 million retention for damages related to Utility-owned non-generating assets, including overhead transmission and distribution assets within 1,000 feet of such assets. The Utilities believe capital expenditures related to restoration that are not covered by insurance will be managed under their current regulatory mechanisms, the recovery of which would be subject to PUC approval. As of December 31, 2024, the Company has $499 million of insurance coverage remaining under the property insurance policy.
Third-party claims and other proceedings.
Tort-related legal claims. As of February 14, 2025, HEI and the Utilities have each been named in approximately 783 lawsuits related to the Maui windstorm and wildfires. These civil and putative class action lawsuits are pending in the Maui Circuit Court against HEI, the Utilities, and other defendants, including the County of Maui, the State of Hawaii and related state entities, private landowners and developers, and telecommunications companies (collectively, tort-related legal claims). One putative class action is also pending in federal court. Most of these lawsuits allege that the defendants were responsible for, and/or negligent in failing to prevent or respond to, the wildfires that led to the property destruction and loss of life. Other claims include, among other things, personal injury, wrongful death, emotional distress and inverse condemnation. One lawsuit asserting similar theories and claims was filed by the County of Maui against HEI and the Utilities, one lawsuit was filed by Spectrum Oceanic, LLC against HEI and the Utilities and other defendants, and other lawsuits were filed by approximately 160 subrogation insurers against HEI, the Utilities, a private landowner, and telecommunications companies. Additional lawsuits may be filed against the Company and other defendants in the future. The plaintiffs seek to recover damages and other costs, including punitive damages. Defendants have asserted cross-claims against one another for indemnification, contribution, and subrogation.
The County of Maui Origin and Cause Report, released on October 2, 2024, attaching the investigative report by the Bureau of Alcohol, Tobacco, Firearms and Explosives, estimated the total economic damage of approximately $6 billion. That estimate has not been validated by the Company, and it represents a gross number that does not take into account causation or liability and does not attempt to allocate responsibility among the various defendants. As such, the estimate is not intended to provide a reasonably possible loss in excess of the recorded amount under ASC Topic 450-20, “Loss Contingencies” attributable to the Company arising from the Maui windstorm and wildfires.
On November 8, 2023, Hawaii Governor Josh Green announced the One ‘Ohana Initiative (the One ‘Ohana Initiative) as a collective path forward to recovery from the Maui windstorm and wildfires. The One ‘Ohana Initiative is a new humanitarian aid fund of $175 million, with the objective to compensate, in an expedited manner, those who have lost loved ones and those who have suffered severe injuries in the Maui windstorm and wildfires. The One ‘Ohana Initiative provides an alternative to a lengthy and expensive legal process. Beneficiaries who have lost loved ones are anticipated to receive payments of $1.5 million per decedent, and those who suffered severe injuries are expected to share in a specially allocated pool of compensation. In exchange for receiving such a payment, beneficiaries will be required to waive their ability to pursue legal claims for wrongful death and severe injuries, except if they seek compensation through the litigation settlement. Hawaiian Electric fully supports this humanitarian initiative and has contributed $75 million. The Governor announced that other parties, including the State of Hawaii, the County of Maui, and Kamehameha Schools have all agreed to contribute to the fund. Hawaiian Electric’s contribution to the Initiative was less than half of the total, and Hawaiian Electric's insurance carriers funded its share of the contributions to the fund. Hawaiian Electric’s contribution is reflective of its commitment to join with community partners to
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
provide solutions to promote Maui’s recovery. Hawaiian Electric’s commitment to contribute to the One ‘Ohana Initiative is not an admission of guilt or reflection of fault or liability related to the wildfires. Under the One ‘Ohana Initiative, all claimants (except families of missing persons) were required to submit a completed registration form and registrants who meet the Fund’s eligibility requirements then were required to complete and submit a claim form. As of October 25, 2024, 36 claim forms were received that relate to death claims and 12 claim forms were received that relate to physical injury claims. The One ‘Ohana Initiative will retain its separate existence and claimants eligible will be required to apply to the One ‘Ohana Initiative before obtaining benefits from the litigation settlement.
Effective November 1, 2024, HEI and Hawaiian Electric entered into two definitive settlement agreements (collectively, the Settlement Agreements) to settle the tort-related legal claims in the litigation arising out of the Maui windstorm and wildfires (expressly excluding securities and derivative actions) on a global basis without any admission of liability. Under the Settlement Agreements, subject to certain conditions (including those described below), HEI and Hawaiian Electric, along with other defendants (the State of Hawaii, the County of Maui, Kamehameha Schools, entities affiliated with the West Maui Land Co., Hawaiian Telcom, and Spectrum/Charter Communications) have agreed to settle the claims of those who filed lawsuits in state and federal courts, or who may have claims but have not yet filed lawsuits, in connection with the Maui windstorm and wildfires. One Settlement Agreement is between the defendants, class counsel, and class plaintiffs (the Class Settlement Agreement), and the other is between the defendants and over 30 lawyers representing numerous individual plaintiffs who have brought their own lawsuits (the Individual Settlement Agreement). The 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 (described below) is a condition that must be satisfied before any payment is due from the defendants. Both Settlement Agreements remain subject to court approval and other conditions, including those set out below.
Under the Settlement Agreements, HEI and Hawaiian Electric are obligated to contribute a total of $1.99 billion (out of a total defendant contribution of approximately $4.04 billion), which includes $75 million previously contributed for the One ‘Ohana Initiative (a humanitarian aid fund to provide payments outside of litigation to the beneficiaries of those who died, as well as compensation for personal injury damages). The total settlement amount is to be divided between two settlement funds, one for the benefit of individual plaintiffs, and the other for the benefit of the class plaintiffs. HEI and Hawaiian Electric must pay such amounts in four equal annual installments of approximately $479 million, with the first installment expected to be made no earlier than the fourth quarter of 2025. HEI and Hawaiian Electric have the option to accelerate the payments, in whole or in part, with such accelerated payments to be discounted at a rate of 5.5% per annum. HEI transferred the amount of the first payment, $479 million, into a new subsidiary, which is restricted from disbursing such funds except in connection with the initial payment to the settlement funds. Additionally, under the Settlement Agreements, HEI and Hawaiian Electric are obligated to contribute a share to the settlement administration fees only if certain other sources are exhausted when those fees are due, for which $3.5 million was accrued as of December 31, 2024 based on the best estimate at that time.
The Settlement Agreements are intended to resolve all of the tort-related legal claims related to the Maui windstorm and wildfires. The Class Settlement Agreement provides releases by plaintiffs to the defendants, and among defendants, for acts and omissions relating to the Maui windstorm and wildfires. The Individual Settlement Agreement provides that individual plaintiffs who elect to accept the settlement will sign releases. The releases in the Settlement Agreements, including those among defendants (subject to certain conditions), are effective on the initial payment due date. The Settlement Agreements also provide that $500 million of the total settlement payments will be reserved and made available to defendants to defray the cost to resolve any claims brought by plaintiffs who do not release claims as part of the settlements. Defendants have the right to terminate the Settlement Agreements under certain circumstances, including if more than specified thresholds of plaintiffs choose not to participate in the settlement.
The Settlement Agreements contain multiple conditions that must be met before any payment from HEI and Hawaiian Electric to the settlement funds are due. Those conditions include, among others, resolving claims of the insurers (either through agreement or a final court order stating that the insurers cannot maintain independent lawsuits against the defendants), legislation appropriating money from the state, and court approval of the Settlement Agreements.
The Settlement Agreements do not resolve claims with insurers who have asserted subrogation claims in separate lawsuits, and such insurers are not parties to the Settlement Agreements. However, the Settlement Agreements provide that all subrogation claims by insurers that have been or could be brought against defendants arising out of the Maui windstorm and wildfires must be resolved in order for HEI and Hawaiian Electric’s payment obligation to arise. The Settlement Agreements include a condition to the defendants’ obligations providing that by May 19, 2025, either (a) insurers that have brought claims arising out of the Maui windstorm and wildfires enter into a written agreement that provides for releases of all claims against the defendants, or (b) that there is a final and unappealable court order providing that if the final definitive agreement between the plaintiffs and the defendants becomes effective, then those same insurers’ exclusive remedy for any claims against the
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
defendants would be limited to asserting liens against the settlement amounts obtained by the individual plaintiffs. On February 6, 2025, after briefing was complete, the Supreme Court of Hawaii heard argument on three reserved questions regarding the scope of Hawaii subrogation law concerning the condition described in this paragraph in the manner described in (b) above. On February 10, 2025, the Hawaii Supreme Court issued an order regarding the reserved questions providing that, once the settlement becomes final, the exclusive remedy for insurers seeking to recover amounts paid to settling plaintiffs is to assert liens against their policyholders pursuant to HRS 663-10. The Hawaii Supreme Court is expected to issue a written opinion providing further detail on its decision in the coming weeks.
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 HEI’s and the Utilities’ Consolidated Balance Sheets. The Settlement Agreements contain no admission of any liability by HEI or the Utilities and reflect the collective efforts of the State, HEI and the Utilities, and other defendants to seek a comprehensive resolution of the litigation arising out of the Maui windstorm and wildfires. The Utilities have recorded an additional $40 million in “Accounts receivable and unbilled revenues, net” and “Other accounts receivable, net” on HEI’s and the Utilities’ Consolidated Balance Sheets, respectively, as of December 31, 2024, based on the amounts expected to be remaining under the applicate insurance policies at time of settlement payment.
As part of the agreement in principle preceding the Settlement Agreements, the parties agreed to vacate all trial dates and stay the litigation, except for (i) litigation activities between the plaintiffs (individual and class) and the subrogation insurers and (ii) actions taken to further settlement. On August 2, 2024, the Maui Circuit Court overseeing the Special Proceeding, in which most of the actions have been coordinated, vacated the trial dates that previously had been set. Accordingly, no trial dates are currently set in any action. On October 21, 2024, the three subrogation actions that had been pending in the Oahu Circuit Court were transferred to the Maui Circuit Court. On December 9, 2024, the Maui Circuit Court entered an order staying the three subrogation actions, and permitting the parties to request a status conference to discuss next steps within 14 days of a decision by the Hawaii Supreme Court on the reserved questions.
The Company intends to vigorously defend itself in the litigation if a definitive settlement is ultimately not achieved. There is no assurance that the Company will be successful in the defense of the litigation or that insurance will be available or adequate to fund any potential settlements, judgments, or costs associated with the litigation. If additional liabilities were to be incurred, the loss could be material to the Company’s results of operations, financial position and cash flows and could result in violations of the financial covenants in the Company’s debt agreements. If any such losses were to be sufficiently high, the Company may not have liquidity or the ability to access liquidity at levels necessary to satisfy such losses. However, any possible loss in excess of the amount recorded cannot reasonably be estimated at this time.
Securities class action and shareholder lawsuits. On August 24, 2023, a putative securities class action captioned Bhangal v. Hawaiian Electric Industries, Inc., et al., No.: 3:23-cv-04332-JSC (the Securities Action) was filed in the United States District Court for the Northern District of California. The lawsuit alleges violations of the Securities Exchange Act of 1934 (the Exchange Act) and Rule 10b-5 promulgated thereunder against HEI and certain of its current and former officers (collectively, Defendants), and Section 20(a) of the Exchange Act against certain of HEI’s current and former officers. Plaintiff broadly alleges that Defendants made materially false and misleading statements or omissions regarding HEI’s wildfire prevention and safety protocols and related matters. Plaintiff seeks unspecified monetary damages. On December 7, 2023, the court appointed Daniel Warren as lead plaintiff and Pomerantz LLP as lead plaintiff’s counsel. On March 8, 2024, the lead plaintiff filed an amended complaint. On October 15, 2024, the court granted defendants’ motion to dismiss the amended complaint, with leave to amend. On November 12, 2024, the lead plaintiff filed a second amended complaint. The Company anticipates filing a motion to dismiss the second amended complaint and intends to vigorously defend against this action. An unsuccessful mediation was held on January 22, 2025. There is no assurance that the Company will be successful in the defense of the litigation or that insurance will be available or adequate to fund any potential settlement or judgment or the litigation costs of the action. The Company does not believe that a loss is probable and any possible loss or range of loss is not reasonably estimable.
On September 11, 2023, a putative shareholder derivative action captioned Rice v. Connors, et al., No. 1CCV-23-0001181 was filed in the Circuit Court of the First Circuit, State of Hawaii. On December 6, 2023, the case was removed to the United States District Court for the District of Hawaii and captioned Rice v. Connors, et al., No. 1:23-cv-00577-JAO-BMK. On March 14, 2024, the United States District Court remanded the case to the Circuit Court of the First Circuit, State of Hawaii. This action is purportedly brought by a shareholder on behalf of nominal defendants HEI and Hawaiian Electric against certain current and former officers and directors of HEI and Hawaiian Electric. Plaintiff asserts Hawaii state law breach of fiduciary duty, abuse of control, corporate waste, unjust enrichment, and aiding and abetting breach of fiduciary duty claims allegedly arising in connection with the Maui windstorm and wildfires that occurred in August 2023 and certain of the Company’s prior
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
public disclosures. Plaintiff seeks, on behalf of HEI and Hawaiian Electric, compensatory and punitive damages, restitution, disgorgement, and equitable relief in the form of changes to corporate governance, policies and culture. HEI has moved to stay the proceeding pending resolution of the tort-related legal claims and the Securities Action. A hearing on the motion to stay is set for March 5, 2025. While the Company has obligations to indemnify and/or advance the defendants’ legal fees and costs in connection with this lawsuit, any monetary recovery in the derivative litigation should accrue to the Company. An unsuccessful mediation was held on January 22, 2025. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
On November 6, 2024, a putative shareholder derivative action captioned Hamilton v. Lau, et al., No. 1CCV-24-0001595 was filed in the Circuit Court of the First Circuit, State of Hawaii (the “Hamilton Action”). This action is purportedly brought by a shareholder on behalf of nominal defendants HEI and Hawaiian Electric against certain current and former officers and directors of HEI and Hawaiian Electric. Plaintiff asserts Hawaii state law breach of fiduciary duty, unjust enrichment, aiding and abetting breaches of fiduciary duty, and corporate waste claims allegedly arising in connection with the Maui windstorm and wildfires that occurred on in August 2023 and certain of HEI’s prior public disclosures. Plaintiff seeks, on behalf of HEI and Hawaiian Electric, compensatory and punitive damages, restitution and equitable relief in the form of changes to HEI’s corporate governance, policies and culture. While the Company has certain obligations to indemnify and/or advance the individual defendants’ legal fees and costs in connection with this lawsuit, any monetary recovery in the derivative litigation should accrue to the Company. An unsuccessful mediation was held on January 22, 2025. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
Three putative shareholder derivative actions were filed in the United States District Court for the Northern District of California between December 26, 2023 and February 8, 2024, including:
Kallaus v. Johns, et al., No. 3:23-cv-06627 (the Kallaus Action), Cole v. Johns, et al., No. 3:24-cv-00598 (the Cole Action), and Tai v. Seu, et al., No. 3:24-cv-01198 (the Tai Action). On March 19, 2024, upon stipulation by the parties, the court consolidated the Kallaus Action, the Cole Action, and the Tai Action under the caption In Re Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. Derivative Litigation, No. 3:23-cv-06627 (the Consolidated Derivative Actions). On June 19, 2024, Plaintiffs filed a consolidated amended complaint. The Consolidated Derivative Actions are purportedly brought by shareholders of HEI on behalf of nominal defendants HEI and Hawaiian Electric against certain current and former officers and directors of HEI and Hawaiian Electric. Plaintiffs purport to assert both Hawaii state law and federal securities law claims. Plaintiffs assert state law breach of fiduciary duty, corporate waste, unjust enrichment, gross mismanagement, and abuse of control claims purportedly arising in connection with the Maui windstorm and wildfires that occurred in August 2023 and certain public disclosures. Plaintiffs also assert claims under Section 10(b) of the Exchange Act, and Rule 10b-5 promulgated thereunder, and generally allege that the Company and certain of its current and former officers made materially false and misleading statements or omissions regarding the Company’s wildfire prevention and safety protocols and related matters. Plaintiffs seek, on behalf of HEI and Hawaiian Electric, unspecified monetary and punitive damages, disgorgement, and other relief. HEI moved to stay the Consolidated Derivative Actions pending resolution of the tort-related legal claims and the Securities Action, and also moved to dismiss the consolidated amended complaint for failing to adequately allege that the Board’s refusal of the plaintiffs’ demands was wrongful. Hawaii state court plaintiff Christina Rice (see above) filed a motion to intervene in this action for the limited purpose of seeking dismissal, or alternatively a stay, of this action in favor of the Hawaii state court derivative action she filed. Hawaii federal court plaintiffs George Assad and Robert Faris (see below) also filed a motion to intervene in this action for the limited purpose of seeking dismissal, or alternatively a stay, of this action in favor of a separate Hawaii federal court derivative action they filed. The court deferred the hearing on the Company’s motions to stay and dismiss, Rice’s motion to intervene, and Assad’s and Faris’s motion to intervene pending a mediation on January 22, 2025, which was unsuccessful. On January 30, 2025, the Court granted the plaintiffs’ request to voluntarily dismiss the case so that they could refile the action in Hawaii. As a result, the Court did not rule on the Company’s pending motion to dismiss or motion to stay. While the Company has certain obligations to indemnify and/or advance the defendants’ legal fees and costs in connection with this lawsuit, any monetary recovery in the Consolidated Derivative Actions should accrue to the Company. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
Two putative shareholder derivative actions were filed in the United States District Court for the District of Hawaii between April 8, 2024 and June 8, 2024, including:
Assad v. Seu, et al., No. 1:24-cv-00164 (the Assad Action), and Faris v. Seu, et al., No. 1:24-cv-00247 (the Faris Action). On July 3, 2024, upon stipulation by the parties, the court consolidated the Assad Action and Faris Action under the caption In Re Hawaiian Electric Industries, Inc., Stockholder Derivative Litigation, No. 1:24-cv-00164 (the Hawaii Federal Derivative Actions). Both actions are purportedly brought by shareholders on behalf of nominal defendant HEI and against certain current
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
and former officers and directors of HEI and Hawaiian Electric. Plaintiffs purport to assert Hawaii state law claims for breach of fiduciary duty, corporate waste, and unjust enrichment allegedly arising in connection with the Maui windstorm and wildfires that occurred in August 2023 and certain public disclosures. Plaintiffs generally allege that the Company and certain of its current and former officers made materially false and misleading statements or omissions regarding the Company’s wildfire prevention and safety protocols and related matters. Plaintiffs seek, on behalf of HEI, compensatory damages, restitution, disgorgement, injunctive relief, and equitable relief, including in the form of changes to HEI’s corporate governance policies and procedures. On July 30, 2024, upon HEI’s motion, the court stayed the Hawaii Federal Derivative Actions pending resolution of the motion to dismiss the Securities Action and the motions to stay and dismiss the Consolidated Derivative Actions. While the Company has obligations to indemnify and/or advance the defendants’ legal fees and costs in connection with this lawsuit, any monetary recovery in the derivative litigation should accrue to the Company. A mediation was held on
January 22, 2025. The parties did not reach a settlement on that date. The Company is unable to predict the ultimate outcome and is unable to make a reasonable estimate of the amount or range of loss, if any, that could result from any unfavorable outcome.
Maui windstorm and wildfires costs. Legal costs in connection with the litigation and loss contingencies are expensed as incurred. The Company has $165 million of excess liability insurance and $25 million of miscellaneous professional liability insurance for third party claims, including claims related to wildfires, with a retention of $0.3 million and $1.0 million, respectively, and $145 million directors and officers liability insurance to cover claims related to the shareholder and derivative lawsuits, with a retention of $1.0 million. As of December 31, 2024, the Company’s and Utilities’ insurance receivable totaled $57 million and $55 million, respectively, under the policies. As of December 31, 2024, HEI and its subsidiaries have approximately $13 million, nil and $122 million of insurance coverage remaining under the excess liability, miscellaneous 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 and recognized as a receivable as of year-end.
See table below for the incremental expenses related to the Maui windstorm and wildfires.
Year ended December 31, 2024 Year ended December 31, 2023
(in thousands) Electric utility
HEI Consolidated2
Electric utility
HEI Consolidated2
Maui windstorm and wildfires related expenses:
Legal expenses $ 51,406 $ 69,779 $ 24,737 $ 33,969
Wildfire tort-related claims
1,915,000 1,915,000 75,000 75,000
Other expense
52,421 61,251 15,071 18,143
Total Maui windstorm and wildfires related expenses 2,018,827 2,046,030 114,808 127,112
Insurance recoveries
(85,781) (94,699) (98,613) (104,580)
Deferral treatment approved by the PUC1
(37,960) (37,960) (14,692) (14,692)
Total Maui windstorm and wildfires related expenses, net of insurance recoveries and approved deferral treatment $ 1,895,086 $ 1,913,371 $ 1,503 $ 7,840
1 Related to the PUC’s order, received on December 27, 2023, approving deferred accounting treatment for the Utilities’ incremental non-labor expenses related to the August 2023 Maui windstorm and wildfires. Amounts were reclassified to a regulatory asset.
2 Excludes expenses related to discontinued operations amounting to $1.3 million and $11.3 million for the years ended December 31, 2024 and 2023, respectively.
On May 4, 2024, HEI and the Utilities reached an agreement to settle indemnification claims asserted by the State of Hawaii without any admission of fault or responsibility. Under the terms of the agreement, HEI and the Utilities agreed to contribute up to $18.4 million through the end of 2024 related to the costs of the professional advisors engaged by the State of Hawaii to advise on a variety of matters related to the Maui windstorm and wildfires. Under certain circumstances, HEI and the Utilities have the unilateral right to terminate the agreement and stop paying the costs for future periods. As of December 31, 2024, a total of $18.4 million of such costs were accrued and reflected in Maui windstorm and wildfires related expenses-Other expense in the table above.
In addition, the Utilities incurred $8.7 million and $18.0 million of total capital costs related to the Maui windstorm and wildfires in 2024 and 2023, respectively.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Note 3 · Segment financial information
Reportable segments are strategic business units of the Company that offer different products and services and operate in different regulatory environments. Prior to December 31, 2024, the Company operated and reported on two reportable segments: Electric utility and bank. On December 31, 2024, the Company sold 90.1% of ASB (previously, the bank reportable segment) and presented its results as discontinued operations for all periods presented. Accordingly, the bank reportable segment has been eliminated and the segment information presented herein excludes the results of ASB for all periods presented. All comparable information for the historical periods has been recast to reflect the impact of these changes. The Company now operates and reports on 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.
The accounting policies of the segments are the same as those described for the Company in the summary of significant accounting policies, except as otherwise indicated and except that federal and state income taxes for each segment are calculated on a “stand-alone” basis. The Company’s chief operating decision makers (CODM) evaluate segment performance based on net income. Each segment accounts for intersegment sales and transfers as if the sales and transfers were to third parties (i.e., at current market prices). Intersegment revenues consist primarily of Hamakua Energy electricity revenues, interest and preferred stock dividends.
HEI’s CODM is its Chief Executive Officer. The CODM uses net income to evaluate income generated from segment assets (return on assets) in deciding whether to reinvest profits into the segments or into other parts of the entity, such as for acquisitions or to pay dividends. The CODM considers inputs from a variety of sources including the Chief Financial Officer, the General Counsel and presidents of operating units. Net income is used to monitor budget versus actual results. The CODM also uses net income in competitive analysis by benchmarking to HEI’s competitors. The competitive analysis along with the monitoring of budgeted versus actual results are used in assessing performance of the segment and in establishing management’s compensation. The segment level information that is regularly provided to the CODM does not include expense categories other than depreciation and amortization, interest expense, and income taxes.
Electric utility
Hawaiian Electric and its wholly owned operating subsidiaries, Hawaii Electric Light and Maui Electric, are public electric utilities in the business of generating, purchasing, transmitting, distributing and selling electric energy on all major islands in Hawaii other than Kauai, and are regulated by the PUC. Hawaiian Electric, Hawaii Electric Light, and Maui Electric are aggregated within the electric utility segment because they: (1) are involved in the business of supplying electric energy in the same geographical location (i.e., the State of Hawaii), (2) have similar production processes that comprise electric generation, (3) serve similar customers within their franchise territories (e.g., residential, commercial and industrial customers), (4) use similar electric grids to distribute the energy to their customers, (5) are regulated by the PUC and undergo similar rate-making processes, (6) have similar economic characteristics and (7) perform financial reporting oversight and management of the business at the consolidated level. Hawaiian Electric also owns the following nonregulated subsidiaries: Renewable Hawaii, Inc. (RHI), which was formed to invest in renewable energy projects; HE AR INTER LLC (HE AR INTER), which was formed to pursue financing through a secured asset-based (accounts receivable) credit facility. Both RHI and HE AR INTER are included within electric utility segment information provided to the CODMs.
Hawaiian Electric has determined that its CODMs are the Chief Executive Officer and Chief Financial Officer. Net income variance analysis is regularly provided to CODMs and it is used to monitor budget as well as measuring against performance to the same period in the previous year. The CODMs measure the segment performance based on the Hawaiian Electric consolidated net income and segment net income of Hawaii Electric Light and Maui Electric to make decisions to allocate resources. Hawaiian Electric concluded that all of the expense categories for its single reportable segment included in the Consolidated Statement of Income for Hawaiian Electric are the expense categories regularly provided to the CODMs and are significant.
All Other
“All Other” includes amounts for the holding companies (HEI and ASB Hawaii), GLST1, and Pacific Current and its subsidiaries and do not meet the definition of reportable segments.
ASB Hawaii. ASB Hawaii was formed in 1988 and served as the holding company for ASB prior to its sale on December 31, 2024. ASB Hawaii still retains a 9.9% noncontrolling investment in ASB.
GLST1. GLST1 was formed in 2024 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 legal claims in the litigation arising out of the Maui windstorm and wildfires.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Pacific Current. Pacific Current was formed in 2017 to focus on investing in non-regulated renewable energy and sustainable infrastructure in the State of Hawaii to help achieve the state’s sustainability goals. Significant investments of Pacific Current made through its subsidiaries, Hamakua Energy, Mauo, Kaʻieʻie Waho, and Mahipapa include:
Hamakua power plant. In 2017, Hamakua Energy acquired Hamakua Energy Partners, L.P.’s 60-MW combined cycle power plant and other assets from affiliates of ArcLight Capital Partners, a private equity firm. The plant sells all the power it produces to Hawaii Electric Light under an existing power purchase agreement (PPA) that expires in 2030.
Solar-plus-storage power purchase agreement. In 2018, Mauo executed definitive agreements to acquire a solar-plus-storage PPA for a multi-site, commercial-scale project that provides 8.1 MW of solar capacity and 42.6 megawatt-hours (MWh) of storage capacity on the islands of Maui and Oahu. The PPA has a 15-year term with a customer option to extend for an additional five years.
6-MW photovoltaic system. In 2020, Kaʻieʻie Waho acquired a 6-MW photovoltaic system situated on 20 acres of land on the island of Kauai. Kauai Island Utility Cooperative purchases all of the power generated by the system under a PPA that expires in 2033.
7.5-MW renewable, firm dispatchable closed-loop biomass-to-energy facility. In 2022, Mahipapa acquired a 7.5-MW renewable, firm dispatchable closed-loop biomass-to-energy facility on Kauai. Kauai Island Utility Cooperative purchases all of the power generated by the system under a PPA that expires in January 2036.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Electric utility reportable segment and All Other information were as follows:
(in thousands) Electric utility All Other
Total
Revenues $ 3,206,700 $ 13,150 $ 3,219,850
Depreciation and amortization 282,970 10,563 293,533
Interest income 6,633 12,729 19,362
Interest expense, net 82,082 45,125 127,207
Loss from continuing operations before income taxes
(1,663,914) (127,681) (1,791,595)
Income tax benefit
(439,547) (31,415) (470,962)
Loss from continuing operations
(1,224,367) (96,266) (1,320,633)
Preferred stock dividends of subsidiaries 1,995 (105) 1,890
Loss from continuing operations for common stock
(1,226,362) (96,161) (1,322,523)
Capital expenditures1
329,479 14,772 344,251
Assets (at December 31, 2024) 7,613,604 1,317,812 8,931,416
Revenues $ 3,269,521 $ 17,982 $ 3,287,503
Depreciation and amortization 270,195 12,111 282,306
Interest income 6,454 2,651 9,105
Interest expense, net 86,140 39,392 125,532
Income (loss) from continuing operations before income taxes
247,140 (64,840) 182,300
Income tax expense (benefit)
51,193 (16,659) 34,534
Income (loss) from continuing operations
195,947 (48,181) 147,766
Preferred stock dividends of subsidiaries 1,995 (105) 1,890
Income (loss) from continuing operations for common stock
193,952 (48,076) 145,876
Capital expenditures1
438,775 3,952 442,727
Assets (at December 31, 2023) 7,283,554 393,818 7,677,372
Revenues from external customers $ 3,408,583 $ 12,334 $ 3,420,917
Intersegment revenues (eliminations) 4 (4) -
Revenues 3,408,587 12,330 3,420,917
Depreciation and amortization 260,744 9,661 270,405
Interest expense, net 76,416 26,986 103,402
Income (loss) from continuing operations before income taxes
240,600 (38,646) 201,954
Income tax expense (benefit)
49,676 (10,761) 38,915
Income (loss) from continuing operations
190,924 (27,885) 163,039
Preferred stock dividends of subsidiaries 1,995 (105) 1,890
Income (loss) from continuing operations for common stock
188,929 (27,780) 161,149
Capital expenditures1
329,457 9,876 339,333
1 Contributions in aid of construction balances are included in capital expenditures.
Intercompany electricity sales of the Utilities to HEI and its other subsidiaries are not eliminated because those entities would need to purchase electricity from another source if it were not provided by the Utilities and the revenue and profit on such sales is nominal.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
Hamakua Energy’s sales to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation (see “related-party transactions” in Note 4).
Impairment of long-lived assets. HEI and Pacific Current have been undertaking a comprehensive review of strategic options for certain assets of Pacific Current. During the course of this process, in the third quarter of 2024, HEI and Pacific Current had determined it is 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, currently classified as held-and-used, are less than its carrying value. After performing a recoverability test of these assets, Pacific Current determined a portion of these long-lived assets of Pacific Current were not recoverable and therefore impaired. As a result, HEI and Pacific Current recorded a pretax asset impairment charge of $35.2 million in the third quarter of 2024. The impairment charge is recorded in “Other Expenses” in the Company’s Consolidated Statements of Income.
Sale of Hamakua Holdings, LLC. 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, LLC, a wholly owned subsidiary of Pacific Current, to an unaffiliated third party for cash consideration to be determined under the provisions of the agreement. Hamakua Holdings, LLC has two wholly-owned subsidiaries: Hamakua Energy, LLC, which owns a 60-MW combined cycle power plant that sells power to Hawaii Electric Light under an existing power purchase agreement, and HAESP, LLC (created in connection with the current on-going Stage 3 RFP process). Upon closing, both Hamakua Energy and HAESP, LLC as wholly-owned subsidiaries of Hamakua Holdings will no longer be owned by Pacific Current. The close of the transaction is subject to the satisfaction of certain customary closing conditions and is expected to be finalized in March 2025. The sale transaction is not expected to have a material impact to the Company’s consolidated financial statements.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 4 · Electric utility segment
Regulatory assets and liabilities. 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. Regulatory assets represent deferred costs and accrued decoupling revenues which are expected to be recovered through rates over PUC-authorized periods. Generally, the Utilities do not earn a return on their regulatory assets; however, they have been allowed to recover interest on certain regulatory assets and to include certain regulatory assets in rate base. Regulatory liabilities represent amounts included in rates and collected from ratepayers for costs expected to be incurred in the future, or amounts collected in excess of costs incurred that are refundable to customers. For example, the regulatory liability for cost of removal in excess of salvage value represents amounts that have been collected from ratepayers for costs that are expected to be incurred in the future to retire a utility plant. Generally, the Utilities include regulatory liabilities in rate base or are required to apply interest to certain regulatory liabilities. In the table below, noted in parentheses are the original PUC authorized amortization or recovery periods and, if different, the remaining amortization or recovery periods as of December 31, 2024 are noted.
Regulatory assets were as follows:
December 31 2024 2023
(in thousands)
Income taxes (1-35 years)
$ 81,102 $ 81,620
Retirement benefit plans (balance primarily varies with plans’ funded statuses) 13,755 70,616
Maui windstorm and wildfire related costs (to be determined by PUC)
52,652 14,692
Retirement of generating units (10 years)
40,953 29,930
Right-Of-Use (ROU) assets (25 years remaining)
19,105 9,067
ECRC/PPAC (1 year)
17,418 24,691
Vacation earned, but not yet taken (1 year)
13,950 14,585
Decoupling revenue balancing account and RAM (1 year)
9,829 19,002
Performance Incentive Mechanisms (PIMs) (1 year)
6,783 2,923
COVID-19 related costs (3 years)
6,715 8,715
Other (1-35 years remaining)
19,057 18,963
Total regulatory assets $ 281,319 $ 294,804
Included in:
Current assets $ 53,895 $ 68,453
Long-term assets 227,424 226,351
Total regulatory assets $ 281,319 $ 294,804
Regulatory liabilities were as follows:
December 31 2024 2023
(in thousands)
Cost of removal in excess of salvage value (1-79 years)
$ 601,741 $ 591,298
Income taxes (1-35 years)
292,036 303,225
Retirement benefit plans (balance primarily varies with plans’ funded statuses)
279,553 171,421
Solar tax credits (1-17 years)
46,661 49,507
Enterprise Resource Planning (ERP) Benefits (to be determined by PUC)
12,549 12,409
Decoupling revenue balancing account and RAM (1 year)
5,498 5,995
ECRC/PPAC (1 year)
4,296 15,169
Other (1 year remaining)
1,749 1,666
Total regulatory liabilities $ 1,244,083 $ 1,150,690
Included in:
Current liabilities $ 26,568 $ 36,559
Long-term liabilities 1,217,515 1,114,131
Total regulatory liabilities $ 1,244,083 $ 1,150,690
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The regulatory asset and liability relating to retirement benefit plans was recorded as a result of pension and OPEB tracking mechanisms adopted by the PUC in rate case decisions for the Utilities in 2007 (see Note 11).
Regulatory asset related to retirement of generating units.
Honolulu generating units 8 and 9. On December 22, 2023, the PUC issued a decision and order approving the Utilities’ request to establish a regulatory asset for the remaining net book value of the fossil fuel generating units for both Honolulu units 8 and 9 assets that retired on December 31, 2023, and amortize the regulatory asset over approximately nine years. The PUC also ruled that the Utilities may seek to include the regulatory asset in rate base and seek to recover the amortization expense and a return on the unamortized balance of the regulatory asset in the next rate case or rate re-setting proceeding. As of December 31, 2024, the Utilities have recorded $26.7 million in regulatory assets for the remaining net book value of Honolulu generating units 8 and 9.
Waiau generating units 3 and 4. On September 30, 2024, the PUC issued a decision and order approving the Utilities’ request to establish a regulatory asset for the remaining net book value of the fossil fuel generating units for both Waiau units 3 and 4 assets that retired on December 31, 2024, and amortize the regulatory asset over approximately nine years. The PUC also ruled that the Utilities may seek to include the regulatory asset in rate base and seek to recover the amortization expense and a return on the unamortized balance of the regulatory asset in the next rate case or rate re-setting proceeding. As of December 31, 2024, the Utilities have recorded $14.3 million in regulatory assets for the remaining net book value of Waiau generating units 3 and 4.
Regulatory assets for Maui windstorm and wildfires related costs. On December 27, 2023, the PUC issued an order authorizing deferred accounting treatment for the Utilities’ incremental non-labor expenses under specific cost categories related to the August 2023 Maui windstorm and wildfires. The deferred accounting treatment authorized, applied to certain non-labor expenses incurred from August 8, 2023 through December 31, 2024 that are not already a part of base rates.
As of December 31, 2024, the Utilities have recorded $52.7 million in regulatory assets for the incremental costs incurred related to the Maui windstorm and wildfires event.
On November 27, 2024, the Utilities filed a request with the PUC to extend the deferral accounting period to December 31, 2025, specifically limited to insurance premiums and outside services and legal costs associated with the asset-based lending facility credit agreement (see Note 6). On February 12, 2025, the PUC issued an order granting the Utilities’ request to extend.
Requests for cost recovery of deferred costs will be the subject of a separate application at which time the PUC will evaluate whether such costs were prudently incurred and reasonable and determine the extent to which such costs will be eligible for recovery, and the period over which recovery will occur. If the PUC denies recovery of any deferred costs, such costs would be charged to expense in the period that those costs are no longer considered probable of recovery.
Regulatory liabilities for Enterprise Resource Planning/Enterprise Asset Management (ERP/EAM). The ERP/EAM Implementation Project went live in October 2018. Hawaii Electric Light and Hawaiian Electric began to incorporate their portion of the deferred project costs in rate base and started the amortization over a 12-year period in January 2020 and November 2020, respectively. The PUC required a minimum of $246 million ERP/EAM project-related benefit to be delivered to customers over the system’s 12-year service life.
In February 2019, the PUC approved a methodology for passing the future cost saving benefits of the ERP/EAM system to customers developed by the Utilities in collaboration with the Consumer Advocate. The Utilities filed a benefits clarification document on June 10, 2019, reflecting $150 million in future net other operation and maintenance (O&M) expense reductions and cost avoidance, and $96 million in capital cost reductions and tax savings over the 12-year service life. To the extent the reduction in O&M expense relates to amounts reflected in electric rates, the Utilities would reduce future rates for such amounts. In October 2019, the PUC approved the Utilities and the Consumer Advocate’s Stipulated Performance Metrics and Tracking Mechanism. As part of the settlement agreement approved in the Hawaiian Electric 2020 test year rate case, the regulatory liability for Hawaiian Electric will be amortized over five years, beginning in November 2020, and the O&M benefits for Hawaiian Electric was considered flowed through to customers. On December 29, 2023, the PUC approved the Utilities’ proposal to accelerate flow-through of the ERP benefits savings currently tracked in regulatory liability accounts to Hawaii Electric Light and Maui Electric customers as part of the customer dividend in the ARA, to mitigate the impact of the Utilities’ recovery of the COVID-19 related costs on customers. See “Regulatory assets for COVID-19 related costs” section below.
As of December 31, 2024, the Utilities’ regulatory liability was $12.5 million ($1.2 million for Hawaiian Electric, $4.5 million for Hawaii Electric Light and $6.8 million for Maui Electric) for the O&M expense savings that are being amortized or to be included in future rates. At the PUC’s direction, the Utilities have been filing Annual Enterprise System Benefits (AESB) report on the achieved benefits savings.
Regulatory assets for COVID-19 related costs. On December 29, 2023, the PUC issued a decision and order (December 2023 D&O) approving the Utilities’ request to recover the COVID-19 related deferred costs up to $8.8 million evenly over a
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
three-year recovery period from 2024 through 2026 through the Z-factor in the ARA. Following the Utilities’ motion for clarification or in the alternative partial reconsideration of the December 2023 D&O, on February 27, 2024, the PUC issued an order clarifying the December 2023 D&O and approving, among other things, the Utilities’ requests to base the recovery on the recorded balances as of December 31, 2023 and to modify the recovery period to begin June 1, 2024 and end May 31, 2027. As of December 31, 2024, the Utilities have recorded $6.7 million in regulatory assets for deferral of COVID-19 related costs.
Regulatory assets for suspension of disconnections related costs. Based on circumstances related to the Maui windstorm and wildfires, on August 31, 2023 and subsequently on October 13, 2023, the PUC issued orders directing all regulated utilities located on, or providing utility service on Maui, including the Utilities, among other things, (i) to suspend disconnections of services and associated disconnection fees beginning from August 8, 2023, through the end of the emergency relief period established by the Governor’s Emergency Proclamations related to the Maui windstorm and wildfires, which currently continues through April 5, 2025 (Suspension Period); (ii) to suspend any and all rules and provisions of individual utility tariffs that prevent or condition re-connection of disconnected customers during the Suspension Period; (iii) not to charge customers interest on past due payments or impose any late payment fees through the Suspension Period; (iv) to establish regulatory assets to record costs directly related to the suspension of disconnections, and to record receipt of governmental aid and donation-based aid, loans or grants, and/or all other assistance measures, and any cost savings realized; and (v) to file a notice with the PUC regarding any upcoming application or other request pursuant to HRS Sections 269-16.3, -17, -17.5, -18, -19, or -19.5 and/or regarding any significant financial change to the Maui utility, at least 60 days prior to filing such application or other request with the PUC. The orders also discourage the filing of emergency or general rate increases in response to the emergency situation. In future proceedings, the PUC will assess the utility’s request for recovery of these regulatory assets including whether it is reasonable and necessary, the appropriate period of recovery for the approved amount of regulatory assets, any amount of carrying costs thereon, any savings directly attributable to suspension of disconnects, and other related matters. As of December 31, 2024, the Utilities have recorded $2.8 million in regulatory assets for the incremental costs incurred due to the suspension of disconnections.
Major customers. The Utilities received 11% ($369 million), 12% ($376 million) and 12% ($393 million) of their operating revenues from the sale of electricity to various federal government agencies in 2024, 2023 and 2022, respectively.
Cumulative preferred stock. The following series of cumulative preferred stock are redeemable only at the option of the respective company at the following prices in the event of voluntary liquidation or redemption:
December 31, 2024 Voluntary
liquidation price Redemption
price
Series
C, D, E, H, J and K (Hawaiian Electric) $ 20 $ 21
I (Hawaiian Electric) 20 20
G (Hawaii Electric Light) 100 100
H (Maui Electric) 100 100
Hawaiian Electric is obligated to make dividend, redemption and liquidation payments on the preferred stock of each of its subsidiaries if the respective subsidiary is unable to make such payments, but this obligation is subordinated to Hawaiian Electric’s obligation to make payments on its own preferred stock.
Related-party transactions. HEI charged the Utilities $5.5 million, $5.2 million and $5.6 million for general management and administrative services in 2024, 2023 and 2022, respectively. The amounts charged by HEI to its subsidiaries for services provided by HEI employees are allocated primarily on the basis of time expended in providing such services.
In 2024, 2023 and 2022, Hamakua Energy (an indirect subsidiary of HEI) sold energy and capacity to Hawaii Electric Light (subsidiary of Hawaiian Electric and indirect subsidiary of HEI) under a power purchase agreement (PPA) in the amount of $35 million, $71 million and $66 million, respectively.
Hawaiian Electric’s short-term borrowings from HEI totaled nil at December 31, 2024 and 2023. Borrowings among the Utilities are eliminated in consolidation. Interest charged by HEI to Hawaiian Electric was nil for the years ended December 31, 2024 and 2023.
Consolidated variable interest entities. The HE AR INTER LLC and its direct subsidiary, HE AR BRWR LLC, (collectively, the SPEs) are bankruptcy remote, direct and indirect wholly owned subsidiaries of the Utilities. Pursuant to the asset-based lending facility (ABL Facility) credit agreement, the Utilities sells certain accounts receivable to the SPEs as collateral, which in turn, obtain financing from financial institutions. As of December 31, 2024, the ABL Facility remains undrawn and the SPEs have $324.7 million of net accounts receivable, included in “Customer accounts receivable, net”, and “Accrued unbilled
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
revenues, net”, on the Utilities’ Consolidated Balance Sheet and “Accounts receivable and unbilled revenues, net”, on the Company’s Consolidated Balance Sheet.
The SPEs are considered VIEs due to insufficient equity investment at risk. The most significant activities that impact the economic performance of the SPEs are cash and financing management. The Utilities are considered the primary beneficiary as the Utilities direct the activities related to cash and financing management and therefore, are required to consolidate the SPEs. Although the SPEs are direct and indirect wholly owned consolidated subsidiaries of the Utilities, the SPEs are legally separate from the Utilities. The assets of the SPEs (which are primarily accounts receivables) are not available to creditors of the Utilities.
Unconsolidated variable interest entities.
Power purchase agreements. As of December 31, 2024, the Utilities had four power purchase agreements (PPAs) for firm capacity and other PPAs with independent power producers (IPPs) and Schedule Q providers (i.e., customers with cogeneration and/or power production facilities who buy power from or sell power to the Utilities), none of which are currently required to be consolidated as VIEs.
Pursuant to the current accounting standards for VIEs, the Utilities are deemed to have a variable interest in Kalaeloa Partners, L.P. (Kalaeloa) and Hamakua Energy by reason of the provisions of the PPA that the Utilities have with the two IPPs. However, management has concluded that the Utilities are not the primary beneficiary of Kalaeloa and Hamakua Energy because the Utilities do not have the power to direct the activities that most significantly impact the two IPPs’ economic performance nor the obligation to absorb their expected losses, if any, that could potentially be significant to the IPPs. Thus, the Utilities have not consolidated Kalaeloa and Hamakua Energy in its consolidated financial statements. However, Hamakua Energy is an indirect subsidiary of Pacific Current and is consolidated in HEI’s consolidated financial statements.
For the other PPAs with IPPs, the Utilities have concluded that the consolidation of the IPPs was not required because either the Utilities do not have variable interests in the IPPs due to the absence of an obligation in the PPAs for the Utilities to absorb any variability of the IPPs, or the IPP was considered a “governmental organization,” and thus excluded from the scope of accounting standards for VIEs. The consolidation of any significant IPP could have a material effect on the consolidated financial statements, including the recognition of a significant amount of assets and liabilities and, if such a consolidated IPP were operating at a loss and had insufficient equity, the potential recognition of such losses. If the Utilities determine they are required to consolidate the financial statements of such an IPP and the consolidation has a material effect, the Utilities would retrospectively apply accounting standards for VIEs to the IPP.
Commitments and contingencies.
Contingencies. The Utilities are subject in the normal course of business to legal, regulatory and environmental proceedings. Excluding the potential liabilities from the Maui windstorm and wildfires, management does not anticipate that the aggregate ultimate liability arising out of these pending or threatened legal proceedings will be material to its financial position. However, the Utilities cannot rule out the possibility that such outcomes could have a material effect on the results of operations or liquidity for a particular reporting period in the future. The Utilities record loss contingencies when the outcome of such proceedings is probable and when the amount of the loss is reasonably estimable. The Utilities also evaluate, on a continuous basis, whether developments in such proceedings could cause these assessments or estimates to change. Assessment regarding future events is required when evaluating whether a loss is probable or reasonably possible, and as to whether such loss or a range of such loss is estimable. Management is often unable to estimate a reasonably possible loss, or a range of loss, particularly in cases in which: (i) the damages sought are indeterminate or the basis for the damages claimed is not clear; (ii) proceedings are in early stages; (iii) discovery is not complete; (iv) the matters involve novel or unsettled legal theories; (v) significant facts are in dispute; (vi) a large number of parties are represented (including circumstances in which it is uncertain how liability, if any, would be shared among multiple defendants); (vii) a lower court or administrative agency’s decision or ruling has been appealed; and/or (viii) a wide range of potential outcomes exist. In such cases, there may be considerable uncertainty regarding the timing or ultimate resolution, including any possible loss, fine, penalty, or business impact.
August 2023 Maui windstorm and wildfires. See Note 2.
Hu Honua Bioenergy, LLC (Hu Honua). In May 2012, Hawaii Electric Light signed a PPA, which the PUC approved in December 2013, with Hu Honua for 21.5 MW of renewable, dispatchable firm capacity fueled by locally grown biomass from a facility on the island of Hawaii. Under the terms of the PPA, the Hu Honua plant was scheduled to be in service in 2016. However, Hu Honua encountered construction and litigation delays, which resulted in the termination of the original PPA. Following the termination, Hu Honua filed a lawsuit in the U.S. District Court for the District of Hawaii. The parties reached a settlement that was conditioned on the PUC’s timely, non-appealable final approval of an amended and restated PPA dated May 9, 2017. On May 23, 2022, following a contested case hearing, the PUC issued a decision and order denying the amended and restated PPA, based on, among other things, findings that: (1) the project will result in significant greenhouse gas (GHG)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
emissions, (2) Hu Honua’s proposed carbon commitment to sequester more GHG emissions than produced by the project are speculative and unsupported, (3) the amended and restated PPA is likely to result in high costs to customers through its relatively high cost of electricity and through potential displacement of other, lower cost, renewable resources, and (4) based on the foregoing, approving the amended and restated PPA is not prudent or in the public interest. On June 2, 2022, Hawaii Electric Light and Hu Honua filed their separate motions for reconsideration, which were denied by the PUC on June 24, 2022. On June 29, 2022, Hu Honua filed its notice of appeal to the Hawaii Supreme Court of the PUC’s May 23, 2022 decision and order denying the amended and restated PPA. On March 13, 2023, the Hawaii Supreme Court affirmed the PUC’s decision denying the amended and restated PPA between Hu Honua and Hawaii Electric Light and entered its judgment on appeal on April 12, 2023. On June 7, 2023, Hu Honua filed a status report with the U.S. District Court for the District of Hawaii, stating, among other things, that because settlement of the underlying federal lawsuit was contingent on timely, non-appealable, final approval of the amended and restated PPA by the PUC, that the Hawaii Supreme Court’s opinion made fulfillment of the condition impossible, and therefore the settlement agreement between the Hawaiian Electric defendants (HEI, Hawaiian Electric, and Hawaii Electric Light) and Hu Honua is null and void and of no further effect. On November 16, 2023, Hu Honua filed its Motion for Leave to File Third Amended and Supplemental Complaint and for Permissive Joinder with the U.S. District Court for the District of Hawaii, asking the court to grant it leave to file a Third Amended and Supplemental Complaint, which would amend its claims and add three new proposed defendants. The hearing on this motion took place on February 14, 2024. The court issued a decision and order on the motion on April 2, 2024, which was consistent with Hawaii Electric Light's position, only allowing amendments that were agreed to and not allowing Hu Honua to add new claims or parties, effectively leaving Hu Honua with its previously-pled breach of contract and antitrust claims. Hu Honua filed its objection to the order on April 16, 2024 and the Hawaiian Electric defendants filed their response to the objection on April 30, 2024. A hearing on Hu Honua’s objection took place on July 30, 2024. On September 12, 2024, the court issued its decision affirming the April 2, 2024 order. Hu Honua filed its Third Amended and Supplemental Complaint on October 25, 2024, and after discussion with the Hawaiian Electric defendants and the court, filed its Amended Third Amended and Supplemental Complaint on December 3, 2024. The Hawaiian Electric defendants filed their Motion to Compel Arbitration on the contract claims and Motion to Dismiss the antitrust claims on January 7, 2025, and the matter is set for hearing on March 31, 2025.
Molokai New Energy Partners (MNEP). In July 2018, the PUC approved Maui Electric’s PPA with MNEP to purchase solar energy from a photovoltaic (PV) plus battery storage project. The 4.88 MW PV and 3 MW Battery Energy Storage System (BESS) project was to deliver no more than 2.64 MW at any time to the Molokai system. On March 25, 2020, MNEP filed a complaint in the United Stated District Court for the District of Hawaii against Maui Electric claiming breach of contract. On June 3, 2020, Maui Electric provided a Notice of Default and Termination of the PPA to MNEP terminating the PPA with an effective date of July 10, 2020. Thereafter, MNEP filed an amended complaint to include claims relating to the termination and Hawaiian Electric filed its answer to the amended complaint on September 11, 2020, disputing the facts presented by MNEP and all claims within the original and amended complaint. Currently, the discovery phase is ongoing.
Environmental regulation. The Utilities are subject to environmental laws and regulations that regulate the operation of existing facilities, the construction and operation of new facilities and the proper cleanup and disposal of hazardous waste and toxic substances.
Hawaiian Electric, Hawaii Electric Light and Maui Electric, like other utilities, periodically encounter petroleum or other chemical releases associated with current or previous operations. The Utilities report and take action on these releases when and as required by applicable law and regulations. The Utilities believe the costs of responding to such releases identified to date will not have a material effect, individually or in the aggregate, on Hawaiian Electric’s consolidated results of operations, financial condition or liquidity.
Former Molokai Electric Company generation site. In 1989, Maui Electric acquired Molokai Electric Company. Molokai Electric Company had sold its former generation site (Site) in 1983 but continued to operate at the Site under a lease until 1985 and left the property in 1987. The Environmental Protection Agency (EPA) has since identified environmental impacts in the subsurface soil at the Site. In cooperation with the State of Hawaii Department of Health and EPA, Maui Electric further investigated the Site and the adjacent parcel to determine the extent of impacts of polychlorinated biphenyls (PCBs), residual fuel oils and other subsurface contaminants. Maui Electric has a reserve balance of $2.5 million as of December 31, 2024, representing the probable and reasonably estimable undiscounted cost for remediation of the Site and the adjacent parcel based on presently available information; however, final costs of remediation will depend on the cleanup approach implemented.
Pearl Harbor sediment study. In July 2014, the U.S. Navy notified Hawaiian Electric of the Navy’s determination that Hawaiian Electric is a Potentially Responsible Party under CERCLA responsible for the costs of investigation and cleanup of PCB contamination in sediment in the area offshore of the Waiau Power Plant as part of the Pearl Harbor Superfund Site. Hawaiian Electric was also required by the EPA to assess potential sources and extent of PCB contamination onshore at Waiau Power Plant.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
As of December 31, 2024, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $9.5 million. The reserve balance represents the probable and reasonably estimable undiscounted cost for the onshore and offshore investigation and remediation. The final remediation costs will depend on the actual onshore and offshore cleanup costs.
Endangered Species Act (ESA). The Utilities received a 60-day Notice under the federal Endangered Species Act, from Earthjustice on behalf of the American Bird Conservancy and Conservation Council for Hawaii (Conservation Groups) in January 2024. The 60-day Notice (Notice) is the pre-cursor to a citizen’s suit under the Endangered Species Act. The Notice alleges that the Utilities are out of compliance with the Act due to alleged impacts on endangered seabirds caused by the Utilities’ powerlines, street lights and facility lights on Maui and Lanai. At the time the Notice was served, the Utilities were already in the process of drafting a Habitat Conservation Plan (HCP) with respect to the powerlines and will be applying for associated state and federal take/license permits. Notwithstanding, the Notice asserts that the scope of the HCP should be broader and additional interim measures are necessary while the HCP and related permits are pending. After negotiations among the parties a complaint was filed on November 12, 2024, regarding the powerlines and on December 11, 2024, the Court approved a settlement agreement. Pursuant to that agreement the Utilities will continue the HCP process and take specific actions to minimize and mitigate the potential impact of the Utilities’ powerlines while the document is being prepared. The agreement also contains additional requirements that include coordination with the Conservation Groups with various aspects of the HCP and powerline operations, and continuing the Utilities’ commitment to a species mitigation project with University of Hawaii Foundation to monitor, protect and increase the population of Hawaiian Petrels. The street and facility lights aspect of the Notice was not resolved and a second complaint was filed on November 19, 2024 that includes the County of Maui as a party. At this time, the parties are engaging in settlement discussions and the Utilities are unable to determine the ultimate outcome or the amount of any possible loss.
Commitments.
Purchase commitments. As of December 31, 2024, the Utilities’ estimated future minimum payments pursuant to purchase obligations related to material contracts for the following five years and thereafter are as follows:
Payments Due
(in millions) 2025
Thereafter
Total
Firm capacity PPAs
$ 75 $ 75 $ 75 $ 70 $ 70 $ 225 $ 590
Renewable dispatchable generation plus energy storage and energy storage PPAs 77 77 77 77 77 1,174 1,559
Other renewable PPA
- 1 4 4 4 69 82
Fuel transportation
7 7 2 - - - 16
Total
$ 159 $ 160 $ 158 $ 151 $ 151 $ 1,468 $ 2,247
Firm capacity PPAs. The Utilities are committed to purchase from four firm capacity PPAs for a total of 368.7 megawatts (MW) of firm capacity, which expire at various dates through 2033.
Renewable dispatchable generation plug energy storage and energy storage PPAs. The Utilities also have long-term renewable PPAs with IPPs from the issuances of Stage 1 and 2 request for proposals in 2018 and 2019, respectively. The Utilities have additional annual payments of $28 million when three projects began commercial operations in 2024. As of December 31, 2024, a total of seven projects provides the Utilities capacity of 219.5 MW, with 1,443 MWh batteries. The contracts expire at various dates through 2049.
Other renewable PPA. The Utilities also have a long-term renewable PPA that provides the Utilities capacity of 10.56 MW, which expires in 2046.
Fuel transportation lease contract. The Utilities entered into an inter-island fuel transportation contract, expiring in 2027.
The PUC has approved PPACs for the Utilities to recover purchased power capacity, operation and maintenance (O&M) and other non-energy costs related to all aforementioned PPAs. In addition, the Utilities are able to recover fuel component of the energy charges for firm capacity PPAs as well as costs associated to fuel transportation through ECRC.
In general, the Utilities base their payments under the PPAs upon available capacity and actual energy supplied and they are generally not required to make payments for capacity if the contracted capacity is not available, and payments are reduced, under certain conditions, if available capacity drops below contracted levels. In general, the payment rates for capacity have been predetermined for the terms of the agreements. The Utilities do not operate, or participate in the operation of, any of the facilities that provide power under the agreements. Title to the facilities does not pass to Hawaiian Electric or its subsidiaries upon expiration of the agreements, and the agreements do not contain bargain purchase options for the facilities.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Purchases from all IPPs were as follows:
Years ended December 31 2024 2023 2022
(in millions)
Kalaeloa $ 291 $ 298 $ 342
AES Hawaii1
- - 82
HPOWER 74 70 73
Hamakua Energy
35 71 66
Puna Geothermal Venture 56 38 48
Kapolei Energy Storage
24 - -
Wind IPPs 130 125 119
Solar IPPs 84 72 57
Other IPPs2
9 (2) 7
Total IPPs $ 703 $ 672 $ 794
1 The term of the PPA with AES Hawaii expired on September 1, 2022 and the AES Hawaii coal plant ceased operations.
2 Includes hydro power and other PPAs.
Utility projects. Many public utility projects require PUC approval and various permits from other governmental agencies. Difficulties in obtaining, or the inability to obtain, the necessary approvals or permits or community support can result in significantly increased project costs or even cancellation of projects. In the event a project does not proceed, or if it becomes probable the PUC will disallow cost recovery for all or part of a project, or if PUC-imposed caps on project costs are expected to be exceeded, project costs may need to be written off in amounts that could result in significant reductions in Hawaiian Electric’s consolidated net income.
Waena Switchyard/Synchronous Condenser Project. In October 2020, to support efforts to increase renewable energy generation and reduce fossil fuel consumption by deactivating current generating units, Maui Electric filed a PUC application to construct a switchyard, which includes the extension of two 69 kV transmission lines and the relocation of another 69 kV transmission line; and the conversion of two generating units to synchronous condensers at Kahului Power Plant in central Maui. In November 2021, the PUC approved Maui Electric’s request to commit funds estimated at $38.8 million for the project, and to recover capital expenditures for the project under Exceptional Project Recovery Mechanism (EPRM) not to exceed $38.8 million, which shall be further reduced to reflect the total project cost exclusive of overhead costs not directly attributable to the project. The Waena Switchyard was placed in service on October 25, 2023. Maui Electric petitioned and received from the State of Hawaii Department of Health a one-year extension to the mandatory retirement of Kahului Power Plant and there is now flexibility to operate the units until the end of 2028. The conversion of the two generating units will be performed after the retirement of Kahului Power Plant Units 3 and 4.
In approving the project, the PUC recognized that the project will facilitate the ability to accommodate increased renewable energy, as contemplated under the EPRM guidelines. As of December 31, 2024, $25.5 million has been incurred for the project.
Waena Battery Energy Storage System Project. In September 2020, Maui Electric filed a PUC application to purchase and install a 40 MW BESS at its Waena Site in Central Maui. In December 2023, the PUC approved Maui Electric’s request to commit funds estimated at $82.1 million, for the purchase and installation of the project, and to recover costs for the project under EPRM. Project costs incurred as of December 31, 2024 amount to $6.7 million.
Climate Adaptation Transmission and Distribution Resilience Program. The Utilities maintain that improving resiliency of the electric grid is an urgent matter and recognizes that climate change is making Hawaii increasingly vulnerable to sever weather events. On January 31, 2024, the PUC approved the Utilities’ request to commit an estimated $189.7 million in funds for the Climate Adaptation Transmission and Distribution Resilience Program, over a project period of five years. The project is to focus on, among other things, system hardening in wildfire risk areas to prevent ignition and to enable quicker response, video camera and weather monitors in wildfire risk areas and to add situational awareness, and strengthening transmission lines.
The project costs to be recovered through EPRM is subject to a cap of $95 million and any amount in excess will be subject to the PUC’s further review. On August 7, 2024, the Utilities received a notification from the U.S. Department of Energy that its application for $95 million in federal funds under the Infrastructure Investment and Jobs Act (IIJA) was officially awarded. On August 20, 2024, the Utilities submitted a copy of their executed agreement with the Department of Energy to the PUC. On November 18, 2024, the Utilities filed their August 2024 - August 2025 Forward Looking Annual Report. Project costs incurred as of December 31, 2024 amount to $9.7 million.
In January 2025, President Trump issued multiple Executive Orders (EOs) that impact both IIJA and IRA funding. EO 14154 entitled Unleashing American Energy ordered to immediately pause disbursement of funds appropriated through IIJA and IRA grants, which is causing delays in processing the Utilities’ requests for reimbursement for the Resilience Program and
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
may potentially lead to project delays and economic uncertainty. The EO entitled Ending Radical and Wasteful Government DEI Programs and Preferencing resulted in the federal contracting officer ordering recipients to cease all diversity, equity and inclusion and community benefits plan activities funded by federal grants as of January 28, 2025, which could potentially impact the Utilities’ existing community benefits agreements with some third parties and commitments included in the Resilience Program project costs.
Asset retirement obligations. Asset retirement obligations (AROs) represent legal obligations associated with the retirement of certain tangible long-lived assets, are measured as the present value of the projected costs for the future retirement of specific assets and are recognized in the period in which the liability is incurred if a reasonable estimate of fair value can be made. The Utilities’ recognition of AROs have no impact on their earnings. The cost of the AROs is recovered over the life of the asset through depreciation. AROs recognized by the Utilities relate to legal obligations associated with the retirement of plant and equipment, including removal of asbestos and other hazardous materials.
The Utilities recorded AROs related to: 1) the removal of retired generating units, certain types of transformers and underground storage tanks; 2) the abandonment of fuel pipelines, underground injection and supply wells; and 3) the removal of equipment and restoration of leased land used in connection with Utility-owned renewable and dispatchable generation facilities.
Changes to the ARO liability included in “Other liabilities” on Hawaiian Electric’s balance sheet were as follows:
(in thousands) 2024 2023
Balance, January 1 $ 12,009 $ 11,548
Accretion expense 484 463
Liabilities incurred - -
Liabilities settled (1) (2)
Balance, December 31 $ 12,492 $ 12,009
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 Utilities-owned generating facilities and certain electric transmission, distribution and telecommunications assets resulting from easements over property not owned by the Utilities.
Regulatory proceedings.
Decoupling. Decoupling is a regulatory model that is intended to provide the Utilities with financial stability and facilitate meeting the State of Hawaii’s goals to transition to a clean energy economy and achieve an aggressive renewable portfolio standard. Decoupling delinks the utility’s revenues from the utility’s sales, removing the disincentive to promote energy efficiency and accept more renewable energy. Decoupling continues under the PBR Framework.
Performance-based regulation framework. On December 23, 2020, the PUC issued a decision and order (PBR D&O) establishing the PBR Framework to govern the Utilities. The PBR Framework incorporates an annual revenue adjustment (ARA) and a suite of new regulatory mechanisms in addition to previously established regulatory mechanisms. Under the PBR Framework, the decoupling mechanism (i.e., the Revenue Balancing Account (RBA)) established by the previous regulatory framework will continue. The existing cost recovery mechanisms continued as previously implemented (e.g., the Energy Cost Recovery Clause, Purchased Power Adjustment Clause (PPAC), Demand-Side Management surcharge, Renewable Energy Infrastructure Program, Demand Response Adjustment Clause, Pension and Other Post-Employment Benefits (OPEB) tracking mechanisms). In addition to annual revenues provided by the ARA, the Utilities may seek relief for extraordinary projects or programs through the Exceptional Project Recovery Mechanism (EPRM) (formerly known as the Major Project Interim Recovery adjustment mechanism) and earn financial rewards for exemplary performance as provided through a portfolio of Performance Incentive Mechanisms (PIMs) and Shared Savings Mechanisms (SSMs). The PBR Framework incorporates a variety of additional performance mechanisms, including Scorecards, Reported Metrics, and an expedited Pilot Process. The PBR Framework also contains a number of safeguards, including a symmetric Earnings Sharing Mechanism (ESM) which protects the Utilities and customers from excessive earnings or losses, as measured by the Utilities’ achieved rate-making ROACE and a Re-Opener mechanism, under which the PUC will open an examination, at its discretion, to determine if adjustments or modifications to specific PBR mechanisms are appropriate. The PBR Framework became fully effective on June 1, 2021.
On June 17, 2022, the PUC issued a decision and order (June 2022 D&O) establishing additional PIMs under the PBR Framework for the Utilities. The June 2022 D&O approved two PIMs, a SSM, and extended the timeframe for an existing PIM. Specifically, the PUC approved (1) a (penalty-only) generation-caused interruption reliability PIM, (2) a (penalty/reward) interconnection requirements study PIM, (3) a (reward-only) Collective Shared Savings Mechanism (CSSM), and (4) a
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
modification and extension of the existing Interim Grid Services PIM (reward-only). On November 23, 2022, the PUC approved the Utilities’ proposed tariffs to implement the aforementioned PIMs with an effective date of January 1, 2023.
In addition, the June 2022 D&O instructed the Utilities to prepare and submit: a detailed fossil fuel retirement report (FF Retirement Report) outlining necessary steps to safely and reliably retire certain existing fossil fuel power plants during the first multi-year rate period (MRP); and a functional integration plan (FIP) for distributed energy resources (DER) to increase transparency into the Utilities’ plans and progress for utilizing cost-effective grid services from DERs and ensure that the necessary functionalities and requisite technologies are in place to do so. The PUC also instructed the PBR Working Group to continue its ongoing collaborative efforts to consider other potential new incentive mechanisms and to address other issues raised during the proceeding. On March 30, 2023, the PUC held a PBR Working Group coordination meeting to initiate subgroups on the Long-Term Grid Services PIM, modification/evaluation of existing PIMs, and comprehensive PBR Framework review priority topics.
In accordance with the June 2022 D&O, the Utilities filed their FIP on September 30, 2022, Long-Term Grid Services PIM proposal on July 3, 2023, and FF Retirement Report on October 11, 2024.
On October 16, 2023, the Utilities filed a request for limited suspension of the Transmission and Distribution (T&D) System Average Interruption Duration Index (SAIDI) PIM, the T&D System Average Interruption Frequency Index (SAIFI) PIM, and the target heat rate provision of Maui Electric Maui Division’s Energy Cost Recovery Clause (ECRC) tariff starting from August 8, 2023. On December 28, 2023, the PUC issued an order granting a temporary suspension of Maui Electric’s T&D SAIDI and SAIFI PIMs and Maui Electric Maui Division’s target heat rate provision from August 8, 2023 through June 30, 2024, which the tariffs became effective on January 1, 2024.
On November 3, 2023, the Utilities, Ulupono Initiative LLC, and the County of Hawaii filed a stipulation on proposed modifications to the RPS-A, Call Center, AMI Utilization, and interconnection requirements study PIMs. On June 24, 2024, the PUC issued an order (1) approving modifications to the interconnection requirements study PIM to expand its application to firm generation projects effective August 1, 2024, (2) approving a consolidated target for the Call Center PIM and modifying the target performance based on the average of the Utilities’ performance, weighted by the number of calls for the last eight quarters as of December 31, 2023, effective August 1, 2024, (3) denying the proposed modifications to the RPS-A PIM and clarifying that it will continue to operate according to its existing tariff language; and (4) denying the proposed modifications to the AMI Utilization PIM and declining to extend the PIM beyond its scheduled sunset date of December 31, 2023.
On December 26, 2023, the PUC issued an order (1) confirming that the Interim Grid Services PIM will sunset on December 31, 2023, (2) extending the Interconnection Approval PIM through December 31, 2024, and (3) determining that it will continue examination of the Long-Term Grid Services PIM into 2024 as part of a broader examination that addresses barriers to the utilization of DERs to meet grid needs.
On April 1, 2024, the Utilities filed a request for partial temporary suspension and modification of the T&D SAIDI and T&D SAIFI PIMs to specifically suspend the T&D SAIDI and T&D SAIFI PIMs for wildfire risk circuits from January 1, 2024 to December 31, 2025. The Utilities also proposed that circuits not identified as wildfire risk circuits would continue to be subject to the existing PIMs on a prorated basis. On December 18, 2024, as clarified on January 15, 2025, the PUC issued orders granting the Utilities’ request to suspend the T&D SAIDI and T&D SAIFI PIMs for wildfire risk circuits from January 1, 2024 to December 31, 2025.
On June 19, 2024, the PUC issued an order (June 2024 order) providing preliminary guidance regarding the comprehensive evaluation of the PBR Framework that will commence in the fourth year of the PBR Framework’s first MRP (PBR Framework Review). The PUC has developed a high-level review structure and timeline for the PBR Framework Review and divided the remainder of the first MRP into three phases: (i) the evaluation of the current PBR Framework, (ii) the examination of proposal for modifications to the PBR Framework, and (iii) the implementation of modifications prior to commencing the second MRP. At the PBR Working Group meeting held on June 26, 2024, the PUC staff solicited the parties’ feedback on the scope of the PBR Framework Review and discussed other considerations, including rebasing target revenues. On July 19, 2024, as requested by the PUC staff, the parties filed written feedback to materials presented and discussed at the June Working Group meeting and in the June 2024 order.
On July 30, 2024, the PUC issued an order providing further guidance on the first of the three phases of the PBR Framework Review established by the June 2024 order. The first phase will focus on the evaluation of the individual PBR mechanisms using an informal, collaborative process. Parties will submit briefing on their evaluation of the individual PBR mechanisms near the end of the first phase, followed by a decision and order summarizing the findings of the evaluation, including which PBR mechanisms will be subject to additional examination and potential modification in the second phase of the PBR Framework Review. At the PBR Working Group meetings held on August 30, 2024 and October 25, 2024, the Working Group discussed issues and considerations regarding re-basing target revenues for the next MRP. Series of PBR Working Group meetings are expected to be held with the parties. Timely briefs addressing the issues of whether and how to
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
rebase target revenues were filed on December 5, 2024. Pending the PUC’s review and issuance of an Order on the briefings, the PBR Working Group will continue its evaluation of the PBR Framework as part of this proceeding.
Annual revenue adjustment mechanism. The PBR Framework established a five-year MRP during which there will be no general rate cases. Target revenues will be adjusted according to an index-driven ARA based on (i) an inflation factor, (ii) a predetermined X-factor to encompass productivity, which is set at zero, (iii) a Z-factor to account for exceptional circumstances not in the Utilities’ control and (iv) a customer dividend consisting of a negative adjustment of 0.22% of adjusted revenue requirements compounded annually and a flow through of the “pre-PBR” savings commitment from the management audit recommendations developed in a prior docket at a rate of $6.6 million per year from 2021 to 2025. The ARA mechanism replaced the previous revenue adjustment mechanism (RAM). RAM revenue adjustments approved by the PUC in 2020 will continue to be included in the RBA provision’s target revenue and RBA rate adjustment to the extent such adjustments are not included in base rate unless modified with PUC approval. The implementation of the ARA occurred on June 1, 2021.
Earnings sharing mechanism. The PBR Framework established a symmetrical ESM for achieved rate-making ROACE outside of a 300 basis points deadband above or below the current authorized ROACE of 9.5% for each of the Utilities. There is a 50/50 sharing between customers and Utilities for the achieved rate-making ROACE falling within 150 basis points outside of the deadband in either direction, and a 90/10 sharing for any further difference. A reopening or review of the PBR terms may be triggered if the Utilities credit rating outlook indicates a potential credit downgrade below investment grade status, or if its achieved rate-making ROACE enters the outer most tier of the ESM.
On August 31, 2023, the PUC issued an order temporarily suspending the ESM until further notice. The intent of the order is to address the unintended consequence of customers potentially bearing the costs associated with the Maui windstorm and wildfires through the operation of the ESM without prior PUC review.
Exceptional project recovery mechanism. Prior to the implementation of the PBR Framework, the PUC established the Major Project Interim Recovery (MPIR) adjustment mechanism and MPIR Guidelines. The MPIR mechanism provides the opportunity to recover revenues for net costs of approved eligible projects placed in service between general rate cases. In establishing the PBR Framework, the MPIR Guidelines were terminated and replaced with the EPRM Guidelines. Although the MPIR Guidelines were terminated and replaced by the EPRM Guidelines, the MPIR mechanism will continue within the PBR Framework to provide recovery of project costs previously approved for recovery under the MPIR. The established EPRM Guidelines permit the Utilities to include the full amount of approved costs in the EPRM for recovery in the first year the project goes into service, pro-rated for the portion of the year the project is in service. Deferred and O&M expense projects are also eligible for EPRM recovery under the EPRM Guidelines. EPRM recoverable costs will be limited to the lesser of actual incurred project costs or PUC-approved amounts, net of savings.
As of December 31, 2024, the Utilities annualized MPIR and EPRM revenue amounts totaled $38.0 million, including revenue taxes, for the Schofield Generating Station ($16.1 million), West Loch PV project ($3.2 million), Grid Modernization Strategy (GMS) Phase 1 project ($16.1 million for all three utilities), Waiawa UFLS project ($0.1 million) and Waena Switchyard/Synchronous project ($2.5 million) that included the 2024 return on project amount (based on approved amounts) in rate base, depreciation and incremental O&M expenses. The PUC approved the Utilities’ recovery of the annualized 2024 MPIR and EPRM amounts for the Schofield Generating Station, West Loch PV, GMS Phase 1, Waiawa UFLS and Waena Switchyard projects effective June 1, 2024 through the RBA rate adjustment.
As of December 31, 2024, the PUC approved four EPRM applications for projects totaling $218.5 million to the extent the project costs are not included in rates. Currently, the Utilities are seeking EPRM recovery for two additional projects with total project costs up to $294.2 million, subject to PUC approval.
Pilot process. As part of the PBR Framework, the PUC approved a pilot process to foster innovation by establishing an expedited implementation process for pilots that tests new technologies, programs, business models, and other arrangements (Pilot Process). Under the Pilot Process, the Utilities submit specific pilot proposals (Pilot Notices) that are within the scope of the approved Workplan to the PUC for their expedited review. The PUC will strive to issue an order addressing a proposed pilot within 45 days of the filing date of a Pilot Notice. If the PUC does not take affirmative action on a Pilot Notice by the end of the 45-day period, the Pilot Notice will be considered approved as submitted. The PUC may modify the pilot as originally proposed, and the Utilities will have 15 days to notify the PUC whether the Utilities accept the modification, propose further modification, or withdraw the Pilot Notice. The PUC may also, where necessary, suspend the Pilot Notice for further investigation.
The approved Pilot Process includes a cost recovery process that generally allows the Utilities to defer and recover total annual expenditures of approved pilot projects net of revenues, subject to an annual cap of $10 million, over 12 months beginning June 1 of the year following pilot implementation through the RBA rate adjustment, although the PUC may determine on a case-by-case basis that a particular project’s deferred costs should be amortized over a period greater than 12 months.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
On March 11, 2024, the Utilities filed their annual Pilot Update report covering pilot projects that were active during 2023, including reporting on pilot projects that were initiated prior to the commencement of the Pilot Process. The Pilot Update reported on approximately $3.0 million of 2023 recorded pilot project costs including revenue taxes for the Utilities. The 2023 recorded pilot project costs were included in the Utilities’ proposed adjustments to target revenue in the 2024 spring revenue report filed on March 28, 2024.
On December 4, 2024, the Utilities requested PUC approval to extend the Charge Ready Hawaii and the eBus Make-Ready Infrastructure pilots beyond their current implementation schedule end dates by approximately 12 months, from December 31, 2025 to December 31, 2026. On February 6, 2025, the PUC approved the pilot extension requests.
Performance incentive mechanisms. The following PIMs and SSMs were approved by the PUC and are applicable for the 2024 evaluation period.
•Service Quality performance incentives (ongoing). Service Quality performance incentives are measured on a calendar-year basis. The PIM tariff requires the performance targets, deadbands and the amount of maximum financial incentives used to determine the PIM financial incentive levels for each of the PIMs to remain constant in interim periods, unless otherwise amended by order of the PUC.
•Service Reliability Performance measured by Transmission and Distribution-caused SAIDI and SAIFI (penalties only). Target performance is based on each utility’s historical 10-year average performance with a deadband of one standard deviation. The maximum penalty for each performance index is 20 basis points applied to the common equity share of each respective utility’s approved rate base prorated by the circuit customer count of Non-Wildfire Risk Circuits divided by the 2023 annual average total system customer count (or maximum penalties of approximately $3.6 million for calendar years 2024 and 2025 - for both indices in total for the three utilities). On December 18, 2024, as clarified on January 15, 2025, the PUC granted the Utilities’ request to suspend the T&D SAIDI and SAIFI PIMs for wildfire risk circuits from January 1, 2024 to December 31, 2025. Circuits not identified as wildfire risk circuits continue to be subject to the existing PIMs and measured effective January 1, 2024. For the 2024 evaluation period, the Utilities accrued $1.0 million in penalties.
•Call Center Performance measured by the percentage of calls answered within 30 seconds. The previous target performance was based on the annual average performance for each utility for the most recent eight quarters with a deadband of 3% above and below the target. On June 24, 2024, the PUC issued an order approving a consolidated target for the Call Center PIM and modifying the target performance based on the average of the Utilities’ performance, weighted by the number of calls for the last eight quarters as of December 31, 2023, to be effective August 1, 2024. The maximum penalty or reward is 8 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties or rewards of approximately $1.4 million - in total for the three utilities). For the 2024 evaluation period, the Utilities did not make any accruals.
•Phase 1 RFP PIM. Procurement of low-cost variable renewable resources through the RFP process in 2018 is measured by comparison of the procurement price to target prices. The first portion of the incentive was earned upon PUC approval of the PPAs. Based on the seven PPAs approved in 2019, the Utilities recognized $1.7 million in 2019 with the remaining award to be recognized in the year following the in-service date of the projects prorated in proportion to the actual amount of energy utilized, which is estimated to occur from 2023 to 2025. Based on the in-service date of two projects, the Utilities earned the second portion of the incentive of approximately $0.1 million (for Hawaiian Electric) in rewards in both 2023 and the first quarter of 2024. In the second quarter of 2024, the Utilities earned the second portion of the incentive of approximately $0.1 million (for Hawaii Electric Light).
•Renewable portfolio standard (RPS) - A PIM that provides a financial reward for accelerating the achievement of RPS goals. The Utilities may earn a reward for the amount of system generation above the interpolated statutory RPS goal at $20/MWh in 2021 and 2022, $15/MWh in 2023, and $10/MWh for the remainder of the MRP. Penalties are already prescribed in the RPS as $20/MWh for failing to meet RPS targets in 2030, 2040 and 2045. The evaluation period commenced on January 1, 2021. For the 2024 evaluation period, the Utilities accrued $1.9 million in rewards.
•Interconnection Approval PIM that provides financial rewards and penalties for interconnection times for DER systems <100 kW in size. The Interconnection Approval PIM extends through December 31, 2024. The Utilities can earn a total annual maximum reward of $3.0 million or a total annual maximum penalty of $0.9 million. For the 2024 evaluation period, the Utilities accrued $2.4 million in rewards.
•Low-to-Moderate Income (LMI) Energy Efficiency PIM that provided financial rewards for collaboration between the Utilities and the third-party Public Benefits Fee Administrator to deliver energy savings for low- and moderate-income customers. The Utilities could earn a total annual maximum reward of $2.0 million. The evaluation period was based on Hawaii Energy’s program year with the initial evaluation year being the period of July 1, 2021 through June 30,
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
2022 and ended the period ending June 30, 2024. The Utilities earned $0.01 million in rewards for the program period ending June 30, 2023.
•Generation-caused System Average Interruption Duration and Frequency Indexes PIMs to incentivize achievement of generation-based reliability targets, measured by Generation System Average Interruption Duration and Frequency Indexes (penalties only). Target performance is based on each utility’s historical 10-year average performance with a deadband of one standard deviation. The maximum penalty for each performance index is 3 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties of approximately $1 million - for both indices in total for the three utilities). For the 2024 evaluation period, the Utilities accrued $0.1 million in penalties (for Hawaii Electric Light).
•An interconnection requirements study PIM to incentivize the timely completion of the IRS process for large-scale renewable energy projects (rewards and penalties) measured by the number of months between final model checkout and delivery of IRS results to the developer. Target performance is ten months with an asymmetrical deadband of two-months for penalties and no deadband for rewards. The maximum penalty and reward will depend on the specifics of the upcoming procurement. For the 2024 evaluation period, the Utilities did not make any accruals.
•A CSSM to incentivize cost control over the Utilities’ fuel, purchased power, and EPRM/MPIR costs (collectively, non-ARA costs). This is a reward only incentive where the Utilities retain 20% share of savings when non-ARA costs in a performance year are lower than target year non-ARA costs, which are adjusted for changes in fuel prices, inflation, and system generation from a base year (calendar year 2021). The CSSM does not have a potential penalty and does not have a cap for maximum reward. For the 2024 evaluation period, the Utilities accrued $2.8 million in rewards (for Hawaii Electric Light).
For the 2024 evaluation period, the Utilities accrued $6.2 million ($2.5 million for Hawaiian Electric, $3.4 million for Hawaii Electric Light and $0.3 million for Maui Electric) in rewards net of penalties. The net rewards related to 2024 will be reflected in the 2025 PIMS annual report and 2025 spring revenue report filings with the exception of the Phase 1 RFP PIM for Hawaiian Electric and Hawaii Electric Light, which were reflected in the 2024 spring revenue report and 2024 fall revenue report filings, respectively.
Annual review cycle. PBR D&O established an annual review cycle for revenue adjustments under the PBR Framework, including the biannual submission of the revenue reports. On December 17,2024, the PUC approved the Utilities’ 2024 fall revenue report filed on October 28, 2024. The filing reflected ARA revenues for 2025 to be collected from January 1 through December 31, 2025, as follows:
(in millions) Hawaiian Electric Hawaii Electric Light Maui Electric Total
2025 ARA revenues
$ 15.4 $ 3.8 $ 3.7 $ 22.9
Management Audit savings commitment (4.6) (1.0) (1.0) (6.6)
Net 2025 ARA revenues
$ 10.8 $ 2.8 $ 2.7 $ 16.3
The net incremental amounts between the 2024 spring and fall revenue reports are shown in the following table. The amounts are to be collected (refunded) from January 1 through December 31, 2025 under the RBA rate tariffs, which were included in the 2024 fall revenue report filing.
(in millions) Hawaiian Electric Hawaii Electric Light Maui Electric Total
2025 ARA revenues
$ 15.4 $ 3.8 $ 3.7 $ 22.9
Annual change in accrued RBA balance through September 30, 2024 (and associated revenue taxes)
(7.0) (1.3) 6.4 (1.9)
Incremental Performance Incentive Mechanisms (net)
(0.1) 0.1 - -
Net incremental amount to be collected under the RBA rate tariffs $ 8.3 $ 2.6 $ 10.1 $ 21.0
Consolidating financial information. Consolidating financial information for Hawaiian Electric and its subsidiaries are presented for the years ended December 31, 2024, 2023 and 2022, and as of December 31, 2024 and 2023.
On March 21, 2024, Hawaiian Electric formed HE AR INTER LLC and its direct consolidated subsidiary, HE BRWR LLC, which were established to pursue financing through a secured asset-based (accounts receivable) credit facility.
Hawaiian Electric unconditionally guarantees Hawaii Electric Light’s and Maui Electric’s obligations (a) to the State of Hawaii for the repayment of principal and interest on Special Purpose Revenue Bonds issued for the benefit of Hawaii Electric Light and Maui Electric and (b) under their respective private placement note agreements and the Hawaii Electric Light notes and Maui Electric notes issued thereunder. Hawaiian Electric is also obligated, after the satisfaction of its obligations on its own
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
preferred stock, to make dividend, redemption and liquidation payments on Hawaii Electric Light’s and Maui Electric’s preferred stock if the respective subsidiary is unable to make such payments.
Consolidating statement of income
Year ended December 31, 2024
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries
Consolidating adjustments Hawaiian Electric
Consolidated
Revenues $ 2,283,148 483,715 440,432 5,570 (6,165) [1]
$ 3,206,700
Expenses
Fuel oil 790,004 121,719 166,322 - - 1,078,045
Purchased power 517,583 132,086 53,702 - - 703,371
Other operation and maintenance 390,111 102,883 121,693 1,150 (6,165) [1] 609,672
Wildfire tort-related claims, net (Note 2)
1,500,000 187,500 187,500 - - 1,875,000
Depreciation 167,909 43,855 39,378 - - 251,142
Taxes, other than income taxes 215,137 45,025 41,166 - - 301,328
Total expenses 3,580,744 633,068 609,761 1,150 (6,165) 4,818,558
Operating income (loss)
(1,297,596) (149,353) (169,329) 4,420 - (1,611,858)
Allowance for equity funds used during construction 10,853 1,189 1,744 - - 13,786
Equity in earnings of subsidiaries (248,004) - - - 248,004 [2] -
Retirement defined benefits credit (expense)-other than service costs 3,574 665 (102) - - 4,137
Interest expense and other charges, net (59,906) (11,422) (16,688) - 5,934 [1] (82,082)
Allowance for borrowed funds used during construction 4,300 355 815 - - 5,470
Interest Income
11,136 1,062 369 - (5,934) [1]
6,633
Income (loss) before income taxes
(1,575,643) (157,504) (183,191) 4,420 248,004 (1,663,914)
Income tax expense (benefit)
(350,361) (41,624) (48,700) 1,138 - (439,547)
Net income (loss)
(1,225,282) (115,880) (134,491) 3,282 248,004 (1,224,367)
Preferred stock dividends of subsidiaries - 534 381 - - 915
Net income (loss) attributable to Hawaiian Electric
(1,225,282) (116,414) (134,872) 3,282 248,004 (1,225,282)
Preferred stock dividends of Hawaiian Electric
1,080 - - - - 1,080
Net income (loss) for common stock
$ (1,226,362) (116,414) (134,872) 3,282 248,004 $ (1,226,362)
Consolidating statement of comprehensive income
Year ended December 31, 2024
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries Consolidating
adjustments Hawaiian Electric
Consolidated
Net income (loss) for common stock
$ (1,226,362) (116,414) (134,872) 3,282 248,004 $ (1,226,362)
Other comprehensive loss, net of taxes:
Retirement benefit plans:
Net gains arising during the period, net of taxes 65,680 8,108 7,342 - (15,450) [1] 65,680
Adjustment for amortization of net gains recognized during the period in net periodic benefit cost, net of taxes
(2,035) (159) (243) - 402 [1] (2,035)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes (63,708) (7,895) (7,076) - 14,971 [1] (63,708)
Other comprehensive loss, net of taxes
(63) 54 23 - (77) (63)
Comprehensive income (loss) attributable to common shareholder
$ (1,226,425) (116,360) (134,849) 3,282 247,927 $ (1,226,425)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating statement of income
Year ended December 31, 2023
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Consolidating adjustments Hawaiian Electric
Consolidated
Revenues $ 2,356,478 464,161 448,882 - $ 3,269,521
Expenses
Fuel oil 913,801 105,009 192,610 - 1,211,420
Purchased power 486,067 142,837 42,865 - 671,769
Other operation and maintenance 343,462 85,261 104,834 - 533,557
Depreciation 164,150 42,541 37,014 - 243,705
Taxes, other than income taxes 221,664 43,095 42,153 - 306,912
Total expenses 2,129,144 418,743 419,476 - 2,967,363
Operating income 227,334 45,418 29,406 - 302,158
Allowance for equity funds used during construction
11,721 1,411 2,032 - 15,164
Equity in earnings of subsidiaries 44,809 - - (44,809) [2] -
Retirement defined benefits credit (expense)-other than service costs 3,735 667 (99) - 4,303
Interest expense and other charges, net (62,362) (11,650) (12,933) 805 [1] (86,140)
Allowance for borrowed funds used during construction 4,081 451 669 - 5,201
Interest Income
5,113 1,071 1,075 (805) [1] 6,454
Income before income taxes 234,431 37,368 20,150 (44,809) 247,140
Income taxes 39,399 8,327 3,467 - 51,193
Net income 195,032 29,041 16,683 (44,809) 195,947
Preferred stock dividends of subsidiaries - 534 381 - 915
Net income attributable to Hawaiian Electric 195,032 28,507 16,302 (44,809) 195,032
Preferred stock dividends of Hawaiian Electric 1,080 - - - 1,080
Net income for common stock $ 193,952 28,507 16,302 (44,809) $ 193,952
Consolidating statement of comprehensive income
Year ended December 31, 2023
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Consolidating adjustments Hawaiian Electric
Consolidated
Net income for common stock $ 193,952 28,507 16,302 (44,809) $ 193,952
Other comprehensive income (loss), net of taxes:
Retirement benefit plans:
Net gains arising during the period, net of taxes
10,175 961 1,275 (2,236) [1] 10,175
Adjustment for amortization of prior service credit and net gains recognized during the period in net periodic benefit cost, net of taxes
(1,983) (221) (266) 487 [1] (1,983)
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes
(8,204) (752) (978) 1,730 [1] (8,204)
Other comprehensive income (loss), net of taxes
(12) (12) 31 (19) (12)
Comprehensive income attributable to common shareholder
$ 193,940 28,495 16,333 (44,828) $ 193,940
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating statement of income
Year ended December 31, 2022
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Consolidating adjustments Hawaiian Electric
Consolidated
Revenues $ 2,452,969 485,590 470,355 (327) [1] $ 3,408,587
Expenses
Fuel oil 917,801 133,238 214,575 - 1,265,614
Purchased power 601,235 143,636 48,713 - 793,584
Other operation and maintenance 326,785 85,110 85,706 - 497,601
Depreciation 158,725 41,404 35,295 - 235,424
Taxes, other than income taxes 228,843 44,685 43,645 - 317,173
Total expenses 2,233,389 448,073 427,934 - 3,109,396
Operating income 219,580 37,517 42,421 (327) 299,191
Allowance for equity funds used during construction
8,464 898 1,212 - 10,574
Equity in earnings of subsidiaries 47,493 - - (47,493) [2] -
Retirement defined benefits credit (expense)-other than service costs 3,296 666 (127) - 3,835
Interest expense and other charges, net (55,260) (10,659) (10,824) 327 [1] (76,416)
Allowance for borrowed funds used during construction
2,769 277 370 - 3,416
Income before income taxes 226,342 28,699 33,052 (47,493) 240,600
Income taxes 36,333 6,349 6,994 - 49,676
Net income 190,009 22,350 26,058 (47,493) 190,924
Preferred stock dividends of subsidiaries - 534 381 - 915
Net income attributable to Hawaiian Electric
190,009 21,816 25,677 (47,493) 190,009
Preferred stock dividends of Hawaiian Electric 1,080 - - - 1,080
Net income for common stock $ 188,929 21,816 25,677 (47,493) $ 188,929
Consolidating statement of comprehensive income
Year ended December 31, 2022
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Consolidating adjustments Hawaiian Electric
Consolidated
Net income for common stock $ 188,929 21,816 25,677 (47,493) $ 188,929
Other comprehensive income, net of taxes:
Retirement benefit plans:
Net gains arising during the period, net of taxes
187,193 44,411 44,386 (88,797) [1] 187,193
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of taxes 18,884 2,811 2,584 (5,395) [1] 18,884
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes
(199,936) (46,841) (46,694) 93,535 [1] (199,936)
Other comprehensive income, net of tax benefits
6,141 381 276 (657) 6,141
Comprehensive income attributable to common shareholder
$ 195,070 22,197 25,953 (48,150) $ 195,070
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating balance sheet
December 31, 2024
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries
Consolidating
adjustments Hawaiian Electric
Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land $ 42,860 5,645 3,514 - - $ 52,019
Plant and equipment 5,502,198 1,501,947 1,417,356 - - 8,421,501
Right-of-use assets - finance lease
360,270 36,074 50,757 - - 447,101
Less accumulated depreciation (2,029,719) (691,161) (605,744) - - (3,326,624)
Construction in progress 282,150 31,341 52,218 - - 365,709
Utility property, plant and equipment, net 4,157,759 883,846 918,101 - - 5,959,706
Nonutility property, plant and equipment, less accumulated depreciation
1,145 115 1,532 - - 2,792
Total property, plant and equipment, net 4,158,904 883,961 919,633 - - 5,962,498
Investment in wholly-owned subsidiaries, at equity
680,414 - - - (680,414) [2] -
Current assets
Cash and cash equivalents 118,367 31,534 16,456 17,791 - 184,148
Advances to affiliates 62,200 - - - (62,200) [1] -
Customer accounts receivable, net
19,050 7,245 8,941 164,662 - 199,898
Accrued unbilled revenues, net 12,738 4,046 1,890 160,047 - 178,721
Other accounts receivable, net 209,752 58,366 51,465 - (249,946) [1] 69,637
Fuel oil stock, at average cost 70,800 13,764 14,339 - - 98,903
Materials and supplies, at average cost
69,602 15,506 33,358 - - 118,466
Prepayments and other 110,516 16,662 30,747 - (6,705) [1] 151,220
Regulatory assets 36,520 8,211 9,164 - - 53,895
Total current assets 709,545 155,334 166,360 342,500 (318,851) 1,054,888
Other long-term assets
Operating lease right-of-use assets 29,868 22,672 6,741 - - 59,281
Regulatory assets 172,257 18,875 36,292 - - 227,424
Defined benefit pension and other postretirement benefit plans asset
66,292 30,397 24,128 - (11,998) [1]
108,819
Other 194,006 18,612 21,702 - (33,626) [1] 200,694
Total other long-term assets 462,423 90,556 88,863 - (45,624) 596,218
Total assets
$ 6,011,286 1,129,851 1,174,856 342,500 (1,044,889) $ 7,613,604
(continued)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating balance sheet (continued)
December 31, 2024
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries
Consolidating
adjustments Hawaiian Electric
Consolidated
Capitalization and liabilities
Capitalization
Common stock equity $ 1,156,955 243,964 282,876 153,574 (680,414) [2] $ 1,156,955
Cumulative preferred stock-not subject to mandatory redemption
22,293 7,000 5,000 - - 34,293
Long-term debt, net 1,353,173 244,466 256,575 - - 1,854,214
Total capitalization 2,532,421 495,430 544,451 153,574 (680,414) 3,045,462
Current liabilities
Current portion of operating lease liabilities 4,430 7,802 2,970 - - 15,202
Current portion of long-term debt, net 40,000 5,000 2,000 - - 47,000
Short-term borrowings-non-affiliate 48,623 - - - - 48,623
Short-term borrowings-affiliate - - 62,200 - (62,200) [1] -
Accounts payable 137,837 27,077 32,066 - - 196,980
Interest and preferred dividends payable
15,994 3,191 2,701 - (350) [1] 21,536
Taxes accrued, including revenue taxes 197,768 42,692 37,108 1,138 (6,705) [1] 272,001
Regulatory liabilities 11,701 10,039 4,828 - - 26,568
Wildfire tort-related claims (Note 2)
383,000 47,875 47,875 - - 478,750
Other 103,415 35,492 43,913 187,788 (249,597) [1] 121,011
Total current liabilities 942,768 179,168 235,661 188,926 (318,852) 1,227,671
Deferred credits and other liabilities
Operating lease liabilities 29,830 15,230 4,075 - - 49,135
Finance lease liabilities 341,364 34,370 49,891 - - 425,625
Deferred income taxes - 5,368 28,257 - (33,625) [1] -
Regulatory liabilities 864,259 222,834 130,422 - - 1,217,515
Unamortized tax credits 54,950 10,757 10,969 - - 76,676
Defined benefit pension plan liability
18,301 125 - - (11,998) [1] 6,428
Wildfire tort-related claims (Note 2)
1,149,000 143,625 143,625 - - 1,436,250
Other 78,393 22,944 27,505 - - [1]
128,842
Total deferred credits and other liabilities
2,536,097 455,253 394,744 - (45,623) 3,340,471
Total capitalization and liabilities $ 6,011,286 1,129,851 1,174,856 342,500 (1,044,889) $ 7,613,604
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating balance sheet
December 31, 2023
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiary
Consolidating
adjustments Hawaiian Electric
Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land $ 42,859 5,645 3,594 - - $ 52,098
Plant and equipment 5,398,281 1,459,639 1,374,890 - - 8,232,810
Finance lease right-of-use assets 306,099 36,075 - - - 342,174
Less accumulated depreciation (1,925,660) (666,581) (605,273) - - (3,197,514)
Construction in progress 247,836 33,488 38,899 - - 320,223
Utility property, plant and equipment, net 4,069,415 868,266 812,110 - - 5,749,791
Nonutility property, plant and equipment, less accumulated depreciation
5,295 115 1,532 - - 6,942
Total property, plant and equipment, net 4,074,710 868,381 813,642 - - 5,756,733
Investment in wholly-owned subsidiaries, at equity
722,211 - - - (722,211) [2] -
Current assets
Cash and cash equivalents 89,755 10,658 5,587 77 - 106,077
Restricted cash 2,000 - - - - 2,000
Advances to affiliates 70,500 - - - (70,500) [1] -
Customer accounts receivable, net
172,747 38,216 33,346 - - 244,309
Accrued unbilled revenues, net 136,367 25,102 24,175 - - 185,644
Other accounts receivable, net 143,160 13,318 32,521 - (77,480) [1] 111,519
Fuel oil stock, at average cost 108,228 17,968 22,041 - - 148,237
Materials and supplies, at average cost
64,334 14,397 35,702 - - 114,433
Prepayments and other 40,767 7,724 11,638 - (1,638) [1] 58,491
Regulatory assets 58,920 5,771 3,762 - - 68,453
Total current assets 886,778 133,154 168,772 77 (149,618) 1,039,163
Other long-term assets
Operating lease right-of-use assets 34,856 27,470 9,551 - - 71,877
Regulatory assets 189,417 13,575 23,359 - - 226,351
Other postretirement benefit plan asset
50,743 17,827 13,169 - (14,171) [1] 67,568
Other 83,290 18,612 19,960 - - 121,862
Total other long-term assets 358,306 77,484 66,039 - (14,171) 487,658
Total assets
$ 6,042,005 1,079,019 1,048,453 77 (886,000) $ 7,283,554
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating balance sheet (continued)
December 31, 2023
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiary
Consolidating
adjustments Hawaiian Electric
Consolidated
Capitalization and liabilities
Capitalization
Common stock equity $ 2,409,110 359,790 362,344 77 (722,211) [2] $ 2,409,110
Cumulative preferred stock-not subject to mandatory redemption
22,293 7,000 5,000 - - 34,293
Long-term debt, net 1,426,516 249,339 258,422 - - 1,934,277
Total capitalization 3,857,919 616,129 625,766 77 (722,211) 4,377,680
Current liabilities
Current portion of operating lease liabilities 6,788 7,025 2,804 - - 16,617
Short-term borrowings-affiliate - - 70,500 - (70,500) [1] -
Accounts payable 136,102 29,418 25,520 - - 191,040
Interest and preferred dividends payable
17,085 3,098 3,074 - (375) [1] 22,882
Taxes accrued, including revenue taxes 211,840 43,932 37,808 - (1,638) [1] 291,942
Regulatory liabilities 20,013 8,508 8,038 - - 36,559
Wildfire tort-related claims (Note 2)
75,000 - - - - 75,000
Other 90,131 33,240 50,170 - (77,105) [1] 96,436
Total current liabilities 556,959 125,221 197,914 - (149,618) 730,476
Deferred credits and other liabilities
Operating lease liabilities 34,262 20,792 7,044 - - 62,098
Finance lease liabilities 295,935 35,043 - - - 330,978
Deferred income taxes 280,029 51,661 67,311 - - 399,001
Regulatory liabilities 803,404 199,173 111,554 - - 1,114,131
Unamortized tax credits 61,130 11,650 11,532 - - 84,312
Defined benefit pension plan liability
74,842 - - - (14,171) [1] 60,671
Other 77,525 19,350 27,332 - - 124,207
Total deferred credits and other liabilities
1,627,127 337,669 224,773 - (14,171) 2,175,398
Total capitalization and liabilities $ 6,042,005 1,079,019 1,048,453 77 (886,000) $ 7,283,554
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating statements of changes in common stock equity
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries
Consolidating
adjustments Hawaiian Electric
Consolidated
Balance, December 31, 2021 $ 2,261,899 332,900 343,260 77 (676,237) $ 2,261,899
Net income for common stock 188,929 21,816 25,677 - (47,493) 188,929
Other comprehensive income, net of taxes
6,141 381 276 - (657) 6,141
Issuance of common stock, net of expenses 13,101 6,023 3,023 - (9,046) 13,101
Common stock dividends (125,900) (16,400) (15,200) - 31,600 (125,900)
Balance, December 31, 2022 2,344,170 344,720 357,036 77 (701,833) 2,344,170
Net income for common stock 193,952 28,507 16,302 - (44,809) 193,952
Other comprehensive income (loss), net of taxes
(12) (12) 31 - (19) (12)
Common stock dividends (129,000) (13,425) (11,025) - 24,450 (129,000)
Balance, December 31, 2023 2,409,110 359,790 362,344 77 (722,211) 2,409,110
Net income (loss) for common stock
(1,226,362) (116,414) (134,872) 3,282 248,004 (1,226,362)
Other comprehensive income (loss), net of taxes
(63) 54 23 - (77) (63)
Issuance of common stock, net of expenses
- - 55,000 150,215 (205,215) -
Common stock dividends (26,000) - - - - (26,000)
Additional paid-in capital
270 534 381 - (915) 270
Balance, December 31, 2024 $ 1,156,955 243,964 282,876 153,574 (680,414) $ 1,156,955
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating statement of cash flows
Year ended December 31, 2024
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries
Consolidating
adjustments Hawaiian Electric
Consolidated
Cash flows from operating activities
Net income (loss)
$ (1,225,282) (115,880) (134,491) 3,282 248,004 [2] $ (1,224,367)
Adjustments to reconcile net income to net cash provided by operating activities
Equity in earnings of subsidiaries 248,004 - - - (248,004) [2] -
Depreciation of property, plant and equipment 167,909 43,855 39,378 - - 251,142
Other amortization 23,606 4,958 3,264 - - 31,828
Deferred income tax benefit
(393,025) (47,550) (41,049) - - (481,624)
Gain/Loss on sale of receivables to affiliate
4,079 821 670 (5,570) - -
State refundable credit (7,914) (1,848) (2,152) - - (11,914)
Bad debt expense 2,838 476 1,406 - - 4,720
Allowance for equity funds used during construction (10,853) (1,189) (1,744) - - (13,786)
Other (6,270) (50) 9 - - (6,311)
Changes in assets and liabilities:
Decrease (increase) in accounts receivable
22,897 (13,175) 1,570 (95,382) 172,466 [1] 88,376
Decrease (increase) in accrued unbilled revenues
57,281 20,989 22,633 (93,342) - 7,561
Decrease in fuel oil stock
37,427 4,205 7,702 - - 49,334
Decrease (increase) in materials and supplies
(5,269) (1,109) 2,345 - - (4,033)
Increase in regulatory assets
(4,608) (5,346) (12,789) - - (22,743)
Increase in regulatory liabilities
38,413 6,597 3,423 - - 48,433
Increase (decrease) in accounts payable
9,879 (1,687) 1,452 - - 9,644
Change in prepaid and accrued income taxes, tax credits and revenue taxes (14,192) (2,325) (8,614) 1,138 (2,549) [1]
(26,542)
Change in defined benefit pension and other postretirement benefit plans asset/liability
(6,334) (1,521) (1,363) - - (9,218)
Increase in wildfire tort-related claims
1,457,000 191,500 191,500 - - 1,840,000
Change in other assets and liabilities (52,774) (4,035) (23,280) 187,788 (172,466) [1] (64,767)
Net cash provided by (used in) operating activities
342,812 77,686 49,870 (2,086) (2,549) 465,733
Cash flows from investing activities
Capital expenditures (197,142) (51,209) (81,128) - - (329,479)
Advances to affiliates
(46,700) - - - 46,700 [1] -
Other (10,169) 679 (1,011) - 22,349 [1][2]
11,848
Net cash used in investing activities (254,011) (50,530) (82,139) - 69,049 (317,631)
Cash flows from financing activities
Common stock dividends (26,000) - - - -
(26,000)
Preferred stock dividends of Hawaiian Electric and subsidiaries (1,995) - - - - (1,995)
Proceeds from issuance of common stock/capital contribution from parent
270 - - 19,800 (19,800) [2]
Repayment of long-term debt and funds transferred for repayment of long-term debt
(74,000) (5,000) (2,000) - - (81,000)
Net increase (decrease) in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less - - 46,700 - (46,700) [1] -
Payments of obligations under finance leases (3,487) (632) - - - (4,119)
Proceeds from issuance of short-term debt 50,000 - - - - 50,000
Other (6,977) (648) (1,562) - - (9,187)
Net cash provided by (used in) financing activities (62,189) (6,280) 43,138 19,800 (66,500) (72,031)
Net increase in cash and cash equivalents
26,612 20,876 10,869 17,714 - 76,071
Cash, cash equivalents and restricted cash, January 1 91,755 10,658 5,587 77 - 108,077
Cash and cash equivalents, December 31 $ 118,367 31,534 16,456 17,791 - $ 184,148
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating statement of cash flows
Year ended December 31, 2023
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiary
Consolidating
adjustments Hawaiian Electric
Consolidated
Cash flows from operating activities
Net income $ 195,032 29,041 16,683 - (44,809) [2] $ 195,947
Adjustments to reconcile net income to net cash provided by operating activities
Equity in earnings of subsidiaries
(44,809) - - - 44,809 [2] -
Common stock dividends received from subsidiaries
24,450 - - - (24,450) [2] -
Depreciation of property, plant and equipment
164,150 42,541 37,014 - - 243,705
Other amortization 17,692 5,003 3,795 - - 26,490
Deferred income tax expense (benefit)
(851) (296) 2,586 - - 1,439
State refundable credit
(7,577) (1,782) (1,966) - - (11,325)
Bad debt expense 5,565 1,353 1,243 - - 8,161
Allowance for equity funds used during construction
(11,721) (1,411) (2,032) - - (15,164)
Other
380 (46) 126 - - 460
Changes in assets and liabilities:
Increase in accounts receivable (83,401) (7,398) (29,301) - 55,096 [1] (65,004)
Decrease (increase) in accrued unbilled revenues
8 (1,308) (1,748) - - (3,048)
Decrease (increase) in fuel oil stock
45,114 (1,004) (817) - - 43,293
Increase in materials and supplies
(16,204) (4,614) (14,047) - - (34,865)
Decrease (increase) in regulatory assets
(6,616) 5,501 (9,498) - - (10,613)
Increase (decrease) in regulatory liabilities
48,833 (1,176) 6,813 - - 54,470
Increase in accounts payable
13,988 5,998 468 - - 20,454
Change in prepaid and accrued income taxes, tax credits and revenue taxes
4,314 2,407 (4,843) - - 1,878
Change in defined benefit pension and other postretirement benefit plans asset/liability
(5,653) (1,348) (1,185) - - (8,186)
Increase in wildfire tort-related claims
75,000 - - - - 75,000
Change in other assets and liabilities
(12,990) 2,056 17,305 - (55,096) [1] (48,725)
Net cash provided by operating activities
404,704 73,517 20,596 - (24,450) 474,367
Cash flows from investing activities
Capital expenditures (276,600) (63,889) (98,286) - - (438,775)
Advances from (to) affiliates
(70,500) 4,500 21,700 - 44,300 [1] -
Other 4,118 932 1,126 - - 6,176
Net cash used in investing activities (342,982) (58,457) (75,460) - 44,300 (432,599)
Cash flows from financing activities
Common stock dividends (129,000) (13,425) (11,025) - 24,450 [2] (129,000)
Preferred stock dividends of Hawaiian Electric and subsidiaries
(1,080) (534) (381) - - (1,995)
Proceeds from issuance of long-term debt
300,000 25,000 25,000 - - 350,000
Repayment of long-term debt (50,000) (20,000) (30,000) - - (100,000)
Net increase (decrease) in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less (114,167) - 70,500 - (44,300) [1] (87,967)
Payments of obligations under finance leases (2,728) (400) - - - (3,128)
Other (571) (135) (137) - - (843)
Net cash provided by (used in) financing activities
2,454 (9,494) 53,957 - (19,850) 27,067
Net increase (decrease) in cash, cash equivalents and restricted cash
64,176 5,566 (907) - - 68,835
Cash, cash equivalents and restricted cash, January 1
27,579 5,092 6,494 77 - 39,242
Cash, cash equivalents and restricted cash, December 31
91,755 10,658 5,587 77 - 108,077
Less: Restricted cash
(2,000) - - - - (2,000)
Cash and cash equivalents, December 31
$ 89,755 10,658 5,587 77 - $ 106,077
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Consolidating statement of cash flows
Year ended December 31, 2022
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiary
Consolidating
adjustments Hawaiian Electric
Consolidated
Cash flows from operating activities
Net income $ 190,009 22,350 26,058 - (47,493) [2] $ 190,924
Adjustments to reconcile net income to net cash provided by operating activities
Equity in earnings of subsidiaries
(47,493) - - - 47,493 [2] -
Common stock dividends received from subsidiaries
31,600 - - - (31,600) [2] -
Depreciation of property, plant and equipment
158,725 41,404 35,295 - - 235,424
Other amortization 16,708 4,996 3,616 - - 25,320
Deferred income taxes
(33,648) (4,040) (3,727) - - (41,415)
State refundable credit
(7,375) (1,734) (1,890) - - (10,999)
Bad debt expense 4,175 1,073 779 - - 6,027
Allowance for equity funds used during construction
(8,464) (898) (1,212) - - (10,574)
Other
(65) (50) (24) - - (139)
Changes in assets and liabilities:
Increase in accounts receivable (74,067) (11,644) (10,680) - 4,649 [1] (91,742)
Increase in accrued unbilled revenues (43,972) (4,289) (5,762) - - (54,023)
Increase in fuel oil stock (82,158) (4,150) (1,144) - - (87,452)
Increase in materials and supplies
(6,124) (56) (1,511) - - (7,691)
Decrease in regulatory assets
28,076 1,546 4,978 - - 34,600
Increase in regulatory liabilities
28,621 7,977 8,290 - 44,888
Increase in accounts payable
18,657 3,294 404 - - 22,355
Change in prepaid and accrued income taxes, tax credits and revenue taxes
77,903 11,117 14,178 - - 103,198
Decrease in defined benefit pension and other postretirement benefit plans liability (3,545) (626) (657) - - (4,828)
Change in other assets and liabilities
(17,884) 213 (3,623) - (4,649) [1] (25,943)
Net cash provided by operating activities
229,679 66,483 63,368 - (31,600) 327,930
Cash flows from investing activities
Capital expenditures (223,223) (49,004) (57,230) - - (329,457)
Advances from (to) affiliates
1,000 (4,500) (21,700) - 25,200 [1] -
Other (5,687) 760 1,253 - 9,046 [1][2] 5,372
Net cash used in investing activities (227,910) (52,744) (77,677) - 34,246 (324,085)
Cash flows from financing activities
Common stock dividends (125,900) (16,400) (15,200) - 31,600 [2] (125,900)
Preferred stock dividends of Hawaiian Electric and subsidiaries
(1,080) (534) (381) - - (1,995)
Proceeds from the issuance of common stock
13,101 6,023 3,023 - (9,046) [2] 13,101
Proceeds from the issuance of long-term debt
40,000 10,000 10,000 - - 60,000
Repayment of long-term debt
(40,000) (12,000) - - - (52,000)
Net increase (decrease) in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less 114,167 (1,000) - - (25,200) [1] 87,967
Payments of obligations under finance leases
(670) - - - - (670)
Other (241) (62) (61) - - (364)
Net cash used in financing activities
(623) (13,973) (2,619) - (2,646) (19,861)
Net increase (decrease) in cash and cash equivalents
1,146 (234) (16,928) - - (16,016)
Cash and cash equivalents, January 1
26,433 5,326 23,422 77 - 55,258
Cash and cash equivalents, December 31
$ 27,579 5,092 6,494 77 - $ 39,242
Explanation of consolidating adjustments on consolidating schedules:
[1] Eliminations of intercompany receivables and payables and other intercompany transactions
[2] Elimination of investment in subsidiaries, carried at equity
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 5. Discontinued operations
As a result of a comprehensive review of strategic options of ASB, 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, amounting to $405.5 million, to various investors including certain ASB officers and directors of ASB, while retaining a 9.9% noncontrolling investment in ASB amounting to $44.6 million. 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 will be used to primarily strengthen the Company’s balance sheet and promote long-term financial stability which may include partially paying down its long-term debt, funding the wildfire settlement amount, and/or for other corporate purposes.
The sale of ASB met the accounting requirements to be disclosed as discontinued operations. Accordingly, the results of ASB, including the loss on the ASB sale, are presented as discontinued operations in the consolidated statements of income and cash flows, and have been excluded from both continuing operations and segment results for all periods presented. Further, the assets and liabilities associated with ASB have been classified as discontinued operations in the consolidated balance sheet as of December 31, 2023.
The Company recorded a net loss on the sale transaction amounting to $115.8 million, which is net of a $2.4 million tax benefit, and is included in “Income (loss) from discontinued operations” in the Company’s Consolidated Statements of Income. The tax benefit includes a valuation allowance of $66.4 million recorded against the related deferred tax assets generated in connection with the sale transaction as it is more likely than not that these deferred tax assets will not be realized. See Note 13. A summary of the ASB sale transaction as of December 31, 2024 is as follows:
(in thousands) December 31, 2024
Sale proceeds received
$ 400,950
Sale proceeds not yet received
4,500
Investment retained in ASB
44,550
Transaction costs
(21,735)
Net assets derecognized
(546,458)
Loss from the sale of ASB (118,193)
Income taxes
68,820
Income taxes - valuation allowance
(66,430)
Income taxes, net
2,390
Net loss on the sale transaction
(115,803)
Net income from operations of discontinued bank segment
12,317
Loss from discontinued operations
$ (103,486)
For the year ended December 31, 2024, total noncash transactions of the ASB sale amounted to $507.8 million comprised of the derecognized net assets of ASB, the Company’s investment retained in ASB, accrued transaction costs and other noncash transactions.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The following table summarizes the income (loss) from discontinued operations included in the Consolidated Statements of Income for the periods presented:
Years ended December 31 2024 2023 2022
(in thousands)
Interest and dividend income
Interest and fees on loans $ 293,100 $ 276,688 $ 207,830
Interest and dividends on investment securities 55,944 58,095 58,044
Total interest and dividend income 349,044 334,783 265,874
Interest expense
Interest on deposit liabilities 72,727 48,905 7,327
Interest on other borrowings 27,442 33,892 5,974
Total interest expense 100,169 82,797 13,301
Net interest income 248,875 251,986 252,573
Provision for credit losses (1,963) 10,357 2,037
Net interest income after provision for credit losses 250,838 241,629 250,536
Noninterest income
Fees from other financial services 20,797 19,034 19,830
Fee income on deposit liabilities 19,900 19,131 18,762
Fee income on other financial products 11,798 10,616 10,291
Bank-owned life insurance 13,079 7,390 2,533
Mortgage banking income 1,419 910 1,692
Gain on sale of real estate - 495 1,778
Loss on sale of investment securities, net
- (14,965) -
Other income, net 2,535 2,799 2,086
Total noninterest income 69,528 45,410 56,972
Noninterest expense
Compensation and employee benefits 126,936 118,297 113,839
Occupancy 21,382 21,703 24,026
Data processing 19,612 20,545 17,681
Services 17,485 13,943 10,679
Equipment 9,914 11,842 10,100
Office supplies, printing and postage 4,085 4,315 4,398
Marketing 3,506 4,001 3,968
Goodwill impairment 82,190 - -
FDIC insurance 5,992 6,230 3,591
Other expense 15,907 22,762 16,985
Total noninterest expense 307,009 223,638 205,267
Income before income taxes
13,357 63,401 102,241
Income taxes
1,040 10,039 22,252
Net income from operations of discontinued bank segment
12,317 53,362 79,989
Loss from the sale of ASB
(118,193) - -
Income tax benefit
2,390 - -
Income (loss) from discontinued operations
$ (103,486) $ 53,362 $ 79,989
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The following table summarizes the assets and liabilities of discontinued operations on a stand alone basis as of December 31, 2023:
(in thousands)
Assets
Cash and due from banks $ 184,383
Interest-bearing deposits 251,072
Cash and cash equivalents 435,455
Investment securities
Available-for-sale, at fair value 1,136,439
Held-to-maturity, at amortized cost
1,201,314
Stock in Federal Home Loan Bank, at cost 14,728
Loans held for investment 6,180,810
Allowance for credit losses (74,372)
Net loans 6,106,438
Loans held for sale, at lower of cost or fair value 15,168
Other 681,460
Goodwill 82,190
Total assets of discontinued operations1
$ 9,673,192
Liabilities and shareholder’s equity
Deposit liabilities-noninterest-bearing $ 2,599,762
Deposit liabilities-interest-bearing 5,546,016
Other borrowings 750,000
Other 247,563
Total liabilities of discontinued operations1
$ 9,143,341
1 The total assets and liabilities of discontinued operations on a stand alone basis in the table above does not agree to the total assets and liabilities of discontinued operations included in the Consolidated Balance Sheet, as totals per the Consolidated Balance sheet include reclassifying entries required for consolidation purposes.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 6 · Short-term borrowings
Commercial paper and bank term loan. As of December 31, 2024 and 2023, HEI and Hawaiian Electric had no commercial paper outstanding.
As of December 31, 2024 and 2023, HEI had four and five undrawn letters of credit outstanding, respectively, in the aggregate amount of $6 million and $8 million, respectively, on behalf of Mauo and Hamakua Energy.
HEI term loan. On October 20, 2022, HEI entered into a term loan facility in the aggregate principal amount of $100 million. On December 28, 2022, HEI drew $35 million on the term loan and on March 31, 2023, HEI drew the remaining $65 million at an initial interest rate of 5.81% for an initial one month interest period. On May 31, 2023, HEI fully repaid the term loan facility at which time it was terminated. Borrowings under the facility bore interest at Term Secured Overnight Financing Rate (SOFR), as defined in the agreement, plus an applicable margin and a SOFR spread adjustment. The term loan facility contained certain restrictive financial covenants that were substantially the same as the financial covenants contained in the HEI credit facility.
Hawaiian Electric term loan. On December 30, 2024, Hawaiian Electric entered into a term loan credit agreement for a $50 million commitment with a stated maturity date of December 29, 2025. Hawaiian Electric drew $50 million on December 30, 2024 at an interest rate of 7.50%. The term loan facility contains certain restrictive financial covenants that are substantially the same as the financial covenants contained in the Hawaiian Electric credit facilities.
Credit agreements. On May 14, 2021, HEI and Hawaiian Electric each entered into a separate agreement with a syndicate of nine financial institutions (the HEI Facility and Hawaiian Electric Facility, respectively, and together, the Credit Facilities) to amend and restate their respective previously existing revolving unsecured credit agreements. The $175 million HEI Facility’s initial termination date was May 14, 2026. The $200 million Hawaiian Electric Facility’s initial termination date was May 13, 2022, but on February 18, 2022, the PUC approved Hawaiian Electric’s request to extend the term of the $200 million Hawaiian Electric Facility to May 14, 2026. In addition to extending the term, Hawaiian Electric also received PUC approval to exercise its options of two one-year extensions of the commitment termination date and to increase its aggregate revolving commitment amount from $200 million to $275 million, should there be a need.
On April 21, 2023, HEI and Hawaiian Electric executed Amendment No. 1 to the Credit Facilities (Amendment). The Amendment was executed to reflect the transition from the London Inter-Bank Offered Rate (LIBOR) to the Term SOFR as the benchmark interest rate for non-Alternate Base Rate (ABR) Loans under the Credit Facilities.
On May 14, 2023, HEI and Hawaiian Electric exercised their first of two, one-year extensions to the commitment termination date with eight of the nine financial institutions to extend the Credit Facilities to May 14, 2027. The committed capacities under the HEI Facility and Hawaiian Electric Facility are $175 million and $200 million, respectively, through May 14, 2026, and step down to approximately $157 million and $180 million, respectively, through May 14, 2027 (see Note 7).
In August 2023, HEI and Hawaiian Electric drew the full committed capacity on their respective existing revolving credit facilities, totaling $175 million and $200 million, respectively. The draws were made to provide access to liquidity and support the Company’s restoration efforts on Maui. The cash proceeds were primarily invested in highly liquid short-term investments, and for general corporate purposes. None of the facilities are collateralized. As of December 31, 2024 and 2023, HEI had $173 million and $175 million drawn on its revolving facility, respectively. As of December 31, 2024 and 2023, Hawaiian Electric had $166 million and $200 million drawn on its revolving facility, respectively.
Under the Credit Facilities, draws generally bear interest, based on each company’s respective current long-term credit ratings, at the “Adjusted Term SOFR Rate,” as defined in the Credit Facilities, plus 175.0 basis points for HEI and Hawaiian Electric, and incur annual fees on undrawn commitments, excluding swingline borrowings, at the rate of 30.0 basis points for HEI and Hawaiian Electric.
Additionally, the Credit Facilities contain provisions for pricing adjustments in the event of a long-term ratings change based on the respective Facility’s ratings-based pricing grid, which includes the ratings by Fitch, Moody’s and S&P. The Credit Facilities do not contain clauses that would affect access to the Credit Facilities by reason of a ratings downgrade, nor do they have broad “material adverse change” clauses. In addition, the Credit Facilities contain provisions for potential annual pricing adjustments to the Term Benchmark or Alternate Base Rate margin on draws and fees on undrawn commitments of up to +/-5 basis points and +/-1 basis point, respectively, based on performance against certain sustainability-linked metrics. The sustainability-linked metrics include achievement of renewable portfolio standards in excess of statutory requirements and increasing cumulative penetration of installed MWs of photovoltaic systems on residential rooftops.
The Credit Facilities also include updated terms and conditions customary for facilities of this type and contain customary
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
conditions that must be met in order to draw on them, including compliance with covenants (such as covenants preventing HEI’s and Hawaiian Electric’s respective subsidiaries from entering into agreements that restrict the ability of such subsidiaries to pay dividends to, or to repay borrowings from, HEI or Hawaiian Electric, as applicable; and a covenant in Hawaiian Electric’s facility restricting Hawaiian Electric’s ability, as well as the ability of any of its subsidiaries, to guarantee additional indebtedness of the subsidiaries if such additional debt would cause the subsidiary’s “Consolidated Subsidiary Funded Debt to Capitalization Ratio” (as defined in the Hawaiian Electric Facility) to exceed 65%).
Under the HEI Facility, it is an event of default if HEI fails to maintain an unconsolidated “Capitalization Ratio” (funded debt) (as defined in the HEI Facility) of 50% or less or if HEI sells Hawaiian Electric. Under the Hawaiian Electric Facility, it is an event of default if Hawaiian Electric fails to maintain a “Consolidated Capitalization Ratio” (equity) (as defined in the Hawaiian Electric Facility) of at least 35%, or if Hawaiian Electric is no longer owned by HEI.
Under the HEI and Hawaiian Electric Intercompany Borrowing and Investment Policy effective January 1, 2020 (the Intercompany Borrowing Policy), HEI has committed to make revolving short-term loans to Hawaiian Electric pursuant to the terms set forth in the standing commitment letter dated December 6, 2024 (the 2024 Commitment Letter). For loans that mature on or before December 5, 2025, the 2024 Commitment Letter provides a borrowing limit of $75 million outstanding at any time and the applicable interest rate. Hawaiian Electric currently has no borrowings under the Intercompany Borrowing Policy and the 2024 Commitment Letter.
Asset-based lending facility credit agreement. On May 17, 2024, Hawaiian Electric, through a special-purpose subsidiary, entered into an asset-based lending facility (ABL Facility) credit agreement (ABL Credit Facility Agreement) with several banks, which, subject to the limitations and conditions set forth in such agreement, including approval by the PUC, allows borrowings of up to $250 million on a revolving basis using certain accounts receivable as collateral. Hawaiian Electric filed an application with the PUC for approval to (i) sell accounts receivable, and (ii) establish a long-term credit facility. The first approval would allow the ABL Credit Facility Agreement to become effective for 364 days and the second approval would extend the term of the ABL Credit Facility Agreement from 364 days to three years. The ABL Credit Facility Agreement has an initial term of 364 days, with an automatic extension to three years upon receipt of the second PUC approval, with three separate options to extend one additional year, subject to the consent of the lenders. 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. The ABL Facility remains undrawn as of December 31, 2024.
The amount that could be borrowed is temporarily limited due to the accrual of the wildfire tort-related claims, which reduces the amount of additional debt that could be incurred before exceeding certain financial covenants. The amount that could be drawn as of December 31, 2024 was approximately $150 million and will increase over time as earnings are generated and when HEI contributes equity related to the settlement payments or for capital expenditures.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 7 · Long-term debt
December 31 2024 2023
(dollars in thousands)
Long-term debt of Utilities, net of unamortized debt issuance costs 1
$ 1,901,214 $ 1,934,277
HEI 4.58% senior notes, due 2025
50,000 50,000
HEI 4.72% senior notes, due 2028
100,000 100,000
HEI 2.82% senior notes, due 2028
24,000 24,000
HEI 2.48% senior notes, due 2028
30,000 30,000
HEI 6.04% senior notes, due 2028
39,000 39,000
HEI 2.98% senior notes, due 2030
50,000 50,000
HEI 3.15% senior notes, due 2031
51,000 51,000
HEI 2.78% senior notes, due 2031
25,000 25,000
HEI 2.98% senior notes, due 2032
30,000 30,000
HEI 5.43% senior notes, due 2032
75,000 75,000
HEI 6.10% senior notes, due 2033
61,000 61,000
HEI 5.43% senior notes, due 2034
35,000 35,000
HEI 3.74% senior notes, due 2051
20,000 20,000
HEI 3.94% senior notes, due 2052
20,000 20,000
Hamakua Energy 4.02% non-recourse notes, due 20302
39,026 44,855
Mauo SOFR + 1.475% loan, paid in 20243
- 5,384
Mauo 5.07% non-recourse term loan, due 2034 to 20352, 4
20,795 16,962
Kaʻieʻie Waho 2.79% non-recourse loan, due 20312
8,517 9,727
Mahipapa 2.14% non-recourse loan, due 2034 to 20362, 5
53,263 53,743
Mahipapa 5.625% non-recourse loan, due 20272
424 578
HEI revolving credit facility SOFR + 1.80%, due 2026 to 20276
173,000 175,000
Less unamortized debt issuance costs and debt discount (6,681) (8,097)
Less current portion long-term debt, net of unamortized debt issuance cost
(109,171) (16,496)
Long term debt, net
$ 2,690,387 $ 2,825,933
1 See components of “Total long-term debt” and unamortized debt issuance costs in Hawaiian Electric and subsidiaries’ Consolidated Statements of Capitalization.
2 Secured by real and personal property of the respective entity, including various land parcels, a 60-MW combined cycle facility, photovoltaic and battery storage infrastructure, and a biomass plant. The aggregate net book value of the collateralized property, plant & equipment is approximately $165 million as of December 31, 2024.
3 As of July 1, 2023, LIBOR was replaced by the term SOFR plus the applicable margin of 1.375%, plus an additional 0.10% replacement rate adjustment. On February 8, 2024, the outstanding loan balance was fully paid and the loan was terminated.
4 In February 2024, the final tranche of the non-recourse loan was drawn. The notes bear interest at SOFR plus 1.7%. In connection with the non-recourse notes drawn under the credit agreement, Mauo entered into interest rate swaps that effectively convert the rate on the floating rate notes to fixed rates of 4.91% and 5.10%. As of December 31, 2024, the weighted-average interest rate was 5.07%, and as of December 31, 2023, the fixed rate was 4.91%.
5 As of December 31, 2024 and 2023, the weighted-average interest rate was 2.14% and 1.90%, respectively.
6 The interest rate is based on term SOFR plus the applicable margin of 1.75%, reduced by a 0.05% sustainability margin adjustment, plus an additional 0.10% spread adjustment. As of December 31, 2024 and 2023, the weighted-average interest rate was 6.89% and 7.19%, respectively.
As of December 31, 2024, the aggregate principal payments required on the Company’s long-term debt for 2025 through 2029 are $110 million in 2025, $153 million in 2026, $435 million in 2027, $274 million in 2028 and $51 million in 2029. As of December 31, 2024, the aggregate payments of principal required on the Utilities’ long-term debt for 2025 through 2029 are $47 million in 2025, $125 million in 2026, $266 million in 2027, $68 million in 2028 and $35 million in 2029.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The HEI term loans and senior notes contain customary representation and warranties, affirmative and negative covenants and events of default (the occurrence of which may result in some or all of the notes then outstanding becoming immediately due and payable). The HEI term loans and senior notes also contain provisions requiring the maintenance by HEI of certain financial ratios generally consistent with those in HEI’s revolving unsecured credit facility, as amended. Upon a change of control or certain dispositions of assets (as defined in the note purchase agreements of the senior notes), HEI is required to offer to prepay the senior notes.
The Utilities’ senior notes contain customary representations and warranties, affirmative and negative covenants, and events of default (the occurrence of which may result in some or all of the notes of each and all of the utilities then outstanding becoming immediately due and payable) and provisions requiring the maintenance by Hawaiian Electric, and each of Hawaii Electric Light and Maui Electric, of certain financial ratios generally consistent with those in Hawaiian Electric’s existing, amended revolving unsecured credit agreement.
Changes in long-term debt. As of December 31, 2024, HEI and Hawaiian Electric were in compliance with all applicable financial covenants.
HEI and Hawaiian Electric’s Credit Facilities. See Note 6 for more information.
Mahipapa non-recourse loan. In March 2024, a fire destroyed the cooling tower at the Mahipapa facility on Kauai. The fire was ignited from a vendor’s welding activities being performed on the cooling tower during its scheduled maintenance. As a result, the lender granted Mahipapa a deferral of three scheduled (July, September and December 2024) principal and interest payments totaling $5 million. The deferred payments will be repaid in quarterly payments commencing in March 2025. The facility was restarted in December 2024.
Note 8 · Shareholders’ equity
Reserved shares. As of December 31, 2024, HEI had a total of 27.5 million of authorized and unissued shares of common stock available for future issuance under the HEI Dividend Reinvestment and Stock Purchase Plan (DRIP), the Hawaiian Electric Industries Retirement Savings Plan (HEIRSP), the HEI 2011 Nonemployee Director Stock Plan, the 2010 Equity and Incentive Plan, as amended, and at-the-market offering program.
Accumulated other comprehensive income/(loss). Changes in the balances of each component of AOCI were as follows:
HEI Consolidated Hawaiian Electric Consolidated
(in thousands) Net unrealized gains (losses) on securities Unrealized gains (losses) on derivatives Retirement benefit plans AOCI AOCI-Retirement benefit plans
Balance, December 31, 2021 $ (32,037) $ (3,638) $ (16,858) $ (52,533) $ (3,280)
Current period other comprehensive income (loss) and reclassifications, net of taxes
(296,867) 5,629 7,743 (283,495) 6,141
Balance, December 31, 2022 (328,904) 1,991 (9,115) (336,028) 2,861
Current period other comprehensive income (loss) and reclassifications, net of taxes
45,941 (353) 1,090 46,678 (12)
Balance, December 31, 2023 (282,963) 1,638 (8,025) (289,350) 2,849
Current period other comprehensive income (loss) and reclassifications, net of taxes
1,785 482 917 3,184 (63)
Discontinued operations
281,178 - 8,449 289,627 -
Balance, December 31, 2024 $ - $ 2,120 $ 1,341 $ 3,461 $ 2,786
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Reclassifications out of AOCI were as follows:
Amount reclassified from AOCI Affected line item in the Statement of
Income/Balance Sheet
Years ended December 31 2024 2023 2022
(in thousands)
HEI consolidated
Available-for sale investment securities:
Net realized losses on securities included in net income
$ - $ 10,954 $ - Assets of discontinued operations
Amortization of unrealized holding losses on held-to-maturity securities 13,012 14,398 3,993 Income (loss) from discontinued operations
Net realized losses (gains) on derivatives qualifying as cash flow hedges
(201) (186) 172 Interest expense
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost
(1,730) (1,560) 19,659 See Note 11 for additional details
Impact of D&Os of the PUC included in regulatory assets (63,708) (8,204) (199,936) See Note 11 for additional details
Total reclassifications $ (52,627) $ 15,402 $ (176,112)
Hawaiian Electric consolidated
Retirement benefit plans:
Amortization of prior service credit and net losses (gains) recognized during the period in net periodic benefit cost
$ (2,035) $ (1,983) $ 18,884 See Note 11 for additional details
Impact of D&Os of the PUC included in regulatory assets (63,708) (8,204) (199,936) See Note 11 for additional details
Total reclassifications $ (65,743) $ (10,187) $ (181,052)
Note 9 · Leases
The Company leases certain real estate and equipment for various terms under long-term lease agreements. The agreements expire at various dates through 2054 and provide for renewal options up to 10 years. The periods associated with the renewal options are excluded for the purpose of determining the lease term unless the exercise of the renewal option is reasonably certain. In the normal course of business, it is expected that many of these agreements will be replaced by similar agreements. Certain real estate leases require the Company to pay for operating expenses such as common area maintenance, real estate taxes and insurance, which are recognized as variable lease expense when incurred and are not included in the measurement of the lease liability. The Company elected the short-term lease recognition exemption for all of its leases that qualify, and accordingly, does not recognize lease liabilities and ROU assets for all leases that have lease terms that are 12 months or less. The amounts related to short-term leases are not material. The Company elected the practical expedient to not separate lease and non-lease components for its real estate and equipment and fossil fuel and renewable energy PPAs and to separate lease components from non-lease components for renewable energy plus battery storage PPAs.
The Utilities contract with independent power producers to supply energy under long-term power purchase agreements. Certain PPAs are treated as operating leases under the lease standard because the Company elected the practical expedient package under which prior conclusions about lease identification were not reassessed. The fixed capacity payments under the PPAs are included in the lease liability, while the variable lease payments (e.g., payments based on kWh) are excluded from the lease liability. Several as-available PPAs have variable-only payment terms based on production. For PPAs with no minimum lease payments, the Utilities do not recognize any lease liabilities or ROU assets, and the related costs are reported as variable lease costs.
The Utilities’ lease payments for each operating lease agreement were discounted using its estimated unsecured borrowing rates for the appropriate term, increased for the estimated impact of collateral, which is an increase of approximately 500 basis points.
The Utilities account for the battery portion of renewable energy plus storage and energy storage PPAs as leases at their commencement dates. As of December 31, 2024, the Utilities recognized additional finance lease liabilities with corresponding
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
ROU assets of $104.9 million, including AES West Oahu Solar, AES Kuihelani Solar and Kupono Solar project that began commercial operations during the year. The timing of the Utilities’ recognition of the expense conforms to ratemaking treatment for the Utilities’ recovery of the cost of electricity and is included in purchased power for the interest and amortization of financing leases related to PPAs. Any material differences between expense recognition and timing of payments are deferred as a regulatory asset or liability in order to match what is being recovered for ratemaking purposes.
Amounts related to the Company’s total lease cost and cash flows arising from lease transactions are as follows:
HEI consolidated Hawaiian Electric consolidated
Year ended December 31, 2024 Other leases PPAs classified as leases Total Other leases PPAs classified as leases Total
(dollars in thousands)
Operating lease cost $ 13,736 $ 4,163 $ 17,899 $ 12,821 $ 4,163 $ 16,984
Variable lease cost 5,378 222,189 227,567 5,191 222,189 227,380
Sublease income (3,280) - (3,280) (3,280) - (3,280)
Total operating lease cost $ 15,834 $ 226,352 $ 242,186 $ 14,732 $ 226,352 $ 241,084
Finance lease costs:
Amortization of right-of-use assets $ 574 $ 19,498 $ 20,072 $ - $ 19,498 $ 19,498
Interest on lease liabilities 33 32,344 32,377 - 32,344 32,344
Total finance lease cost $ 607 $ 51,842 $ 52,449 $ - $ 51,842 $ 51,842
Other information
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases $ 15,604 $ 3,871 $ 19,475 $ 14,739 $ 3,871 $ 18,610
Operating cash flows from finance leases
33 30,939 30,972 - 30,939 30,939
Financing cash flows from finance leases
559 4,119 4,678 - 4,119 4,119
Weighted-average remaining lease term (in years):
Operating leases 8.2 3.0 7.2 6.4 3.0 5.6
Finance leases 3.7 19.9 19.9 - 19.9 19.9
Weighted-average discount rate:
Operating leases 3.08 % 8.78 % 4.11 % 2.95 % 8.78 % 4.21 %
Finance leases 2.23 % 8.50 % 8.49 % - 8.50 % 8.50 %
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
HEI consolidated Hawaiian Electric consolidated
Year ended December 31, 2023 Other leases PPAs classified as leases Total Other leases PPAs classified as leases Total
(dollars in thousands)
Operating lease cost $ 16,853 $ 4,071 $ 20,924 $ 15,947 $ 4,071 $ 20,018
Variable lease cost 5,813 202,556 208,369 5,605 202,556 208,161
Sublease income (3,031) - (3,031) (3,031) - (3,031)
Total operating lease cost
$ 19,635 $ 206,627 $ 226,262 $ 18,521 $ 206,627 $ 225,148
Finance lease costs:
Amortization of right-of-use assets $ 390 $ 5,591 $ 5,981 $ - $ 5,591 $ 5,591
Interest on lease liabilities 32 6,350 6,382 - 6,350 6,350
Total finance lease cost $ 422 $ 11,941 $ 12,363 $ - $ 11,941 $ 11,941
Other information
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases
$ 18,560 $ 4,071 $ 22,631 $ 17,729 $ 4,071 $ 21,800
Operating cash flows from finance leases
32 6,350 6,382 - 6,350 6,350
Financing cash flows from finance leases
391 3,128 3,519 - 3,128 3,128
Weighted-average remaining lease term (in years):
Operating leases
8.3 4.0 7.5 6.8 4.0 6.3
Finance leases
1.5 20.1 20.0 - 20.1 20.1
Weighted-average discount rate:
Operating leases
3.03 % 3.50 % 3.11 % 2.92 % 3.50 % 3.03 %
Finance leases
3.77 % 8.18 % 8.18 % - 8.18 % 8.18 %
The following table summarizes the maturity of our operating lease liabilities as of December 31, 2024:
HEI consolidated Hawaiian Electric consolidated
(in millions) Other leases PPAs classified as leases Total Other leases PPAs classified as leases Total
2025 $ 13 $ 5 $ 18 $ 12 $ 5 $ 17
2026 13 5 18 12 5 17
2027 7 5 12 6 5 11
2028 5 - 5 5 - 5
2029 5 - 5 5 - 5
Thereafter 24 - 24 16 - 16
Total lease payments 67 15 82 56 15 71
Less: Imputed interest (9) (2) (11) (5) (2) (7)
Total present value of lease payments1
$ 58 $ 13 $ 71 $ 51 $ 13 $ 64
1The fixed capacity payment related to the existing PPA with PGV, which will expire on December 31, 2027, is included as a lease liability as of December 31, 2024. The annual capacity payment based on the most recent accepted output is approximately $5.2 million for 2025. The lease liability will be remeasured when PGV ramps back up to the original contracted firm capacity.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The following table summarizes the maturity of our finance lease liabilities for PPAs as of December 31, 2024:
HEI consolidated Hawaiian Electric consolidated
(in millions) PPAs classified as leases PPAs classified as leases
2025 $ 45 $ 45
2026 45 45
2027 45 45
2028 45 45
2029 45 45
Thereafter 672 672
Total lease payments 897 897
Less: Imputed interest (462) (462)
Total present value of lease payments $ 435 $ 435
Note: Other finance leases are not material.
Note 10 · Revenues
Revenue from contracts with customers. The revenues subject to ASC Topic 606 include the Utilities’ electric energy sales revenue as further described below.
Electric Utilities.
Electric energy sales. Electric energy sales represent revenues from the generation and transmission of electricity to customers under tariffs approved by the PUC. Transaction pricing for electricity is determined and approved by the PUC for each rate class and includes revenues from the base electric charges, which are composed of (1) the customer, demand, energy, and minimum charges, and (2) the power factor, service voltage, and other adjustments as provided in each rate and rate rider schedule. Electric energy sales also represent contract rate charge from the generation and transmission of electricity to the Army. The monthly pricing is recalculated on an annual basis based on actual costs, approved by the Army.
The Utilities satisfy performance obligations of electric energy sales over time, i.e., the Utilities generate and transfer control of the electricity over time as the customer simultaneously receives and consumes the benefits provided by the Utilities’ performance. Payments from customers are generally due within 30 days from the end of the billing period. As electric bills to customers reflect the amount that corresponds directly with the value of the Utilities’ performance to date, the Utilities have elected to use the right to invoice practical expedient, which entitles them to recognize revenue in the amount they have the right to invoice.
The Utilities’ revenues include amounts for recovery of various Hawaii state revenue taxes. Revenue taxes are generally recorded as an expense in the year the related revenues are recognized. For 2024, 2023 and 2022, the Utilities’ revenues include recovery of revenue taxes of approximately $285 million, $291 million and $303 million, respectively, which amounts are in “Taxes, other than income taxes” expense. However, the Utilities pay revenue taxes to the taxing authorities based on (1) the prior year’s billed revenues (in the case of public service company taxes and PUC fees) in the current year or (2) the current year’s cash collections from electric sales (in the case of franchise taxes) after year end. As of December 31, 2024 and 2023, the Utilities had recorded $178 million and $182 million, respectively, in “Taxes accrued, including revenue taxes” on the Utilities’ consolidated balance sheet for amounts previously collected from customers or accrued for public service company taxes and PUC fees, net of amounts paid to the taxing authorities. Such amounts will be used to pay public service company taxes and PUC fees owed for the following year.
All Other.
All Other sales. Other sales primarily consist of revenues from the generation and sale of renewable energy at fixed contractual prices per kWh to customers under power purchase agreements by Pacific Current subsidiaries. The performance obligation is satisfied over time as renewable energy is generated and control is transferred to the customer that simultaneously receives and consumes the benefits provided. Payments from customers are generally due within 30 days from the end of the billing period. The bill to customers reflects the amount that corresponds directly with the value of performance to date. Pacific Current has elected to use the right to invoice practical expedient, which entitles it to recognize revenue in the amount they have the right to invoice.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Revenues from other sources. Revenues from other sources not subject to ASC Topic 606 are accounted for as follows:
Electric Utilities.
Regulatory revenues. Regulatory revenues primarily consist of revenues from the decoupling mechanism and cost recovery surcharges.
Decoupling mechanism - Under the current decoupling mechanism, the Utilities are allowed to recover or obligated to refund the difference between actual revenue and the target revenue as determined by the PUC, collect annual revenue adjustment mechanism (ARA) and exceptional project recovery mechanism revenues, and recover or refund performance incentive mechanism penalties or rewards. These adjustments will be reflected in tariffs in future periods. Under the PBR framework, the accrued RBA revenues as of the preceding September 30 balance and the annual ARA amount are billed from January 1 through December 31 of each year, which is within 24 months following the end of the year in which they are recorded as required by the accounting standard for alternative revenue programs (see “Regulatory proceedings” in Note 4).
Cost recovery surcharges - For the timely recovery of additional costs incurred, and reconciliation of costs and expenses included in tariffed rates, the Utilities recognize revenues under surcharge mechanisms approved by the PUC. These will be reflected in tariffs in future periods (e.g., ECRC and PPAC).
Since revenue adjustments discussed above resulted from either agreements with the PUC or change in tax law, rather than contracts with customers, they are not subject to the scope of ASC Topic 606. Also, see Notes 1, 4 and 13 of the Consolidated Financial Statements. The Utilities have elected to present these revenue adjustments on a gross basis, which results in the amounts being billed to customers presented in revenues from contracts with customers and the amortization of the related regulatory asset/liability as revenues from other sources. Depending on whether the previous deferral balance being amortized was a regulatory asset or regulatory liability, and depending on the size and direction of the current year deferral of surcharges and/or refunds to customers, it could result in negative regulatory revenue during the year.
Utility pole attachment fees. These fees primarily represent revenues from third-party companies for their access to and shared use of Utilities-owned poles through licensing agreements. As the shared portion of the utility pole is functionally dependent on the rest of the structure, no distinct goods appear to exist. Therefore, these fees are not subject to the scope of ASC Topic 606, but recognized in accordance with ASC Topic 610, Other Income.
Army privatization extraordinary O&M (EOM) fees. The monthly EOM fee provides the recovery of the incremental extraordinary O&M costs not covered under the standard utility services. The nature of the work related to transitional period revenue and monthly EOM fees do not represent the Utilities’ ongoing major or central operations (i.e., generating, and transmission and distribution of electricity) and is provided specifically for the arrangement between the Utilities and the Army. Therefore, these revenues are not subject to the scope of ASC Topic 606, but recognized in accordance with ASC Topic 610, Other Income.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Revenue disaggregation. The following tables disaggregate revenues by major source, timing of revenue recognition, and segment:
Year ended December 31, 2024 Year ended December 31, 2023
(in thousands) Electric utility Other Total Electric utility Other Total
Revenues from contracts with customers
Electric energy sales - residential
$ 1,012,620 $ - $ 1,012,620 $ 1,026,321 $ - $ 1,026,321
Electric energy sales - commercial
1,013,189 - 1,013,189 1,044,045 - 1,044,045
Electric energy sales - large light and power
1,123,884 - 1,123,884 1,141,128 - 1,141,128
Electric energy sales - other 18,682 - 18,682 19,471 - 19,471
Other sales - 11,923 11,923 - 17,540 17,540
Total revenues from contracts with customers 3,168,375 11,923 3,180,298 3,230,965 17,540 3,248,505
Revenues from other sources
Regulatory revenue (2,566) - (2,566) 3,708 - 3,708
Other 40,891 1,227 42,118 34,848 442 35,290
Total revenues from other sources 38,325 1,227 39,552 38,556 442 38,998
Total revenues $ 3,206,700 $ 13,150 $ 3,219,850 $ 3,269,521 $ 17,982 $ 3,287,503
Timing of revenue recognition
Total revenues from contracts with customers - services/goods transferred over time
$ 3,168,375 $ 11,923 $ 3,180,298 $ 3,230,965 $ 17,540 $ 3,248,505
There are no material contract assets or liabilities associated with revenues from contracts with customers existing at December 31, 2024 and 2023. Accounts receivable and unbilled revenues related to contracts with customers represent an unconditional right to consideration since all performance obligations have been satisfied. These amounts are disclosed as “Accounts receivable and unbilled revenues, net” on HEI’s consolidated balance sheets and “Customer accounts receivable, net” and “Accrued unbilled revenues, net” on Hawaiian Electric’s consolidated balance sheets.
As of December 31, 2024, the Company had no material remaining performance obligations due to the nature of the Company’s contracts with its customers. For the Utilities, performance obligations are fulfilled as electricity is delivered to customers.
Note 11 · Retirement benefits
ASB benefit obligation. As a result of the ASB sale transaction on December 31, 2024, the Company is no longer required to recognize the contractual obligations of ASB retirement plans. Accordingly, ASB’s benefit obligation and AOCI are presented as discontinued operations in the table below. Unless otherwise noted, references within the retirement benefit footnote exclude discontinued operations.
Defined benefit plans. Substantially all of the employees of HEI and the Utilities hired on or before December 31, 2021, participate in the Retirement Plan for Employees of Hawaiian Electric Industries, Inc. and Participating Subsidiaries (HEI Pension Plan). The HEI Pension Plan (the Plan) was closed to new employees first hired on or after January 1, 2022. The Plan is a qualified, noncontributory defined benefit pension plan and includes benefits for utility union employees determined in accordance with the terms of the collective bargaining agreements between the Utilities and the union. The Plan is subject to the provisions of ERISA. In addition, some current and former executives and directors of HEI and its subsidiaries participate in noncontributory, nonqualified plans (collectively, Supplemental Plans). In general, benefits are based on the employees’ or directors’ years of service and compensation.
The continuation of the Plan and the Supplemental Plans and the payment of any contribution thereunder are not assumed as contractual obligations by the participating employers. The Supplemental Plan for directors has been frozen since 1996. The HEI Supplemental Executive Retirement Plan, Disability, and Death Benefit Plan (noncontributory, nonqualified, defined benefit plans) were frozen as of December 31, 2008. No participants have accrued any benefits under these plans after the respective plan’s freeze and the plans will be terminated at the time all remaining benefits have been paid.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The participating employer reserves the right to terminate its participation in the applicable plans at any time, and HEI reserves the right to terminate its plans at any time. If a participating employer terminates its participation in the Plan, the interest of each affected participant would become 100% vested to the extent funded. Upon the termination of the Plan, assets would be distributed to affected participants in accordance with the applicable allocation provisions of ERISA and any excess assets that exist would be paid to the participating employers. Participants’ benefits in the Plan are covered up to certain limits under insurance provided by the Pension Benefit Guaranty Corporation.
Postretirement benefits other than pensions. HEI and the Utilities provide eligible employees health and life insurance benefits upon retirement under the Postretirement Welfare Benefits Plan for Employees of Hawaiian Electric Company, Inc. and participating employers (Hawaiian Electric Benefits Plan). Eligibility of employees and dependents is based on eligibility to retire at termination, the retirement date and the date of hire. The plan was amended in 2011, changing eligibility for certain bargaining unit employees hired prior to May 1, 2011, based on new minimum age and service requirements effective January 1, 2012, per the collective bargaining agreement, and certain management employees hired prior to May 1, 2011 based on new eligibility minimum age and service requirements effective January 1, 2012. The minimum age and service requirements for management and bargaining unit employees hired May 1, 2011 and thereafter have increased and their dependents are not eligible to receive postretirement benefits. Employees may be eligible to receive benefits from the HEI Pension Plan but may not be eligible for postretirement welfare benefits if the different eligibility requirements are not met.
The executive death benefit plan was frozen on September 10, 2009 for participants at benefit levels as of that date.
The Company’s and Utilities’ cost for OPEB has been adjusted to reflect the plan amendments, which reduced benefits and created prior service credits to be amortized over average future service of affected participants. The amortization of the prior service credit will reduce benefit costs until the various credit bases are fully recognized. Each participating employer reserves the right to terminate its participation in the Hawaiian Electric Benefits Plan at any time.
Balance sheet recognition of the funded status of retirement plans. Employers must recognize on their balance sheets the funded status of defined benefit pension and other postretirement benefit plans with an offset to AOCI in shareholders’ equity (using the projected benefit obligation (PBO) and accumulated postretirement benefit obligation (APBO), to calculate the funded status).
The PUC allowed the Utilities to adopt pension and OPEB tracking mechanisms in previous rate cases. The amount of the net periodic pension cost (NPPC) and net periodic benefits costs (NPBC) to be recovered in rates is established by the PUC in each rate case or as allowed under the PBR Framework (see “Regulatory proceedings” in Note 4). Under the Utilities’ tracking mechanisms, any actual costs determined in accordance with GAAP that are over/under amounts allowed in rates are charged/credited to a regulatory asset/liability. The regulatory asset/liability for each utility will then be amortized over 5 years beginning with the respective utility’s next rate case. Accordingly, all retirement benefit expenses (except for executive life and nonqualified pension plan expenses, which amounted to $0.9 million and $0.7 million in 2024 and 2023, respectively) determined in accordance with GAAP will be recovered.
Under the tracking mechanisms, amounts that would otherwise be recorded in AOCI (excluding amounts for executive life and nonqualified pension plans), net of taxes, as well as other pension and OPEB charges, are allowed to be reclassified as a regulatory asset, as those costs will be recovered in rates through the NPPC and NPBC in the future. The Utilities have reclassified to a regulatory asset/(liability) charges for retirement benefits that would otherwise be recorded in AOCI (amounting to the elimination of a potential adjustment to AOCI of $(85.8) million pretax and $(11.1) million pretax for 2024 and 2023, respectively).
Under the pension tracking mechanism, the Utilities are required to make contributions to the pension trust in the amount of the actuarially calculated NPPC, except when limited by the ERISA minimum contribution requirements or the maximum contributions imposed by the Internal Revenue Code. Contributions in excess of the calculated NPPC are recorded in a separate regulatory asset.
The OPEB tracking mechanisms generally require the Utilities to make contributions to the OPEB trust in the amount of the actuarially calculated NPBC, (excluding amounts for executive life), except when limited by material, adverse consequences imposed by federal regulations. Future decisions in rate cases could further impact funding amounts.
Defined benefit pension and other postretirement benefit plans information. The changes in the obligations and assets of the Company’s and Utilities’ retirement benefit plans and the changes in AOCI (gross) for 2024 and 2023 (ASB included in AOCI debit/credit except for December 31, 2024) and the funded status of these plans and amounts related to these plans reflected in the Company’s and Utilities’ consolidated balance sheets as of December 31, 2024 and 2023 were as follows:
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
2024 2023
(in thousands) Pension
benefits Other
benefits Pension
benefits Other
benefits
HEI consolidated
Benefit obligation, January 1- continuing operations
$ 1,951,821 $ 142,909 $ 1,776,060 $ 157,021
Benefit obligation, January 1- discontinued operations
81,157 434 80,705 415
Benefit obligation, January 1 2,032,978 143,343 1,856,765 157,436
Service cost 45,821 1,112 45,228 1,430
Interest cost 101,882 7,365 98,606 8,497
Actuarial loss (gain) (106,453) (9,913) 130,280 (13,863)
Participants contributions - 4,024 - 3,542
Benefits paid and expenses (99,494) (13,594) (98,353) (13,718)
Change in projected benefit obligations - discontinued operations
(81,157) (434) 452 19
Benefit obligation from continuing operations 1,893,577 131,903 1,951,821 142,909
Benefit obligation from discontinued operations
- - 81,157 434
Benefit obligation, December 31 1,893,577 131,903 2,032,978 143,343
Fair value of plan, January 1 - continuing operations
1,871,872 207,372 1,707,267 190,547
Fair value of plan, January 1 - discontinued operations
101,667 - 99,112 -
Fair value of plan assets, January 1 1,973,539 207,372 1,806,379 190,547
Actual return on plan assets 105,938 19,438 252,998 25,926
Employer contributions 8,778 - 8,274 -
Participants contributions - 4,024 - 3,542
Benefits paid and expenses (97,735) (12,944) (96,667) (12,643)
Change in plan assets - discontinued operations
(101,667) - 2,555 -
Fair value of plan assets from continuing operations
1,888,853 217,890 1,871,872 207,372
Fair value of plan assets from discontinued operations
- - 101,667 -
Fair value of plan assets, December 31 1,888,853 217,890 1,973,539 207,372
Accrued benefit asset (liability) from continuing operations
(4,724) 85,987 (79,949) 64,463
Accrued benefit asset (liability) from discontinued operations
- - 20,510 (434)
Accrued benefit asset (liability), December 31 $ (4,724) $ 85,987 $ (59,439) $ 64,029
Other assets (long-term)
$ 20,269 $ 87,066 $ - $ 65,527
Other liabilities (short-term)
(1,780) (1,079) (1,757) (1,064)
Defined benefit plans liability
(23,213) - (78,192) -
Accrued benefit asset (liability) from continuing operations
(4,724) 85,987 (79,949) 64,463
Accrued benefit asset (liability) from discontinued operations
- - 20,510 (434)
Accrued benefit asset (liability), December 31 $ (4,724) $ 85,987 $ (59,439) $ 64,029
AOCI debit/(credit), January 1 (excluding impact of PUC D&Os) $ 85,262 $ (49,618) $ 74,418 $ (26,238)
Recognized during year - prior service credit - - - 875
Recognized during year - net actuarial gain (loss)
(359) 2,898 (182) 1,865
Occurring during year - net actuarial loss (gain)
(73,969) (15,401) 12,471 (26,140)
Adjustment from discontinued operations
(11,897) 142 (1,445) 20
AOCI debit/(credit) before cumulative impact of PUC D&Os, December 31 (963) (61,979) 85,262 (49,618)
Cumulative impact of PUC D&Os 5,999 55,140 (67,732) 43,066
AOCI debit/(credit), December 31 $ 5,036 $ (6,839) $ 17,530 $ (6,552)
Net actuarial loss (gain) $ (963) $ (61,979) $ 85,262 $ (49,618)
Prior service gain - - - -
AOCI debit/(credit) before cumulative impact of PUC D&Os, December 31 (963) (61,979) 85,262 (49,618)
Cumulative impact of PUC D&Os 5,999 55,140 (67,732) 43,066
AOCI debit/(credit), December 31 5,036 (6,839) 17,530 (6,552)
Income taxes (benefits) (1,297) 1,761 (4,639) 1,689
AOCI debit/(credit), net of taxes (benefits), December 31 $ 3,739 $ (5,078) $ 12,891 $ (4,863)
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
2024 2023
(in thousands) Pension
benefits Other
benefits Pension
benefits Other
benefits
Hawaiian Electric consolidated
Benefit obligation, January 1 $ 1,888,463 $ 136,572 $ 1,716,125 $ 150,534
Service cost 44,669 1,096 44,143 1,415
Interest cost 98,492 7,039 95,351 8,143
Actuarial loss (gain)
(104,692) (9,688) 126,846 (13,721)
Participants contributions - 3,951 - 3,473
Benefits paid and expenses (95,785) (12,835) (94,783) (13,272)
Transfers (693) (47) 781 -
Benefit obligation, December 31 1,830,454 126,088 1,888,463 136,572
Fair value of plan assets, January 1 1,827,285 204,140 1,665,880 187,494
Actual return on plan assets 103,457 19,299 246,976 25,529
Employer contributions 8,733 - 8,252 -
Participants contributions - 3,951 - 3,473
Benefits paid and expenses (95,261) (12,600) (94,332) (12,356)
Other (538) (47) 509 -
Fair value of plan assets, December 31 1,843,676 214,743 1,827,285 204,140
Accrued benefit asset (liability), December 31 $ 13,222 $ 88,655 $ (61,178) $ 67,568
Defined benefit pension and other postretirement benefit plans asset
$ 20,164 $ 88,655 $ - $ 67,568
Other liabilities (short-term) (514) - (507) -
Defined benefit plans liability
(6,428) - (60,671) -
Accrued benefit asset (liability), December 31 $ 13,222 $ 88,655 $ (61,178) $ 67,568
AOCI debit/(credit), January 1 (excluding impact of PUC D&Os) $ 69,339 $ (48,510) $ 57,264 $ (25,402)
Recognized during year - prior service credit - - - 872
Recognized during year - net actuarial gain (loss)
(99) 2,840 (28) 1,827
Occurring during year - net actuarial loss (gain)
(73,215) (15,245) 12,103 (25,807)
AOCI debit/(credit) before cumulative impact of PUC D&Os, December 31 (3,975) (60,915) 69,339 (48,510)
Cumulative impact of PUC D&Os 5,999 55,140 (67,732) 43,066
AOCI debit/(credit), December 31 $ 2,024 $ (5,775) $ 1,607 $ (5,444)
Net actuarial loss (gain) $ (3,975) $ (60,915) $ 69,339 $ (48,510)
Prior service gain - - - -
AOCI debit/(credit) before cumulative impact of PUC D&Os, December 31 (3,975) (60,915) 69,339 (48,510)
Cumulative impact of PUC D&Os 5,999 55,140 (67,732) 43,066
AOCI debit/(credit), December 31 2,024 (5,775) 1,607 (5,444)
Income taxes (benefits) (522) 1,487 (414) 1,402
AOCI debit/(credit), net of taxes (benefits), December 31 $ 1,502 $ (4,288) $ 1,193 $ (4,042)
Pension benefits. In 2024, actuarial gains due to demographic experience, including any assumption changes, improved the funded position, offset by losses on the actual return on plan assets. The most impactful assumption change was the increase in the discount rate used to measure PBO compared to the prior year. Investment returns that were less than assumed partially offset the gain from the discount rate change.
In 2023, actuarial losses due to demographic experience, including any assumption changes, reduced the funded position. The most impactful of these assumption changes were the decrease in the discount rate used to measure PBO compared to the prior year and the change in assumed rates of retirement. Investment returns greater than assumed largely offset the decline.
Other benefits. In 2024, actuarial gains due to demographic experience, including any assumption changes, improved the funded position. The most impactful assumption change was the increase in the discount rate used to measure APBO compared to the prior year. In addition, investment returns that were better than expected, medical claims increases that were less than expected, and demographic experience further improved the funded position.
In 2023, actuarial gains due to demographic experience, including any assumption changes, improved the funded position. The most impactful of these assumption changes was a reduction in the percentage of participants expected to participate. This
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
gain was partially offset by a decrease in the discount rate. Investment returns greater than assumed further improved the funded position.
The dates used to determine retirement benefit measurements for the defined benefit plans and OPEB were December 31 of 2024, 2023 and 2022.
The Company uses the fair value method for the plans’ fixed income securities in the calculation of the expected return on plan assets component of NPPC and NPBC. The remaining plan assets continue to use the calculated market-related value methodology. The Company considers the fair value approach to be preferable for its fixed-income securities portfolio because it results in a current reflection of the changes in the value of plan assets in a way similar to the obligations it is intended to hedge. Amounts related to the Utilities were reflected as adjustments to regulatory assets as appropriate, consistent with the expected regulatory treatment as described in the following paragraph.
The Utilities have implemented pension and OPEB tracking mechanisms under which all of their retirement benefit expenses (except for executive life and nonqualified pension plan expenses) determined in accordance with GAAP are recovered over time. Under the tracking mechanisms, any actual costs determined in accordance with GAAP that are over/under amounts allowed in rates are charged/credited to a regulatory asset/liability. The regulatory asset/liability for each utility will then be amortized over 5 years beginning with the respective utility’s next rate proceeding.
A primary goal of the plans is to achieve long-term asset growth sufficient to pay future benefit obligations at a reasonable level of risk. The investment policy target for defined benefit pension and OPEB plans of HEI and the Utilities reflects the philosophy that long-term growth can best be achieved by prudent investments in equity securities while balancing overall fund and pension liability volatility by an appropriate allocation to fixed income securities. To reduce the level of portfolio risk and volatility in returns, efforts have been made to diversify the plans’ investments by asset class, geographic region, market capitalization and investment style.
The asset allocation of defined benefit retirement plans to equity and fixed income securities (excluding cash) and related investment policy targets and ranges were as follows:
Pension benefits
Other benefits
Investment policy1
Investment policy1
December 31, 2024 %
Target Range2
%
Target Range2
Assets held by category
U.S. equity securities 48 % 46 % 8-100%
54 % 54 % 14-100%
Non-U.S equity securities 19 17 0-37%
21 20 0-40%
Fixed income securities 30 32 11-51%
25 26 6-46%
Private equity 3 5 0-10%
- - -
100 % 100 % 100 % 100 %
Pension benefits
Other benefits
Investment policy Investment policy
December 31, 2023 %
Target Range3
%
Target Range3
Assets held by category
U.S. equity securities 56 % 50 % 40-65%
58 % 50 % 40-65%
Non-U.S equity securities 13 15 5-25%
15 15 5-25%
Fixed income securities 28 30 20-60%
27 30 20-60%
Private equity 3 5 0-10%
- 5 0-10%
100 % 100 % 100 % 100 %
1 Effective December 31, 2024, the investment policy statement was updated to reflect the 2024 transition from separately active investment managers to an outsourced chief investment officer model.
2 As of December 31, 2024, the broad range for equity securities is a minimum of 43% and a maximum of 83%, for pension benefits and a minimum of 54% and maximum of 94%, for other benefits.
3 As of December 31, 2023, the broad range for equity securities is a minimum of 60% and a maximum of 80% for pension benefits and other benefits.
The fair values of the investments shown in the tables below represent the Company’s best estimates of the amounts that would be received upon sale of those assets in an orderly transaction between market participants at that date. Those fair value measurements maximize the use of observable inputs. However, in situations where there is little, if any, market activity for the
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
asset at the measurement date, the fair value measurement reflects the Company’s judgments about the assumptions that market participants would use in pricing the asset. Those judgments are developed by the Company based on the best information available in the circumstances.
The Company used the following valuation methodologies for assets measured at fair value. There have been no changes in the methodologies used at December 31, 2024 and 2023.
Equity securities, equity index fund, exchange-traded funds, U.S. Treasury fixed income securities and mutual funds (Level 1). Equity securities, equity index fund, exchange-traded funds, U.S. Treasury fixed income securities and mutual funds are valued at the closing price reported on the active market on which the individual securities or funds are traded.
Fixed income securities (Level 2). Fixed income, other than those issued by the U.S. Treasury, are valued based on yields currently available on comparable securities of issuers with similar credit ratings.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Assets held in various trusts for the retirement benefit plans are measured at fair value on a recurring basis and were as follows:
Pension benefits Other benefits
Fair value measurements using Fair value measurements using
(in millions) December 31 Quoted prices in active markets for identical assets
(Level 1) Significant other observable inputs
(Level 2) December 31 Quoted prices in active markets for identical assets
(Level 1) Significant other observable inputs
(Level 2)
U.S. equity securities $ 403 $ 403 $ - $ 48 $ 48 $ -
Non-U.S. equity securities 20 20 - 2 2 -
U.S. equity index and exchange-traded funds (ETFs)
484 484 - 63 63 -
Non-U.S. equity index and ETFs
326 326 - 41 41 -
Total equity investments
1,233 1,233 - 154 154 -
Fixed income securities
546 401 145 52 22 30
Private equity at net asset value (NAV)
63 - - 1 - -
Cash equivalents, fund and at NAV 45 - - 10 10 -
Total 1,887 $ 1,634 $ 145 217 $ 186 $ 30
Cash, receivables and payables, net
2 1
Fair value of plan assets
$ 1,889 $ 218
U.S. equity securities $ 449 $ 449 $ - $ 54 $ 54 $ -
Non-U.S. equity securities 165 165 - 20 20 -
U.S. equity index and ETFs
584 584 - 64 64 -
Non-U.S. equity investments at NAV 77 - - 10 - -
Total equity investments
1,275 1,198 - 148 138 -
Fixed income securities1
85 13 72 - - -
Fixed income mutual and ETFs
264 264 - 53 53 -
Fixed income investments at NAV
250 - - 2 - -
Total fixed income investments
599 277 72 55 53 -
Private equity at NAV 50 - - 1 - -
Cash equivalents, fund and at NAV1
60 15 - 3 3 -
Total 1,984 $ 1,490 $ 72 207 $ 194 $ -
Cash, receivables and payables, net1
(10) -
Fair value of plan assets
$ 1,974 $ 207
1 Includes ASB assets held within the pension trust. As of December 31, 2023, ASB fixed income securities totaled $85 million, cash equivalents totaled $15 million and cash, receivables and payables, net totaled $1 million.
The fair value of investments measured at NAV presented in the table above is intended to permit reconciliation to the fair value of plan assets.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The following table represents assets measured at NAV.
Pension benefits Other benefits
Measured at NAV December 31 Redemption frequency Redemption notice period December 31 Redemption frequency Redemption notice period
(in millions)
Private equity (a)
$ 63 NA NA $ 1 NA NA
Cash equivalents (b)
45 Daily 0-1 day
- Daily 0-1 day
$ 108 $ 1
Non-U.S. equity funds (c)
$ 77 Daily-Monthly 5-30 days
$ 10 Daily-Monthly 5-30 days
Fixed income investments (d)
250 Daily 15 days
2 Daily 15 days
Private equity (a)
50 NA NA 1 NA NA
Cash equivalents (b)
45 Daily 0-1 day
- Daily 0-1 day
$ 422 $ 13
NA Not applicable
None of the investments presented in the tables above have unfunded commitments, other than private equity disclosed in (a) below.
(a) Represents investment in a private equity fund. The fund is valued as reported by the General Partner, based on the valuation of the underlying investments. As of December 31, 2024 and 2023, the unfunded commitment of the private equity fund was $122 million and $138 million, respectively. A second tranche commitment of $100 million was entered into effective January 1, 2023. The fund does not allow redemptions but may be dissolved with six months written notice. The termination date of the fund is November 1, 2100, unless dissolved earlier.
(b) Represents investments in cash equivalent funds. This class includes funds that invest primarily in securities issued or guaranteed by the U.S. government or its agencies or instrumentalities and may also invest in fixed income securities of investment grade issuers.
(c) Represents investments in funds that primarily invest in non-U.S. emerging markets equities. Redemption frequency for pension benefits assets as of December 31, 2023 were daily, 63% and monthly, 37%. Redemption frequency for other benefits assets as of December 31, 2023 were: daily, 61% and monthly, 39%.
(d) Represents investments in fixed income securities invested in a US-dollar denominated fund that seeks to exceed the Bloomberg US Long Corporate A or Better Bond Index through investments in US-dollar denominated fixed income securities and commingled vehicles.
The following weighted-average assumptions were used in the accounting for the plans:
Pension benefits Other benefits
December 31 2024 2023 2022 2024 2023 2022
Benefit obligation
Discount rate
5.77 % 5.35 % 5.67 % 5.72 % 5.39 % 5.66 %
Rate of compensation increase 3.5 3.5 3.5 NA NA NA
Net periodic pension/benefit cost (years ended)
Discount rate
5.35 5.67 3.05 5.39 5.66 3.07
Expected return on plan assets (gross return)
7.25 7.25 7.25 7.25 7.25 7.25
Rate of compensation increase1
3.5 3.5 3.5 NA NA NA
NA Not applicable
1 HEI and the Utilities use a graded rate of compensation increase assumption based on age. The rate provided above is an average across all future years of service for the current population.
The Company and the Utilities based their selection of an assumed discount rate for 2025 NPPC and NPBC and December 31, 2024 disclosure on a cash flow matching analysis that utilized bond information provided by Bloomberg for all non-callable, high quality bonds (generally rated Aa or better) as of December 31, 2024. In selecting the expected rate of return on plan assets for 2025 NPPC and NPBC, HEI and the Utilities considered economic forecasts for the types of investments held by the plans (primarily equity and fixed income investments), the Plans’ asset allocations, industry and corporate surveys and the past performance of the plans’ assets in selecting 7.25%. For 2024, retirement benefit plans’ assets of the Company and the Utilities both had a net gain of 6.7%.
As of December 31, 2024, the assumed health care trend rates for 2025 and future years were as follows: medical pre-65, 7.00% grading down to 5% for 2032 and thereafter; medical post-65, 6.50%, grading down to 5% for 2030 and thereafter; dental,
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
5%; and vision, 4%. As of December 31, 2023, the assumed health care trend rates for 2024 and future years were as follows: medical, 6.25%, grading down to 5% for 2029 and thereafter; dental, 5%; and vision, 4%.
The components of NPPC and NPBC were as follows:
Pension benefits Other benefits
(in thousands) 2024 2023 2022 2024 2023 2022
HEI consolidated
Service cost $ 45,821 $ 45,228 $ 77,823 $ 1,112 $ 1,430 $ 2,580
Interest cost 101,882 98,606 76,817 7,365 8,497 6,488
Expected return on plan assets (138,422) (135,189) (137,160) (13,950) (13,648) (13,621)
Amortization of net prior service gain
- - - - (875) (928)
Amortization of net actuarial losses (gains)
359 182 27,285 (2,898) (1,865) (8)
Net periodic pension/benefit cost 9,640 8,827 44,765 (8,371) (6,461) (5,489)
Impact of PUC D&Os 71,448 71,905 37,148 7,769 5,846 4,966
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)
$ 81,088 $ 80,732 $ 81,913 $ (602) $ (615) $ (523)
Hawaiian Electric consolidated
Service cost
$ 44,669 $ 44,143 $ 75,845 $ 1,096 $ 1,415 $ 2,554
Interest cost
98,492 95,351 74,363 7,039 8,143 6,227
Expected return on plan assets
(135,095) (131,962) (133,873) (13,742) (13,442) (13,381)
Amortization of net prior service gain
- - - - (872) (925)
Amortization of net actuarial losses (gains)
99 28 26,358 (2,840) (1,827) -
Net periodic pension/benefit cost 8,165 7,560 42,693 (8,447) (6,583) (5,525)
Impact of PUC D&Os
71,448 71,905 37,148 7,769 5,846 4,966
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)
$ 79,613 $ 79,465 $ 79,841 $ (678) $ (737) $ (559)
The Company recorded pension expense of $47 million, $43 million and $47 million in 2024, 2023 and 2022, respectively, and OPEB income of $(0.2) million, $(0.1) million and $(0.1) million in 2024, 2023 and 2022, respectively, and charged the remaining amounts primarily to electric utility plant. The Utilities recorded pension expense of $45 million, $42 million and $45 million, respectively, and OPEB income of $(0.3) million, $(0.3) million and $(0.1) million in 2024, 2023 and 2022, respectively, and charged the remaining amounts primarily to electric utility plant.
Additional information on the defined benefit pension plans’ accumulated benefit obligations (ABOs), which do not consider projected pay increases (unlike the PBOs shown in the table above), and pension plans with ABOs and PBOs in excess of plan assets as of December 31, 2024 and 2023 were as follows:
HEI consolidated Hawaiian Electric consolidated
December 31 2024 2023 2024 2023
(in billions)
Defined benefit pension plans - ABOs1
$ 1.7 $ 1.8 $ 1.7 $ 1.7
Defined benefit pension plans with PBOs in excess of plan assets2
PBOs
1.9 2.0 - 1.9
Fair value of plan assets
1.9 1.9 - 1.8
1 There are no defined benefit pension plans with ABOs in excess of fair value of plan assets.
2 Hawaiian Electric’s defined benefit pension plans do not have PBOs in excess of fair value of plan assets.
HEI consolidated. The Company estimates that the cash funding for the qualified defined benefit pension plans in 2025 will be $9 million, which will fully satisfy the ERISA minimum required contribution, the requirements of the Utilities’ pension tracking mechanisms and the Plan’s funding policy. The Company’s current estimate of contributions to its other postretirement benefit plans in 2025 is nil.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
As of December 31, 2024, the benefits expected to be paid under all retirement benefit plans in 2025, 2026, 2027, 2028, 2029 and 2030 through 2034 amount to $111 million, $115 million, $119 million, $122 million, $126 million and $677 million, respectively.
Hawaiian Electric consolidated. The Utilities estimate that the cash funding for the qualified defined benefit pension plan in 2025 will be $9 million, which will fully satisfy the ERISA minimum required contribution, the requirements of the pension tracking mechanisms and the Plan’s funding policy. The Utilities’ current estimate of contributions to its other postretirement benefit plans in 2025 is nil.
As of December 31, 2024, the benefits expected to be paid under all retirement benefit plans in 2025, 2026, 2027, 2028, 2029 and 2030 through 2034 amounted to $106 million, $111 million, $114 million, $117 million, $121 million and $652 million, respectively.
Defined contribution plans information. For 2024, 2023 and 2022, the Company’s expense and cash contributions for its defined contribution plans under the HEIRSP was $8 million, $6 million and $4 million, respectively. Included in the 2024, 2023 and 2022 amounts are non-elective employer contributions for the Utilities and HEI employees first hired on or after January 1, 2022, equal to 10% of those new employees’ annual compensation. For 2024, 2023 and 2022 the Utilities’ expense and cash contributions for its defined contribution plan under the HEIRSP was $7 million, $6 million and $4 million, respectively.
Note 12 · Share-based compensation
As a result of the ASB sale transaction on December 31, 2024, previously recorded share-based awards to ASB participants under the EIP (defined below) were cancelled. Unless otherwise noted, amounts in the share-based compensation footnote include discontinued operations.
Under the 2010 Equity and Incentive Plan, as amended and restated effective February 9, 2024 (EIP), HEI can issue shares of common stock as incentive compensation to non-employee directors and selected employees and consultants in the form of stock options, stock appreciation rights, restricted shares, restricted stock units, performance shares and other share-based and cash-based awards.
As of December 31, 2024, approximately 1.8 million shares remained available for future issuance under the terms of the EIP, assuming recycling of shares withheld to satisfy statutory tax liabilities relating to EIP awards, including an estimated 0.7 million shares that could be issued upon the vesting of outstanding restricted stock units and the achievement of performance goals for awards outstanding under long-term incentive plans (assuming that such performance goals are achieved at maximum levels).
Restricted stock units awarded under the EIP in 2023 and 2022 will vest and be issued in unrestricted stock in three equal annual increments on the anniversaries of the grant date and are forfeited to the extent they have not become vested for terminations of employment during the vesting period, except that pro-rata vesting is provided for terminations due to death, disability and retirement. Restricted stock units expense has been recognized in accordance with the fair-value-based measurement method of accounting. Dividend equivalent rights are accrued and are paid at the end of the restriction period when the associated restricted stock units vest.
Stock performance awards granted under the 2024-26, 2023-25 and 2022-24 long-term incentive plans (LTIP) entitle the grantee to shares of common stock with dividend equivalent rights once service conditions and performance conditions are satisfied at the end of the three-year performance period. LTIP awards are forfeited for terminations of employment during the performance period, except that pro-rata participation is provided for terminations due to death, disability and retirement based upon completed months of service after a minimum of 12 months of service in the performance period. Compensation expense for the stock performance awards portion of the LTIP has been recognized in accordance with the fair-value-based measurement method of accounting for performance shares.
Under the 2011 Nonemployee Director Stock Plan (2011 Director Plan), HEI can issue shares of common stock as compensation to nonemployee directors of HEI and its principal subsidiaries. As of December 31, 2024, there were 168,177 shares remaining available for future issuance under the 2011 Director Plan.
Share-based compensation expense and the related income tax benefit from continuing operations were as follows:
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(in millions) 2024 2023 2022
HEI consolidated
Share-based compensation expense1
$ 3.6 $ 6.8 $ 7.5
Income tax benefit 0.3 1.4 1.5
Hawaiian Electric consolidated
Share-based compensation expense1
1.8 3.3 3.0
Income tax benefit 0.2 0.8 0.7
1For 2024, 2023 and 2022, the Company has not capitalized any share-based compensation.
Stock awards. HEI granted HEI common stock to nonemployee directors under the 2011 Director Plan as follows:
(dollars in millions) 2024 2023 2022
Shares granted - 40,450 35,720
Fair value $ - $ 1.5 $ 1.5
Income tax benefit - 0.4 0.4
The number of shares issued to each nonemployee director of HEI and its principal subsidiaries is determined based on the closing price of HEI common stock on the grant date.
Restricted stock units. Information about HEI’s grants of restricted stock units was as follows:
2024 2023 2022
Shares (1) Shares (1) Shares (1)
Outstanding, January 1 189,024 $ 41.23 182,528 $ 39.75 233,448 $ 38.10
Granted - - 100,088 42.41 98,463 41.31
Vested (98,084) 40.43 (84,794) 39.41 (96,282) 37.75
Cancelled (2)
(24,241) 42.06 - - - -
Forfeited (1,071) 41.97 (8,798) 41.63 (53,101) 39.01
Outstanding, December 31 65,628 $ 42.09 189,024 $ 41.23 182,528 $ 39.75
Total weighted-average grant-date fair value of shares granted (in millions)
$ - $ 4.2 $ 4.1
(1)Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.
(2)Represents activity of discontinued operations.
For 2024, 2023 and 2022, total restricted stock units and related dividends that vested had a fair value of $1.4 million, $3.7 million and $4.2 million, respectively, and the related tax benefits were $0.3 million, $0.8 million and $0.6 million, respectively.
As of December 31, 2024, there was $1.1 million of total unrecognized compensation cost related to the nonvested restricted stock units. The cost is expected to be recognized over a weighted-average period of 1.1 years.
Long-term incentive plan payable in stock. The 2022-24, 2023-25 and 2024-26 LTIPs provide for performance awards under the EIP of shares of HEI common stock based on the satisfaction of performance goals, including a market condition goal. The number of shares of HEI common stock that may be awarded is fixed on the date the grants are made, subject to the achievement of specified performance levels and calculated dividend equivalents. The potential payout varies from 0% to 200% of the number of target shares, depending on the achievement of the goals. The market condition goal is based on HEI’s total shareholder return (TSR) compared to the Peer Group (Edison Electric Institute Index (EEI Index) for the 2022-24 performance period, and compared to the Company's compensation peer group consisting of companies in the EEI Index and approved by the Company's Compensation and Human Capital Management Committee for the 2023-25 and 2024-26 performance periods), in each case over the relevant three-year period. The other performance condition goals relate to EPS growth, cumulative EPS, return on average common equity (ROACE), carbon emissions reduction, Hawaiian Electric’s net income growth, credit rating and public safety and Pacific Current’s EBITDA growth and return on average invested capital.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
LTIP linked to TSR. Information about HEI’s LTIP grants linked to TSR was as follows:
2024 2023 2022
Shares (1) Shares (1) Shares (1)
Outstanding, January 1 76,477 $ 50.11 71,574 $ 47.67 90,974 $ 42.86
Granted 62,152 17.28 27,123 55.98 26,469 54.92
Vested (issued or unissued and cancelled) (28,577) 41.12 (18,691) 48.62 (29,042) 41.07
Cancelled (2)
(10,821) 55.46 - - - -
Forfeited (790) 55.64 (3,529) 53.72 (16,827) 44.45
Outstanding, December 31 98,441 $ 31.36 76,477 $ 50.11 71,574 $ 47.67
Total weighted-average grant-date fair value of shares granted (in millions)
$ 1.1 $ 1.5 $ 1.5
(1)Weighted-average grant-date fair value per share determined using a Monte Carlo simulation model.
(2)Represents activity of discontinued operations.
The grant date fair values of the shares were determined using a Monte Carlo simulation model utilizing actual information for the common shares of HEI and the Peer Group for the period from the beginning of the performance period to the grant date and estimated future stock volatility of HEI and the Peer Group over the remaining three-year performance period. The expected stock volatility assumptions for HEI and the Peer Group were based on the three-year historic stock volatility. A dividend assumption is not required for the Monte Carlo simulation because the grant payout includes dividend equivalents and projected returns include the value of reinvested dividends.
The following table summarizes the assumptions used to determine the fair value of the LTIP awards linked to TSR and the resulting fair value of LTIP awards granted:
2024 2023 2022
Risk-free interest rate 4.25 % 4.19 % 1.71 %
Expected life in years 3 3 3
Expected volatility 52.5 % 33.1 % 31.0 %
Range of expected volatility for Peer Group 12.3% to 52.5%
28.7% to 38.8%
25.4% to 76.7%
Grant date fair value (per share) $ 17.28 $ 55.98 $ 54.92
There were no share-based LTIP awards linked to TSR with a vesting date in 2024 and 2023. For 2022, total vested LTIP awards linked to TSR and related dividends had a fair value of $0.8 million, and the related tax benefits were $0.1 million.
As of December 31, 2024, there was $1.1 million of total unrecognized compensation cost related to the nonvested performance awards payable in shares linked to TSR. The cost is expected to be recognized over a weighted-average period of 1.8 years.
LTIP awards linked to other performance conditions. Information about HEI’s LTIP awards payable in shares linked to other performance conditions was as follows:
2024 2023 2022
Shares (1) Shares (1) Shares (1)
Outstanding, January 1 327,085 $ 39.44 309,589 $ 39.50 306,342 $ 38.42
Granted 362,963 13.09 108,499 42.41 105,860 41.31
Vested (113,118) 34.93 (62,778) 48.07 (71,807) 37.68
Increase above target/(cancelled) due to performance
(91,521) 41.31 (13,153) 36.59 36,505 35.75
Cancelled (2)
(43,277) 41.86 - - - -
Forfeited (3,165) 42.06 (15,072) 42.19 (67,311) 37.35
Outstanding, December 31 438,967 $ 18.17 327,085 $ 39.44 309,589 $ 39.50
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)
$ 4.8 $ 4.6 $ 4.4
(1)Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.
(2)Represents activity of discontinued operations.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
For 2024, 2023 and 2022, total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $1.7 million, $2.9 million and $3.2 million, respectively, and the related tax benefits were $0.3 million, $0.6 million and $0.4 million, respectively.
As of December 31, 2024, there was $3.4 million of total unrecognized compensation cost related to the nonvested shares linked to performance conditions other than TSR. The cost is expected to be recognized over a weighted-average period of 1.8 years.
Note 13 · Income taxes
The components of income taxes attributable to income (loss) from continuing operations for common stock were as follows:
HEI consolidated Hawaiian Electric consolidated
Years ended December 31 2024 2023 2022 2024 2023 2022
(in thousands)
Federal
Current $ 13,220 $ 22,206 $ 61,511 $ 34,216 $ 40,365 $ 75,118
Deferred (376,141) 1,951 (37,922) (373,316) (3,444) (39,646)
Deferred tax credits, net* - 52 4,031 - 22 137
(362,921) 24,209 27,620 (339,100) 36,943 35,609
State
Current 2,009 2,924 6,467 7,864 9,367 15,780
Deferred (110,050) 7,401 4,772 (108,311) 4,883 (1,769)
Deferred tax credits, net* - - 56 - - 56
(108,041) 10,325 11,295 (100,447) 14,250 14,067
Total $ (470,962) $ 34,534 $ 38,915 $ (439,547) $ 51,193 $ 49,676
* In 2022, primarily represents federal tax credits related to Mauo’s solar-plus-storage project, deferred and amortized starting in 2022.
A reconciliation of the amount of income taxes computed at the federal statutory rate to the amount provided in the consolidated statements of income was as follows:
HEI consolidated Hawaiian Electric consolidated
Years ended December 31 2024 2023 2022 2024 2023 2022
(in thousands)
Amount at the federal statutory income tax rate $ (376,235) $ 38,283 $ 42,410 $ (349,423) $ 51,899 $ 50,526
Increase (decrease) resulting from:
State income taxes, net of federal income tax benefit
(85,483) 7,989 8,812 (79,487) 11,097 11,026
Net deferred tax asset (liability) adjustment related to the Tax Act
(6,200) (7,316) (9,886) (6,200) (7,316) (9,886)
Tax credits, net
(2,987) (2,251) (487) (2,987) (2,251) (397)
Other, net (57) (2,171) (1,934) (1,450) (2,236) (1,593)
Total $ (470,962) $ 34,534 $ 38,915 $ (439,547) $ 51,193 $ 49,676
Effective income tax rate (%) 26.3 18.9 19.3 26.4 20.7 20.6
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The tax effects of book and tax basis differences that give rise to deferred tax assets and liabilities were as follows:
HEI consolidated Hawaiian Electric consolidated
December 31 2024 2023 2024 2023
(in thousands)
Deferred tax assets
Wildfire tort-related claims
$ 483,749 $ - $ 483,749 $ -
Regulatory liabilities, excluding amounts attributable to property, plant and equipment
76,765 78,884 $ 76,765 $ 78,884
Lease liabilities
130,556 109,480 128,610 107,409
Retirement benefits 45,879 28,623 40,568 23,247
Revenue taxes 48,379 49,522 48,379 49,522
Capital loss carryforward
66,430 - - -
Other1
35,827 27,003 22,387 20,817
Total deferred income tax assets
887,585 293,512 800,458 279,879
Valuation allowances
(73,459) - - -
Total deferred income tax assets, net
814,126 293,512 800,458 279,879
Deferred tax liabilities
Property, plant and equipment related 542,109 527,323 532,257 513,064
Lease right-of-use assets
130,483 109,420 128,610 107,409
Regulatory assets, excluding amounts attributable to property, plant and equipment
21,678 21,872 21,678 21,872
Other 47,148 37,103 46,330 36,535
Total deferred income tax liabilities
741,418 695,718 728,875 678,880
Net deferred income tax asset (liability)
$ 72,708 $ (402,206) $ 71,583 $ (399,001)
1 As of December 31, 2024, HEI consolidated has deferred tax assets of $3.8 million relating to the benefit of state tax credit carryforwards of $5.2 million. These state tax credit carryforwards primarily relate to the West Loch PV project that do not expire.
The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences are deductible. Based upon historical taxable income and projections for future taxable income, management believes it is more likely than not the Company and the Utilities will realize substantially all of the benefits of the deferred tax assets, excluding the capital loss from the sale of ASB. As of December 31, 2024 and 2023, valuation allowances for deferred tax benefits were $73.5 million and nil, respectively, recorded on HEI consolidated related to the capital loss from the sale of ASB and the book/tax difference in equity basis of retained ASB stock. Since capital losses can only be offset against capital gains, the Company believes that it is more likely than not that the tax benefit from ASB's capital loss will not be realized. This is due to the lack of expected capital gains and no tax strategies in place to generate capital gains within the next five years before the loss expires. As a result, a valuation allowance was established in 2024. The Utilities are included in the consolidated federal and Hawaii income tax returns of HEI and are subject to the provisions of HEI’s tax sharing agreement, which determines each subsidiary’s (or subgroup’s) income tax return liabilities and refunds on a standalone basis as if it filed a separate return (or subgroup consolidated return).
The following is a reconciliation of the Company’s liability for unrecognized tax benefits for 2024, 2023 and 2022.
HEI consolidated Hawaiian Electric consolidated
(in millions) 2024 2023 2022 2024 2023 2022
Unrecognized tax benefits, January 1 $ 27.7 $ 30.6 $ 17.1 $ 15.6 $ 11.7 $ 11.6
Additions based on tax positions taken during the year 0.7 0.5 19.0 - 0.3 0.1
Reductions based on tax positions taken during the year (0.1) - (3.5) - - -
Additions for tax positions of prior years 1.5 3.8 0.6 1.5 3.7 0.2
Reductions for tax positions of prior years (4.6) (7.2) (2.6) (0.6) (0.1) (0.2)
Lapses of statute of limitations (1.9) - - (0.5) - -
Settlement (10.8) - - (10.8) - -
Unrecognized tax benefits, December 31 $ 12.5 $ 27.7 $ 30.6 $ 5.2 $ 15.6 $ 11.7
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The Internal Revenue Service began its examination of the Company’s U.S. income tax returns for 2017 and 2018 in the third quarter of 2020. As of December 31, 2024, the Company’s 2017 and 2018 IRS examination was completed and resulted in a reversal of $10.8 million of unrecognized tax benefits.
At December 31, 2024 and 2023, there were $5.2 million and $13.8 million of unrecognized tax benefits, respectively, that, if recognized, would affect the Company’s and Utilities’ annual effective tax rate.
Based on information currently available, the Company and the Utilities believe these accruals have adequately provided for potential income tax issues with federal and state tax authorities, and that the ultimate resolution of tax issues for all open tax periods will not have a material adverse effect on its results of operations, financial condition or liquidity.
Tax years post 2020 remains open under Federal and Hawaii statues of limitations.
HEI consolidated. The Company recognizes interest accrued related to unrecognized tax benefits in “Interest expense, net” and penalties, if any, in operating expenses. In 2024, 2023 and 2022, the Company recognized approximately $0.3 million, $1.3 million and $0.4 million, respectively, in interest expense. The Company had $2.3 million and $1.9 million of interest accrued as of December 31, 2024 and 2023, respectively.
Hawaiian Electric consolidated. The Utilities recognize interest accrued related to unrecognized tax benefits in “Interest expense and other charges, net” and penalties, if any, in operating expenses. In each of 2024, 2023 and 2022, the Utilities recognized approximately $0.3 million, $0.1 million and $0.1 million in interest expense, respectively. The Utilities had $0.1 million and $0.4 million of interest accrued as of December 31, 2024 and 2023, respectively.
As of December 31, 2024, the disclosures above present the Company’s and the Utilities’ accruals for potential tax liabilities, which involve management’s judgment regarding the likelihood of the benefits being sustained under governmental review.
Tax developments. The Inflation Reduction Act of 2022 (IRA) was signed by President Biden on August 16, 2022. Key provisions under the IRA include a 15% corporate alternative minimum tax (CAMT) imposed on certain large corporations and a 1% excise tax on stock repurchases after December 31, 2022. Based on current interpretation of the law and current guidance available we do not believe HEI will be impacted by the CAMT or stock repurchase excise tax provisions.
The IRA also creates new tax credits and enhances others to stimulate investment in renewable energy sources. Certain provisions of the IRA became effective in tax year 2023. The Company is exploring clean energy tax incentives included in the IRA. However, the potential IRA tax credits would not be material to the Company’s financial statements given the current operations of the business.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 14 · Cash flows
Years ended December 31 2024 2023 2022
(in millions)
Supplemental disclosures of cash flow information
HEI consolidated
Activities from continuing operations:
Interest paid to non-affiliates, net of amounts capitalized $ 131 $ 109 $ 94
Interest paid on finance lease obligations 31 6 1
Income taxes paid (net of refundable credits) 32 24 32
Income taxes refunded (including refundable credits) - 1 2
Activities from discontinued operations:
Interest paid to non-affiliates, net of amounts capitalized 121 61 12
Income taxes paid (net of refundable credits) 4 4 9
Income taxes refunded (including refundable credits) 2 - -
Hawaiian Electric consolidated
Interest paid to non-affiliates, net of amounts capitalized 88 74 69
Interest paid on finance lease obligations
31 6 1
Income taxes paid (net of refundable credits)
59 39 67
Income taxes refunded (including refundable credits) - 2 -
Supplemental disclosures of noncash activities
HEI consolidated
Activities from continuing operations:
Property, plant and equipment-Unpaid invoices and accruals for capital expenditures, balance, end of period (investing) 43 43 67
Common stock dividends reinvested in HEI common stock (financing) 1
- 5 -
Right-of-use assets obtained in exchange for operating lease obligations (investing) 2 - 47
Property, plant, equipment and other assets received in exchange for the assumption of debt associated with a business acquisition (investing) - - 68
Debt, lease liabilities and other liabilities assumed in business acquisition (financing) - - 68
Common stock issued (gross) for director and executive/management compensation (financing)1
2 6 9
Right-of-use assets obtained in exchange for finance lease obligations (financing) 106 294 48
Activities from discontinued operations:
Sale of ASB (investing/financing) (see Note 5)
(508) - -
Property, plant and equipment-Unpaid invoices and accruals for capital expenditures, balance, end of period (investing) - - 1
Loans transferred from held for investment to held for sale (investing) 29 106 -
Transfer of retail repurchase agreements to deposit liabilities (financing) - 98 -
Obligations to fund low income housing investments, net (investing) - 18 9
Transfer of securities from available for sale to held to maturities (investing) - - 755
Common stock issued (gross) for director and executive/management compensation (financing)1
1 2 1
Right-of-use assets obtained in exchange for operating lease obligations (investing) 5 1 4
Hawaiian Electric consolidated
Electric utility property, plant and equipment-Unpaid invoices and accruals for capital expenditures, balance, end of period (investing) 42 42 64
Right-of-use assets obtained in exchange for operating lease obligations (investing) 2 - 44
Right-of-use assets obtained in exchange for finance lease obligations (financing) 105 294 48
HEI Consolidated and Hawaiian Electric consolidated
Electric utility property, plant and equipment
Estimated fair value of noncash contributions in aid of construction (investing) 19 21 14
Increase related to an acquisition (investing) - - 15
1 The amounts shown represent the market value of common stock issued for director and executive/management compensation and withheld to satisfy statutory tax liabilities.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 15 · Regulatory restrictions on net assets
The ability of Hawaiian Electric to pay dividends or make other distributions to HEI are subject to contractual and regulatory restrictions. Under the PUC Agreement, in the event that the consolidated common stock equity of the electric utility subsidiaries falls below 35% of the total capitalization of the electric utilities (including the current maturities of long-term debt, but excluding short-term borrowings), the electric utility subsidiaries would, absent PUC approval, be restricted in their payment of cash dividends to 80% of the earnings available for the payment of dividends in the current fiscal year and preceding five years, less the amount of dividends paid during that period. The PUC Agreement also provides that the foregoing dividend restriction shall not be construed as relinquishing any right the PUC may have to review the dividend policies of the electric utility subsidiaries. As of December 31, 2024, the consolidated common stock equity of HEI’s electric utility subsidiaries was 33% of their total capitalization, which includes finance lease liabilities in the calculation of total capitalization. The Utilities plan to file with the PUC, a modified capitalization ratio of 37% to align with its debt covenant requirements, which excludes finance lease liabilities resulting from power purchase agreements. As of December 31, 2024, Hawaiian Electric and its subsidiaries had common stock equity of $1.2 billion, which, in total, was not available for transfer to HEI in the form of dividends, loans or advances without regulatory approval.
HEI and its subsidiaries are also subject to debt covenants, preferred stock resolutions and the terms of guarantees that could limit their respective abilities to pay dividends. The Company does not expect that the regulatory and contractual restrictions applicable to HEI and/or its subsidiaries will significantly affect the operations of HEI.
Note 16 · Significant group concentrations of credit risk
Most of the Company’s business activity is with customers located in the State of Hawaii.
The Utilities are regulated operating electric public utilities engaged in the generation, purchase, transmission, distribution and sale of electricity on the islands of Oahu, Hawaii, Maui, Lanai and Molokai in the State of Hawaii. The Utilities provide the only electric public utility service on the islands they serve. The Utilities extend credit to customers, all of whom reside or conduct business in the State of Hawaii. See Note 4 for a discussion of the Utilities’ major customers. The Utilities target compensation at market rates, and due to the significant increase in competitive market pay for linemen over the past few years, provided an 11.4% market rate adjustment and a 4% annual incentive effective February 1, 2024. The International Brotherhood of Electrical Workers Local 1260 represents roughly half of the Utilities’ workforce covered by a collective bargaining agreement. On January 26, 2024, a new three-year contract was ratified and is in effect from November 1, 2024 through October 31, 2027. The contract provides for a 3% general wage increase in each year of the three-year contract, double time for callouts, and a 1% incentive payment upon achievement of specified objectives.
Financial instruments that potentially subject the Company to significant concentrations of credit risk consist principally of cash, cash equivalents and restricted cash. The Company maintains its cash with what management believes to be high-credit quality financial institutions located in the U.S. Accounts are guaranteed by the Federal Deposit Insurance Corporation (FDIC) up to $250,000, under current regulations. At times, deposits held at these banks may exceed the insured limits. As of December 31, 2024, HEI held cash and cash equivalents and restricted cash of $2 million and $10 million, respectively, in FDIC insured accounts. As of December 31, 2024, the Utilities held cash and cash equivalents of $69 million in FDIC insured accounts. The Company has not experienced any losses in such accounts.
The Company also maintains cash in highly rated taxable and tax-exempt money market mutual funds located in the U.S. The company minimizes risk by investing in money market mutual funds which invest in securities issued by U.S. Government and Government-Sponsored Enterprises and the fund has a AAA rating. Risks associated with cash and cash equivalents are mitigated by the Company’s investment policy, which limits the Company’s investing of excess cash into relatively low risk securities that meet minimum credit quality standards that are defined in the policy. As of December 31, 2024, HEI held cash and cash equivalents and restricted cash of $565 million and $482 million, respectively, in money market mutual funds. As of December 31, 2024, the Utilities held cash and cash equivalents of $116 million in money market mutual funds.
Pacific Current’s investments are in projects located in the State of Hawaii since its strategy is focused on investing in non-regulated renewable energy and sustainable infrastructure in the State of Hawaii.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 17 · Fair value measurements
Fair value measurement and disclosure valuation methodology. The following are descriptions of the valuation methodologies used for assets and liabilities recorded at fair value and for estimating fair value for financial instruments not carried at fair value:
Money market mutual funds. The Company considers all liquid investments purchased with an initial maturity of three months or less and deposits in money market mutual funds that are readily convertible into cash to be cash equivalents. The carrying value of cash and cash equivalents approximates fair value due to the short-term nature of these instruments.
Short-term borrowings. The carrying amount of short-term borrowings approximated fair value because of the short maturity of these instruments.
Long-term debt. Fair value of fixed-rate long-term debt was obtained from third-party financial services providers based on the current rates offered for debt of the same or similar remaining maturities and from discounting the future cash flows using the current rates offered for debt of the same or similar risks, terms, and remaining maturities. The carrying amount of floating rate long-term debt approximated fair value because of the short-term interest reset periods. Long-term debt is classified in Level 2 of the valuation hierarchy.
Interest rate swaps. The Company measures its interest rate swaps at fair value. The fair values of the Company's interest rate swaps are based on the estimated amounts that the Company would receive or pay to terminate the contracts at the reporting date and are determined using interest rate pricing models and interest rate related observable inputs. The fair values of the Company's interest rate swaps are classified as a Level 2 measurements.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
The following table presents the carrying or notional amount, fair value and placement in the fair value hierarchy of the Company’s financial instruments.
Estimated fair value
(in thousands) Carrying or notional
amount Quoted prices in active markets for identical assets
(Level 1) Significant other observable inputs
(Level 2) Significant unobservable inputs
(Level 3) Total
December 31, 2024
Financial assets
HEI consolidated
Money market mutual funds
$ 1,162,259 $ 1,162,259 $ - $ - $ 1,162,259
Derivative assets 29,312 - 1,629 - 1,629
Hawaiian Electric consolidated
Money market mutual funds
115,599 115,599 - - 115,599
Financial liabilities
HEI consolidated
Short-term borrowings
48,623 - 48,623 - 48,623
Long-term debt, net
2,799,558 - 2,196,403 - 2,196,403
Hawaiian Electric consolidated
Short-term borrowings
48,623 - 48,623 - 48,623
Long-term debt, net
1,901,214 - 1,446,316 - 1,446,316
December 31, 2023
Financial assets
HEI consolidated
Money market mutual funds
$ 226,085 $ 226,085 $ - $ - $ 226,085
Derivative assets 10,634 - 972 - 972
Hawaiian Electric consolidated
Money market mutual funds
85,807 85,807 - - 85,807
Financial liabilities
HEI consolidated
Long-term debt, net
2,842,429 - 2,133,225 - 2,133,225
Derivative liabilities 22,949 - 303 - 303
Hawaiian Electric consolidated
Long-term debt, net
1,934,277 - 1,385,025 - 1,385,025
Assets and liabilities measured at fair value on a recurring basis include money market mutual funds and derivative assets and liabilities as included in the table above. Money market mutual funds are included in “Cash and cash equivalents” and “Restricted cash” in the Consolidated Balance Sheets. Derivatives are included in “Other noncurrent assets” and “Other noncurrent liabilities” in the Consolidated Balance Sheets.
There were no transfers of financial assets and liabilities between Level 1 and Level 2 of the fair value hierarchy during the years ended December 31, 2024 and 2023.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
Note 18. Unaudited summarized quarterly information
The unaudited quarterly financial information for the years 2024 and 2023 has been recast for discontinued operations presentation as discussed in Note 5 and is summarized below.
(in thousands, except per share amounts) 1Q24 2Q24 3Q24 4Q24 2024
Revenues
Electric utility $ 788,578 $ 792,331 $ 829,617 $ 796,174 $ 3,206,700
Other 3,436 3,086 3,622 3,006 13,150
Total revenues 792,014 795,417 833,239 799,180 3,219,850
Operating income (loss)
Electric utility 63,355 (1,644,440) (104,564) 73,791 (1,611,858)
Other (12,468) (17,149) (45,156) (20,129) (94,902)
Total operating income (loss) 50,887 (1,661,589) (149,720) 53,662 (1,706,760)
Income (loss) from continuing operations for common stock
21,188 (1,249,697) (123,180) 29,166 (1,322,523)
Income (loss) from discontinued operations
20,934 (45,787) 18,778 (97,411) (103,486)
Net income (loss) for common stock
$ 42,122 $ (1,295,484) $ (104,402) $ (68,245) $ (1,426,009)
Continuing operations - Basic earnings (loss) per common share
$ 0.19 $ (11.33) $ (1.08) $ 0.17 $ (10.42)
Discontinued operations - Basic earnings (loss) per common share
0.19 (0.42) 0.16 (0.56) (0.81)
Basic earnings (loss) per common share $ 0.38 $ (11.74) $ (0.91) $ (0.40) $ (11.23)
Continuing operations - Diluted earnings (loss) per common share
$ 0.19 $ (11.33) $ (1.08) $ 0.17 $ (10.42)
Discontinued operations - Diluted earnings (loss) per common share
0.19 (0.42) 0.16 (0.56) (0.81)
Diluted earnings (loss) per common share $ 0.38 $ (11.74) $ (0.91) $ (0.40) $ (11.23)
Weighted-average number of common shares outstanding 110,218 110,303 114,358 172,466 126,927
Weighted-average shares assuming dilution 110,476 110,303 114,358 172,466 126,927
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)
(in thousands, except per share amounts) 1Q23 2Q23 3Q23 4Q23 2023
Revenues
Electric utility $ 830,361 $ 794,191 $ 794,987 $ 849,982 $ 3,269,521
Other 4,019 4,609 5,912 3,442 17,982
Total revenues 834,380 798,800 800,899 853,424 3,287,503
Operating income (loss)
Electric utility 75,875 73,625 71,358 81,300 302,158
Other (5,877) (5,514) (8,806) (6,969) (27,166)
Total operating income (loss) 69,998 68,111 62,552 74,331 274,992
Income from continuing operations for common stock
36,159 34,406 29,753 45,558 145,876
Income from discontinued operations
18,562 20,204 11,365 3,231 53,362
Net income (loss) for common stock
$ 54,721 $ 54,610 $ 41,118 $ 48,789 $ 199,238
Continuing operations - Basic earnings per common share $ 0.33 $ 0.31 $ 0.27 $ 0.41 $ 1.33
Discontinued operations - Basic earnings per common share 0.17 0.18 0.10 0.03 0.49
Basic earnings per common share
$ 0.50 $ 0.50 $ 0.37 $ 0.44 $ 1.82
Continuing operations - Diluted earnings per common share $ 0.33 $ 0.31 $ 0.27 $ 0.41 $ 1.33
Discontinued operations - Diluted earnings per common share 0.17 0.18 0.10 0.03 0.48
Diluted earnings per common share
$ 0.50 $ 0.50 $ 0.37 $ 0.44 $ 1.81
Weighted-average number of common shares outstanding 109,514 109,573 109,728 110,134 109,739
Weighted-average shares assuming dilution 109,825 109,780 109,917 110,301 110,038

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
HEI and Hawaiian Electric: None

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ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A. CONTROLS AND PROCEDURES
HEI:
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
Scott W. H. Seu, HEI Chief Executive Officer (CEO), and Scott T. DeGhetto, HEI Chief Financial Officer (CFO), have evaluated the disclosure controls and procedures of HEI as of December 31, 2024. Based on their evaluation, as of December 31, 2024, they have concluded that the disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) were effective in ensuring that information required to be disclosed by HEI in reports HEI files or submits under the Securities Exchange Act of 1934:
(1)is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission rules and forms, and
(2)is accumulated and communicated to HEI management, including HEI’s CEO and CFO, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
Management’s Annual Report on Internal Control Over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rule 13a-15(f) and Rule 15d-15(f) promulgated under the Securities Exchange Act of 1934, as amended. The Company’s internal control over financial reporting was designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting as of December 31, 2024 based on criteria established in Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on this evaluation, management has concluded that the Company’s internal control over financial reporting was effective as of December 31, 2024.
The effectiveness of the Company’s internal control over financial reporting as of December 31, 2024 has been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in its report which appears herein.
Changes in Internal Control over Financial Reporting
There have been no changes in internal control over financial reporting during the quarter ended December 31, 2024 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.
Hawaiian Electric:
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
Shelee M. T. Kimura, Hawaiian Electric CEO, and Paul K. Ito, Hawaiian Electric CFO, have evaluated the disclosure controls and procedures of Hawaiian Electric as of December 31, 2024. Based on their evaluation, as of December 31, 2024, they have concluded that the disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended) were effective in ensuring that information required to be disclosed by Hawaiian Electric in reports Hawaiian Electric files or submits under the Securities Exchange Act of 1934:
(1)is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission rules and forms, and
(2)is accumulated and communicated to Hawaiian Electric management, including Hawaiian Electric’s CEO and CFO, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
Management’s Annual Report on Internal Control Over Financial Reporting
Management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Rule 13a-15(f) and Rule 15d-15(f) promulgated under the Securities Exchange Act of 1934, as amended. Hawaiian Electric’s internal control over financial reporting was designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Management conducted an evaluation of the effectiveness of Hawaiian Electric’s internal control over financial reporting as of December 31, 2024 based on criteria established in Internal Control - Integrated Framework (2013) issued by COSO. Based on this evaluation, management has concluded that Hawaiian Electric’s internal control over financial reporting was effective as of December 31, 2024.
Changes in Internal Control over Financial Reporting
There have been no changes in internal control over financial reporting during the quarter ended December 31, 2024 that have materially affected, or are reasonably likely to materially affect, Hawaiian Electric’s internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
HEI and Hawaiian Electric: None

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
HEI:
Information regarding HEI’s executive officers is provided in the “Information about our Executive Officers” section following Item 4 of this report.
The remaining information required by this Item 10 for HEI is incorporated herein by reference to the following sections in HEI’s 2025 Proxy Statement:
•“Director Nominees for Election”
•“Continuing Directors”
•“Committees of the Board” (portions regarding whether HEI has an audit & risk committee and identifying its members; no other portion of the Committees of the Board section is incorporated herein by reference)
•“Audit & Risk Committee Report” (portion identifying audit & risk committee financial experts who serve on the HEI Audit & Risk Committee only; no other portion of the Audit & Risk Committee Report is incorporated herein by reference)
Family relationships; director arrangements
There are no family relationships between any HEI director or director nominee and any other HEI director or director nominee or any HEI executive officer. There are no arrangements or understandings between any HEI director or director nominee and any other person pursuant to which such director or director nominee was selected. Information required to be reported under this caption is incorporated herein by reference to the “Other relationships and related person transactions” section in HEI’s 2025 Proxy Statement.
Delinquent Section 16(a) reports
Information required to be reported under this caption is incorporated herein by reference to the “Delinquent Section 16(a) Reports” section in HEI’s 2025 Proxy Statement.
Code of Conduct
HEI has a Corporate Code of Conduct that includes a code of ethics applicable to, among others, its principal executive officer, principal financial officer and principal accounting officer. The Corporate Code of Conduct is available on HEI’s website at www.hei.com. HEI intends to disclose the information required by Form 8-K, Item 5.05, “Amendments to the Registrant’s Code of Ethics, or Waiver of a Provision of the Code of Ethics,” through this website and such information will remain available on this website for at least a 12-month period.
Insider Trading Arrangements and Policies
Information required to be reported under this caption is incorporated herein by reference to the “Insider Trading Policies and Procedures” section in HEI’s 2025 Proxy Statement. A copy of the insider trading policy is filed as an exhibit to this Form 10-K.
Hawaiian Electric:
The information required by this Item 10 for Hawaiian Electric is incorporated herein by reference to pages 1 to 6 of Hawaiian Electric Exhibit 99.1.
Insider Trading Arrangements and Policies
Information required to be reported under this caption is incorporated herein by reference to the “Insider Trading Policies and Procedures” section in Hawaiian Electric Exhibit 99.1. A copy of the insider trading policy is filed as an exhibit to this Form 10-K.

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ITEM 11. EXECUTIVE COMPENSATION
ITEM 11. EXECUTIVE COMPENSATION
HEI:
The information required by this Item 11 for HEI is incorporated herein by reference to the information relating to executive and director compensation in HEI’s 2025 Proxy Statement.
Hawaiian Electric:
The information required by this Item 11 for Hawaiian Electric is incorporated herein by reference to:
•Pages 7 to 34 of Hawaiian Electric Exhibit 99.1 to this Form 10-K;
•The discussion of “2023-25 Long-Term Incentive Plan” at pages 18 to 19 of Hawaiian Electric’s Exhibit 99.1 to Annual Report on Form 10-K for the year ended December 31, 2023; and
•Information concerning compensation paid to directors of Hawaiian Electric who are also directors of HEI under the section of HEI’s 2025 Proxy Statement entitled, “Director Compensation.”
COMPENSATION & HUMAN CAPITAL MANAGEMENT COMMITTEE INTERLOCKS AND INSIDER PARTICIPATION
HEI:
The information required to be reported under this caption for HEI is incorporated herein by reference to the “Compensation & Human Capital Management Interlocks and Insider Participation” section in HEI’s 2025 Proxy Statement.
Hawaiian Electric:
The information required to be reported under this caption for Hawaiian Electric is incorporated herein by reference to the “Compensation & Human Capital Management Interlocks and Insider Participation” section of Hawaiian Electric Exhibit 99.1.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER MATTERS
HEI:
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
The information required by this Item 12 for HEI is incorporated herein by reference to the “Stock Ownership Information-Security Ownership of Certain Beneficial Owners” section in HEI’s 2025 Proxy Statement.
Equity Compensation Plan Information
Information as of December 31, 2024 about HEI Common Stock that may be issued under all of the Company’s equity compensation plans was as follows:
Plan category (a)
Number of
securities
to be issued upon
exercise of
outstanding
options, warrants
and rights (1) (b)
Weighted-average
exercise price of
outstanding
options,
warrants and
rights (c)
Number of securities
remaining available for
future issuance
under equity
compensation plans
(excluding securities
reflected in column (a)) (2)
Equity compensation plans approved by shareholders 710,655 $ - 1,962,537
Equity compensation plans not approved by shareholders
- - -
Total 710,655 $ - 1,962,537
(1)All outstanding EIP awards held by ASB participants were forfeited effective as of December 31, 2024, in connection with the Company’s sale of its controlling interest in ASB. This column includes the number of shares of HEI Common Stock which may be issued under the HEI 2010 Equity and Incentive Plan, as amended and restated effective February 9, 2024 (EIP) on account of awards outstanding as of December 31, 2024, including:
EIP
46,407 Restricted stock units plus estimated compounded dividend equivalents (if applicable)*
664,248 Shares to be issued in February 2025, 2026 and 2027 under the 2022-24, 2023-25 and 2024-26 LTIPs, respectively, plus compounded dividend equivalents**
710,655
* Under the EIP as of December 31, 2024, RSUs count as one share against shares available for issuance less estimated shares withheld for taxes under net share settlement, which again become available for the issuance of new shares on a one-to-one basis.
** For shares to be issued in February 2026 and 2027 under the 2023-25 and 2024-26 LTIPs, respectively, the number of shares to be issued assumes that applicable performance goals are achieved and shares are issued at maximum levels, reduced by the estimated number of shares withheld for taxes.
(2)This represents the number of shares available as of December 31, 2024 for future awards, including 1,794,360 shares available for future awards under the EIP and 168,177 shares available for future awards under the 2011 Nonemployee Director Plan.
Hawaiian Electric:
The information required by this Item 12 for Hawaiian Electric is incorporated herein by reference to the “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters” section of Hawaiian Electric Exhibit 99.1.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
HEI:
The information required by this Item 13 for HEI is incorporated herein by reference to the sections relating to related person transactions and director independence in HEI’s 2025 Proxy Statement.
Hawaiian Electric:
The information required by this Item 13 for Hawaiian Electric is incorporated herein by reference to the “Certain Relationships and Related Transactions, and Director Independence” section of Hawaiian Electric Exhibit 99.1.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
HEI:
The information required by this Item 14 for HEI is incorporated herein by reference to the relevant information in the Audit & Risk Committee Report in HEI’s 2025 Proxy Statement (but no other part of the “Audit & Risk Committee Report” is incorporated herein by reference).
Hawaiian Electric:
The information required by this Item 14 for Hawaiian Electric is incorporated herein by reference to “Principal Accounting Fees and Services” section of Hawaiian Electric Exhibit 99.1.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a)(1) Financial statements
See Item 8 for the Consolidated Financial Statements of HEI and Hawaiian Electric.
(a)(2) and (c) Financial statement schedules
The following financial statement schedules for HEI and Hawaiian Electric are included in this report on the pages indicated below:
Page/s in Form 10-K
HEI Hawaiian Electric
Schedule I Condensed Financial Information of Registrant, Hawaiian Electric Industries, Inc. (Parent Company) at December 31, 2024 and 2023 and for the years ended December 31, 2024, 2023 and 2022
162-164
NA
Schedule II Valuation and Qualifying Accounts, Hawaiian Electric Industries, Inc. and subsidiaries and Hawaiian Electric Company, Inc. and subsidiaries for the years ended December 31, 2024, 2023 and 2022
NA Not applicable.
Certain schedules, other than those listed, are omitted because they are not required, or are not applicable, or the required information is shown in the Consolidated Financial Statements.