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Electric utility segment
 9 Months Ended
Sep. 30, 2021
Electric Utility Subsidiary [Abstract]  
Electric utility segment Electric utility segment
Unconsolidated variable interest entities.
Power purchase agreements.  As of September 30, 2021, the Utilities had five PPAs for firm capacity (including the Puna Geothermal Venture (PGV) PPA that went offline in May 2018 due to lava flow on Hawaii Island, but returned to service with firm capacity of 13 MW in the first quarter of 2021 and ramped up to 23.9 MW in the second quarter of 2021) and other PPAs with independent power producers (IPPs) and Schedule Q providers (i.e., customers with cogeneration and/or power production facilities who buy power from or sell power to the Utilities), none of which are currently required to be consolidated as VIEs.
Pursuant to the current accounting standards for VIEs, the Utilities are deemed to have a variable interest in Kalaeloa Partners, L.P. (Kalaeloa), AES Hawaii, Inc. (AES Hawaii) and Hamakua Energy by reason of the provisions of the PPA that the Utilities have with the three IPPs. However, management has concluded that the Utilities are not the primary beneficiary of Kalaeloa, AES Hawaii and Hamakua Energy because the Utilities do not have the power to direct the activities that most significantly impact the three IPPs’ economic performance nor the obligation to absorb their expected losses, if any, that could potentially be significant to the IPPs. Thus, the Utilities have not consolidated Kalaeloa, AES Hawaii and Hamakua Energy in its condensed consolidated financial statements. Hamakua Energy is an indirect subsidiary of Pacific Current and is consolidated in HEI’s condensed consolidated financial statements.
For the other PPAs with IPPs, the Utilities have concluded that the consolidation of the IPPs was not required because either the Utilities do not have variable interests in the IPPs due to the absence of an obligation in the PPAs for the Utilities to absorb any variability of the IPPs, or the IPP was considered a “governmental organization,” and thus excluded from the scope of accounting standards for VIEs. The consolidation of any significant IPP could have a material effect on the unaudited condensed consolidated financial statements, including the recognition of a significant amount of assets and liabilities and, if such a consolidated IPP were operating at a loss and had insufficient equity, the potential recognition of such losses. If the Utilities determine they are required to consolidate the financial statements of such an IPP and the consolidation has a material effect, the Utilities would retrospectively apply accounting standards for VIEs to the IPP.
Commitments and contingencies.
Contingencies. The Utilities are subject in the normal course of business to pending and threatened legal proceedings. Management does not anticipate that the aggregate ultimate liability arising out of these pending or threatened legal proceedings will be material to its financial position. However, the Utilities cannot rule out the possibility that such outcomes could have a material effect on the results of operations or liquidity for a particular reporting period in the future.
Power purchase agreements.  Purchases from all IPPs were as follows:
 Three months ended September 30Nine months ended September 30
(in millions)2021202020212020
Kalaeloa$56 $39 $142 $111 
AES Hawaii32 33 98 96 
HPOWER20 18 51 52 
Hamakua Energy15 12 38 36 
Puna Geothermal Venture9 — 20 — 
Wind IPPs38 30 95 83 
Solar IPPs12 17 40 45 
Other IPPs 1
4 — 7 3 
Total IPPs$186 $149 $491 $426 
1Includes hydro power and other PPAs
Kalaeloa Partners, L.P.  Under a 1988 PPA, as amended, Hawaiian Electric is committed to purchase 208 MW of firm capacity from Kalaeloa. Hawaiian Electric and Kalaeloa had been negotiating an extension to the PPA, and the PPA had automatically extended on a month-to-month basis as long as the parties were still negotiating in good faith. In October 2021, Hawaiian Electric and Kalaeloa signed the Amended and Restated Power Purchase Agreement for Firm Dispatchable Capacity and Energy (Amended and Restated PPA) to extend the PPA for an additional term of 10 years. Hawaiian Electric will be submitting an application for approval of the Amended and Restated PPA to the PUC.
AES Hawaii, Inc. Under a PPA entered into in March 1988, as amended (through Amendment No. 2) for a period of 30 years ending September 2022, Hawaiian Electric agreed to purchase 180 MW of firm capacity from AES Hawaii. Hawaiian
Electric and AES Hawaii have been in dispute over an additional 9 MW of capacity. In February 2018, Hawaiian Electric reached agreement with AES Hawaii on an amendment to the PPA. However, in June 2018, the PUC issued an order suspending review of the amendment pending a Department of Health of the State of Hawaii (DOH) decision on AES Hawaii’s request for approval of its Emission Reduction Plan and partnership with Hawaiian Electric. If approved by the PUC, the amendment will resolve AES Hawaii’s claims related to the additional capacity. Hawaiian Electric does not intend to extend the term of the PPA which will expire on September 1, 2022.
Hu Honua Bioenergy, LLC (Hu Honua). In May 2012, Hawaii Electric Light signed a PPA, which the PUC approved in December 2013, with Hu Honua for 21.5 MW of renewable, dispatchable firm capacity fueled by locally grown biomass from a facility on the island of Hawaii. Under the terms of the PPA, the Hu Honua plant was scheduled to be in service in 2016. However, Hu Honua encountered construction and litigation delays, which resulted in an amended and restated PPA between Hawaii Electric Light and Hu Honua dated May 9, 2017. In July 2017, the PUC approved the amended and restated PPA, which becomes effective once the PUC’s order is final and non-appealable. In August 2017, the PUC’s approval was appealed by a third party. On May 10, 2019, the Hawaii Supreme Court issued a decision remanding the matter to the PUC for further proceedings consistent with the court’s decision which must include express consideration of greenhouse gas (GHG) emissions that would result from approving the PPA, whether the cost of energy under the PPA is reasonable in light of the potential for GHG emissions, and whether the terms of the PPA are prudent and in the public interest, in light of its potential hidden and long-term consequences. As a result, the PUC reopened the docket for further proceedings, including re-examining all of the issues in the proceedings. On July 9, 2020, the PUC issued an order denying Hawaii Electric Light’s request to waive the amended and restated PPA from the PUC’s competitive bidding requirements and therefore, dismissed the request for approval of the amended and restated PPA without prejudice to possible participation in any future competitive bidding process. On September 9, 2020, the PUC denied Hu Honua’s motion for reconsideration of the PUC’s order. Hu Honua filed its notice of appeal to the Hawaii Supreme Court of the PUC’s order denying Hu Honua’s motion for reconsideration. On May 24, 2021, the Hawaii Supreme Court vacated the PUC’s decision and remanded the matter back to the PUC for further proceedings. On June 30, 2021, the PUC issued an order reopening the docket consistent with the Hawaii Supreme Court’s order. A contested case hearing has been scheduled for January 2022.
Molokai New Energy Partners (MNEP). In July 2018, the PUC approved Maui Electric’s PPA with MNEP to purchase solar energy from a photovoltaic (PV) plus battery storage project. The 4.88 MW PV and 3 MW Battery Energy Storage System project was to deliver no more than 2.64 MW at any time to the Molokai system. On March 25, 2020, MNEP filed a complaint in the United Stated District Court for the District of Hawaii against Maui Electric claiming breach of contract. On June 3, 2020, Maui Electric provided Notice of Default and Termination of the PPA to MNEP terminating the PPA with an effective date of July 10, 2020. Thereafter, MNEP filed an amended Complaint to include claims relating to the termination and Hawaiian Electric filed its Answer to the Amended Complaint on September 11, 2020, disputing the facts presented by MNEP and all claims within the original and amended complaint. Currently, the discovery phase is ongoing.
Utility projects.  Many public utility projects require PUC approval and various permits from other governmental agencies. Difficulties in obtaining, or the inability to obtain, the necessary approvals or permits or community support can result in significantly increased project costs or even cancellation of projects. In the event a project does not proceed, or if it becomes probable the PUC will disallow cost recovery for all or part of a project, or if PUC-imposed caps on project costs are expected to be exceeded, project costs may need to be written off in amounts that could result in significant reductions in Hawaiian Electric’s consolidated net income.
Enterprise Resource Planning/Enterprise Asset Management (ERP/EAM) implementation project. The ERP/EAM Implementation Project went live in October 2018. Hawaii Electric Light and Hawaiian Electric began to incorporate their portion of the deferred project costs in rate base and started the amortization over a 12-year period in January 2020 and November 2020, respectively. The PUC required the benefit savings of the project to be passed on to customers.
In February 2019, the PUC approved a methodology for passing the future cost saving benefits of the new ERP/EAM system to customers developed by the Utilities in collaboration with the Consumer Advocate. The Utilities filed a benefits clarification document on June 10, 2019, reflecting $150 million in future net O&M expense reductions and cost avoidance, and $96 million in capital cost reductions and tax savings over the 12-year service life. To the extent the reduction in O&M expense relates to amounts reflected in electric rates, the Utilities would reduce future rates for such amounts. In October 2019, the PUC approved the Utilities and the Consumer Advocate’s Stipulated Performance Metrics and Tracking Mechanism. As of September 30, 2021, the Utilities’ regulatory liability was $9.9 million ($5.8 million for Hawaiian Electric, $1.6 million for Hawaii Electric Light and $2.5 million for Maui Electric) for the O&M expense savings that are being amortized or to be included in future rates. As part of the settlement agreement approved in the Hawaiian Electric 2020 test year rate case, the regulatory liability for Hawaiian Electric will be amortized over five years, beginning in November 2020, and the O&M benefits for Hawaiian Electric was considered flowed through to customers. As part of the PBR proceeding, the regulatory
liability as of December 31, 2020 of approximately $1.6 million and $2.3 million, respectively, for Hawaii Electric Light and Maui Electric was flowed to customers as part of the customer dividend in the annual revenue adjustment in 2021.
On July 7, 2021, the PUC issued an order modifying the reporting frequency of the Semi-Annual Enterprise System Benefits (SAESB) reports to an Annual Enterprise System Benefits (AESB) report on the achieved benefits savings. The most recent SAESB report was filed on February 26, 2021 for the period July 1 through December 31, 2020.
Environmental regulation.  The Utilities are subject to environmental laws and regulations that regulate the operation of existing facilities, the construction and operation of new facilities and the proper cleanup and disposal of hazardous waste and toxic substances.
Hawaiian Electric, Hawaii Electric Light and Maui Electric, like other utilities, periodically encounter petroleum or other chemical releases associated with current or previous operations. The Utilities report and take action on these releases when and as required by applicable law and regulations. The Utilities believe the costs of responding to such releases identified to date will not have a material effect, individually or in the aggregate, on Hawaiian Electric’s consolidated results of operations, financial condition or liquidity.
Former Molokai Electric Company generation site.  In 1989, Maui Electric acquired Molokai Electric Company. Molokai Electric Company had sold its former generation site (Site) in 1983, but continued to operate at the Site under a lease until 1985. The federal Environmental Protection Agency (EPA) has since identified environmental impacts in the subsurface soil at the Site. In cooperation with the DOH and EPA, Maui Electric further investigated the Site and the Adjacent Parcel to determine the extent of impacts of polychlorinated biphenyls (PCBs), residual fuel oils and other subsurface contaminants. Maui Electric has a reserve balance of $2.7 million as of September 30, 2021, representing the probable and reasonably estimable undiscounted cost for remediation of the Site and the Adjacent Parcel; however, final costs of remediation will depend on the cleanup approach implemented.
Pearl Harbor sediment study. In July 2014, the U.S. Navy notified Hawaiian Electric of the Navy’s determination that Hawaiian Electric is a Potentially Responsible Party responsible for the costs of investigation and cleanup of PCB contamination in sediment in the area offshore of the Waiau Power Plant as part of the Pearl Harbor Superfund Site. Hawaiian Electric was also required by the EPA to assess potential sources and extent of PCB contamination onshore at Waiau Power Plant.
As of September 30, 2021, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $10.4 million. The reserve balance represents the probable and reasonably estimable undiscounted cost for the onshore and offshore investigation and remediation. The final remediation costs will depend on the actual onshore and offshore cleanup costs.
Regulatory proceedings
Decoupling. Decoupling is a regulatory model that is intended to provide the Utilities with financial stability and facilitate meeting the State of Hawaii’s goals to transition to a clean energy economy and achieve an aggressive renewable portfolio standard. Prior to the implementation of the performance-based regulation framework (PBR Framework), the decoupling mechanism had the following major components: (1) monthly revenue balancing account (RBA) revenues or refunds for the difference between PUC-approved target revenues and recorded adjusted revenues, which delinks revenues from kWh sales, (2) rate adjustment mechanism (RAM) revenues for escalation in certain O&M expenses and rate base changes, (3) major project interim recovery (MPIR) adjustment mechanism, (4) performance incentive mechanisms (PIMs), and (5) an earnings sharing mechanism (ESM), which would provide for a reduction of revenues between rate cases in the event the utility exceeds the authorized rate-making return on average common equity (ROACE) allowed in its most recent rate case.
Performance-based regulation framework. On December 23, 2020, the PUC issued a D&O (PBR D&O) approving the new PBR Framework. Under the PBR Framework, the Utilities’ decoupling will continue to be used with modifications, as described below. The existing cost recovery mechanisms will continue as currently implemented (e.g., the Energy Cost Recovery Clause (ECRC), Purchased Power Adjustment Clause (PPAC), Demand Side Management surcharge (DSM), Renewable Energy Infrastructure Program (REIP), Demand Response Adjustment Clause (DRAC), Pension and Other Post-Employment Benefits (OPEB) tracking mechanisms). In addition to annual revenues provided by the annual revenue adjustment (ARA), the Utilities may seek relief for extraordinary projects or programs through the Exceptional Project Recovery Mechanism (EPRM) (formerly known as the MPIR adjustment mechanism) and earn financial rewards for exemplary performance as provided through a portfolio of PIMs and Shared Savings Mechanisms (SSMs). The PBR Framework will incorporate a variety of other performance mechanisms, including Scorecards, Reported Metrics, and an expedited Pilot Process. The PBR Framework also contains a number of safeguards, including a symmetric ESM which protects the Utilities and customers from excessive earnings or losses, as measured by the Utilities’ achieved rate-making ROACE and a Re-Opener
mechanism, under which the PUC will open an examination, at its discretion, to determine if adjustments or modifications to specific PBR mechanisms are appropriate. The new PBR Framework became fully effective on June 1, 2021.
On September 17, 2021, the PUC issued an order including a proposed new set of potential PIMs to address these areas of PUC concern:
•Grid reliability,
•Timely retirement of fossil fuel generation units,
•Interconnection of large-scale renewable energy projects,
•Cost control for fossil fuel, purchased power, and other non-ARA costs, and
•Expedient utilization of grid services from demand-side resources
The order established a procedural schedule by which a PBR Working Group (consisting of parties from the docket in which the new PBR Framework was established) will comment upon and evaluate the potential new PIMs and potentially propose alternatives. The schedule included procedural steps for technical conferences, statements of position filings and an evidentiary hearing. The PUC has not stated when any new PIMs might become effective. On November 2, 2021, the PUC suspended the previous procedural schedule, pending review of schedule modifications.
Rate adjustment mechanism. The RAM is based on the lesser of: a) an inflationary adjustment for certain O&M expenses and return on investment for certain rate base changes, or b) cumulative annual compounded increase in Gross Domestic Product Price Index applied to annualized target revenues (the RAM Cap). All Utilities were limited to the RAM Cap in 2020. Under the PBR Framework, the ARA mechanism replaced the RAM, and became effective on June 1, 2021. The transition to the ARA includes the continuation of the 2020 RAM revenue adjustment.
Annual revenue adjustment mechanism. The PBR Framework established a five-year multi-year rate period during which there will be no general rate cases. Target revenues will be adjusted according to an index-driven ARA based on (i) an inflation factor, (ii) a predetermined X-factor to encompass productivity, which is set at zero, (iii) a Z-factor to account for exceptional circumstances not in the Utilities’ control and (iv) a customer dividend consisting of a negative adjustment of 0.22% compounded annually and a flow through of the “pre-PBR” savings commitment from the management audit recommendations developed in a prior docket.
As a result of an Order issued by the PUC pursuant to a motion for partial reconsideration the customer dividend for “pre-PBR” savings commitment portion to be delivered to customers will be at a rate of $6.6 million per year from 2021 to 2025, and the Enterprise Resource Planning system benefits savings of $3.9 million, to be delivered to customers in 2021. The implementation of the ARA occurred on June 1, 2021.
Earnings sharing mechanism. A symmetrical ESM for achieved rate-making ROACE outside of a 300 basis points dead band above or below the current authorized ROACE of 9.5% for each of the Utilities. There is a 50/50 sharing between customers and Utilities for the achieved rate-making ROACE falling within 150 basis points outside of the dead band in either direction, and a 90/10 sharing for any further difference. A reopening or review of the PBR terms will be triggered if the Utilities credit rating outlook indicates a potential credit downgrade below investment grade status, or if its achieved rate-making ROACE enters the outer most tier of the ESM.
Major project interim recovery. On April 27, 2017, the PUC issued an order that provided guidelines for interim recovery of revenues to support major projects placed in service between general rate cases.
Projects eligible for recovery through the MPIR adjustment mechanism are major projects (i.e., projects with capital expenditures net of customer contributions in excess of $2.5 million), including, but not restricted to, renewable energy, energy efficiency, utility scale generation, grid modernization and smaller qualifying projects grouped into programs for review. The MPIR adjustment mechanism provides the opportunity to recover revenues for approved costs of eligible projects placed in service between general rate cases wherein cost recovery is limited by a revenue cap and is not provided by other effective recovery mechanisms. The request for PUC approval must include a business case, and all costs that are allowed to be recovered through the MPIR adjustment mechanism must be offset by any related benefits. The guidelines provide for accrual of revenues approved for recovery upon in-service date to be collected from customers through the annual RBA tariff. Capital projects that are not recovered through the MPIR would be included in the RAM and be subject to the RAM Cap, until the next rate case when the Utilities would request recovery in base rates.
On May 26, 2021, the PUC approved 2021 MPIR amounts totaling $21.8 million, including revenue taxes, for the Schofield Generating Station ($17.6 million), West Loch PV Project ($3.3 million), and Grid Modernization Strategy (GMS) Phase 1 project ($0.9 million for all three utilities) for the accrual of revenues effective January 1, 2021, that included the 2021
return on project amount (based on approved amounts) in rate base, depreciation and incremental O&M expenses. Under the PBR framework, the Utilities began recovery of the annualized 2021 MPIR amounts effective June 1, 2021 through the RBA rate adjustment.
On September 27, 2021, the PUC issued an order rejecting the Utilities’ August 31, 2021 request to update target revenues resulting from the GMS Phase 1 Meter Data Management System (MDMS) deferred software go‑live and completion of implementation through July 2021, as it inappropriately relied on an automatic approval provision in Hawaii Administrative Rules. The PUC did not rule on the merits of the Utilities’ request and offered the Utilities to file an amended request as soon as practicable. On October 7, 2021, the Utilities filed an amended request, requesting PUC approval of RBA tariff sheets reflecting the change to target revenues associated with the GMS Phase 1 MDMS deferred software go-live and completion of implementation through July 2021.
Exceptional project recovery mechanism. Under the PBR Framework, the existing MPIR adjustment mechanism was renamed EPRM to include deferred and O&M expense projects and to permit the Utilities to include the full amount of approved costs in the EPRM for recovery in the first year the project goes into service, pro-rated for the portion of the year the project is in service. Any pending application for MPIR relief submitted by the Utilities prior to the PBR D&O will be grandfathered under the MPIR Guidelines. The Utilities may alternatively request that pending MPIR applications be reviewed under EPRM Guidelines. EPRM recovery will be in accordance with the EPRM Guidelines limited to the lesser of actual incurred project costs or PUC-approved amounts, net of savings. Currently, the Utilities are seeking EPRM recovery of eight projects with total project costs of $324 million, subject to PUC approval.
Pilot process. The PBR D&O approved a Pilot Process to foster innovation by establishing an expedited implementation process for pilots that test new technologies, programs, business models, and other arrangements. This is intended to support initiatives by the Utilities to test new programs and ideas quickly and elevate any successful pilots for consideration of full-scale implementation. The proposed pilots would be subject to PUC approval with a total annual cap of $10 million. The Pilot Process will feature the two primary activities: an initial “Workplan Development” phase, during which the Utilities identify and scope areas of interests, so as to inform the subsequent “Implementation” phase, during which the Utilities submit specific pilot proposals for expedited review by the PUC and implement the pilot upon approval. The PUC will issue an order, approving, denying, or modifying a proposed Pilot within 45 days of receiving notice of a specific pilot project.
On July 9, 2021, the PUC issued an order approving the Utilities’ proposed Pilot Process submitted in April 2021 with modifications, including a cost recovery process that generally allows the Utilities to defer and recover total annual expenditures of approved pilot projects in full over twelve months beginning June 1 of the year following implementation through the RBA rate adjustment, although the Utilities may determine on a case-by-case basis that a particular project’s deferred costs should be amortized over a period greater than twelve months. On July 28, 2021, the Utilities submitted the finalized Pilot Process to govern the review of the pilot project proposals in accordance with the July 9, 2021 order.
Performance incentive mechanisms. The PUC has established the following PIMs: (1) Service Quality performance incentives, (2) Phase 1 Request for proposal (RFP) PIM for procurement of low-cost renewable energy, (3) Phase 2 RFP PIMs for generation and generation plus storage project, and Grid Services and standalone storage.
•Service Quality performance incentives (ongoing). Service Quality performance incentives are measured on a calendar-year basis. The PIM tariff requires the performance targets, deadbands and the amount of maximum financial incentives used to determine the PIM financial incentive levels for each of the PIMs shall remain constant in interim periods, unless otherwise amended by order of the PUC.
•Service Reliability Performance measured by System Average Interruption Duration and Frequency Indexes (penalties only). Target performance is based on each utility’s historical 10-year average performance with a deadband of one standard deviation. The maximum penalty for each performance index is 20 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties of approximately $6.8 million - for both indices in total for the three utilities).
•Call Center Performance measured by the percentage of calls answered within 30 seconds. Target performance is based on the annual average performance for each utility for the most recent 8 quarters with a deadband of 3% above and below the target. The maximum penalty or reward is 8 basis points applied to the common equity share of each respective utility’s approved rate base (or maximum penalties or rewards of approximately $1.4 million - in total for the three utilities).
In December 2020, the Utilities accrued $0.9 million in estimated rewards for call center performance, net of service reliability penalties, for 2020. The net service quality performance rewards related to 2020 was reflected in the 2021
annual decoupling filing which was approved by the PUC on May 26, 2021, resulting in an increase to customer rates effective June 1, 2021.
•Phase 1 RFP PIM. Procurement of low-cost variable renewable resources through the RFP process in 2018 is measured by comparison of the procurement price to target prices. Half of the incentive was earned upon PUC approval of the PPAs. Based on the seven PPAs approved in 2019, the Utilities recognized $1.7 million in 2019 with the remaining award to be recognized in the year following the in-service date of the projects, which is estimated to occur from 2023 to 2024.
•Phase 2 RFP PIMs. The PUC order issued on October 9, 2019 establishes pricing thresholds, timelines to complete contracting, and other performance criteria for the performance incentive eligibility. The PIMs provide incentives only without penalties. The order requires contracts under the Grid Service RFP be filed for approval by May 2020 (subsequently extended to July 9, 2020), and by September 2020 under the Renewable RFPs, with a declining PIM for projects that are not filed by these deadlines. On July 9, 2020, the Utilities filed two Grid Service Purchase Agreements for the Grid Service RFP that potentially qualify for a demand response PIM, however, details of the incentive metrics will be determined by the PUC. On September 15, 2020, the Utilities filed eight power purchase agreements for the Phase 2 RFP. Of those eight, only one project qualified for a potential PIM incentive. On February 16, 2021, the Utilities filed one additional power purchase agreement that qualifies for the declining PIM, which was approved on September 15, 2021. The first allocation of incentives is earned upon PUC approval of the contact and the remaining PIM allocations begin after the project achieves commercial operations and are earned based on delivered energy for the prior year, through 2025. The Utilities accrued $0.1 million in incentives in September 2021. On December 31, 2020, the PUC approved the two Grid Services Purchase Agreements without further clarification regarding the demand response PIM. The Utility filed a letter in January 2021 with the PUC seeking guidance on the next steps to define the demand response incentive metric details.
•The PUC established the following two new PIMs in its PBR D&O, which were approved in an order issued on March 23, 2021 and became effective on June 1, 2021.
•Renewable portfolio standard (RPS)-A PIM that provides a financial reward for accelerating the achievement of RPS goals. The Utilities may earn a reward for the amount of system generation above the interpolated statutory RPS goal at $20/MWh in 2021 and 2022, $15/MWh in 2023, and $10/MWh for the remainder of the multi-year rate period (MRP). Penalties are already prescribed in the RPS as $20/MWh for failing to meet RPS targets in 2030, 2040 and 2045. The evaluation period commenced on January 1, 2021.
•Grid Services Procurement PIM that provides financial rewards for grid services acquired in 2021 and 2022. The Utilities can earn a total maximum reward of $1.5 million over 2021 and 2022. The evaluation period commenced on January 1, 2021.
•The PUC also established the following three new PIMs in its PBR D&O, which were approved by the PUC on May 17, 2021 and became effective on June 1, 2021.
•Interconnection Approval PIM that provides financial rewards and penalties for interconnection times for distributed energy resources systems <100 kW in size. The Utilities can earn a total annual maximum reward of $3.0 million or a total annual maximum penalty of $0.9 million. The evaluation period commenced on January 1, 2021.
•Low-to-Moderate Income (LMI) Energy Efficiency PIM that provides financial reward for collaboration between the Utilities and the third-party Public Benefits Fee Administrator to deliver energy savings for low- and moderate-income customers. The Utilities can earn a total annual maximum reward of $2.0 million. The PIM will initially have a duration of three years and be subject to an annual review. The evaluation period is based on Hawaii Energy’s program year with the initial evaluation year being the period of July 1, 2021 through June 30, 2022.
•Advanced Metering Infrastructure Utilization PIM that provides financial rewards for leveraging grid modernization investments and engaging customers beyond what is already planned in the Phase 1 Grid Modernization program. The Utilities can earn a total annual maximum reward of $2.0 million. The PIM will initially have a duration of three years after which it will be re-evaluated. The evaluation period commenced on January 1, 2021.
Annual review cycle. PBR D&O established an annual review cycle for revenue adjustments under the PBR Framework, including the biannual submission of the revenue reports. The Utilities filed the fall revenue report on October 29,
2021, which is subject to PUC approval. The filing reflected ARA revenues for 2022 to be collected from January 1 through December 31, 2022, as follows:
(in millions)Hawaiian ElectricHawaii Electric LightMaui ElectricTotal
2022 ARA revenues$19.8 $4.9 $4.8 $29.5 
Management Audit savings commitment(4.6)(1.0)(1.0)(6.6)
Net 2022 ARA revenues$15.2 $3.9 $3.8 $22.9 

The proposed net incremental amounts between the 2021 spring and fall revenue reports are as follows. The amounts are to be collected (refunded) from January 1 through December 31, 2022 under the RBA rate tariffs, which was proposed in the 2021 fall revenue report filing and is subject to PUC approval.
(in millions)Hawaiian ElectricHawaii Electric LightMaui ElectricTotal
Incremental RAM revenues and ARA revenues$41.7 $8.9 $10.9 $61.5 
Incremental accrued RBA balance through September 30, 2021 (and associated revenue taxes)21.9 2.5 (0.1)24.3 
Incremental Performance Incentive Mechanisms (net)
— — 0.1 0.1 
Incremental MPIR/EPRM Revenue Adjustment9.8 0.3 0.3 10.4
Net incremental amount to be collected under the RBA rate tariffs$73.4 $11.7 $11.1 $96.2 
Note: Columns may not foot due to rounding.
Most recent rate proceedings.
Hawaiian Electric 2020 test year rate case. On October 22, 2020, the PUC issued a final D&O approving the stipulated settlement agreement filed in the proceeding. As a result, there will be no increase in base electric rates established in the 2017 test year rate case. In the final D&O, the PUC approved the capital structure that consists of a 58% total equity ratio, and an authorized ROACE of 9.5% for the 2020 test year. The resulting return on rate base (RORB) is 7.37%. The D&O approved the agreement to implement the overall lower depreciation rates approved in the last depreciation study proceeding, effective January 1, 2020. See “Annual revenue adjustment mechanism” under “Performance-based regulation framework” above, regarding the PUC’s decision on the treatment of Hawaiian Electric’s Management Audit savings commitment. Hawaiian Electric’s proposed RBA provision tariff and ECRC tariff submitted on November 6, 2020 were approved by the PUC on December 11, 2020 and took effect on January 1, 2021.
Hawaii Electric Light 2019 test year rate case. On July 28, 2020, the PUC issued a final D&O, approving the Stipulated Partial Settlement Letter in part and ordering final rates for the 2019 test year to remain at current effective rates such that there is a zero increase in rates. The PUC determined that an appropriate authorized ROACE for the 2019 test year is 9.5%, approved a capital structure of 58% total equity and approved as fair a 7.52% RORB. In addition, the order, among others, (1) approved a 10-year amortization period for the state investment tax credit; and (2) approved a modification to Hawaii Electric Light’s ECRC to incorporate a 98%/2% risk-sharing split between customers and Hawaii Electric Light with an annual maximum exposure cap of +/- $600,000. The proposed final tariffs and PIM tariffs took effect on November 1, 2020, and the ECRC tariff took effect on January 1, 2021.
Regulatory assets for COVID-19 related costs. On May 4, 2020, the PUC issued an order, authorizing all utilities, including the Utilities, to establish regulatory assets to record costs resulting from the suspension of disconnections of service during the pendency of the Governor’s Emergency Proclamation and until otherwise ordered by the PUC. In future proceedings, the PUC will consider the reasonableness of the costs, the appropriate period of recovery, any amount of carrying costs thereon, and any savings directly attributable to suspension of disconnects, and other related matters. As part of the order, the PUC prohibits the Utilities from charging late payment fees on past due payments. On June 30, 2020, the PUC issued an order approving the Utilities’ request made in April 2020 for deferral treatment of COVID-19 related costs through December 31, 2020. On October 1, 2021, the PUC approved the Utilities’ request to extend the deferral period to December 31, 2021. The Utilities are required to file quarterly reports to update the Utilities’ financial condition, report measures in place to assist their customers during the COVID-19 emergency situation, identify the planned deferred costs and details for the deferred costs, and identify funds received or benefits received that have resulted from the COVID-19 emergency period. The recovery of the regulatory assets would be determined in a subsequent proceeding and management believes the deferred costs are probable of recovery. In addition, starting in December 2020 and monthly moving forward until otherwise ordered by the PUC, the Utilities are required to file information on, among other things, number of customers, arrears balances, payment arrangements entered into, and available assistance used to assist customer bill payments. The monthly report is intended to assist the PUC in determining next
steps regarding appropriate regulatory measures. As of September 30, 2021, the Utilities recorded a total of $28.7 million in regulatory assets pursuant to the orders.
Collective bargaining agreement. As of September 30, 2021, approximately 47% of the Utilities’ employees are members of the International Brotherhood of Electrical Workers, AFL-CIO, Local 1260. The current collective bargaining agreement with the union that was set to expire on October 31, 2021 was extended to January 3, 2022. The Utilities continue to renegotiate the contract with the union.
Condensed consolidating financial information. Condensed consolidating financial information for Hawaiian Electric and its subsidiaries are presented for the three and nine month periods ended September 30, 2021 and 2020, and as of September 30, 2021 and December 31, 2020.
Hawaiian Electric unconditionally guarantees Hawaii Electric Light’s and Maui Electric’s obligations (a) to the State of Hawaii for the repayment of principal and interest on Special Purpose Revenue Bonds issued for the benefit of Hawaii Electric Light and Maui Electric, and (b) under their respective private placement note agreements and the Hawaii Electric Light notes and Maui Electric notes issued thereunder. Hawaiian Electric is also obligated, after the satisfaction of its obligations on its own preferred stock, to make dividend, redemption and liquidation payments on Hawaii Electric Light’s and Maui Electric’s preferred stock if the respective subsidiary is unable to make such payments.
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Three months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustments
Hawaiian Electric
Consolidated
Revenues$478,046 100,313 101,141 — (1)$679,499 
Expenses
Fuel oil126,909 21,104 32,669 — — 180,682 
Purchased power136,688 31,159 17,912 — — 185,759 
Other operation and maintenance75,191 19,964 21,313 — — 116,468 
Depreciation38,912 10,050 8,424 — — 57,386 
Taxes, other than income taxes45,239 9,333 9,440 — — 64,012 
   Total expenses422,939 91,610 89,758 — — 604,307 
Operating income55,107 8,703 11,383 — (1)75,192 
Allowance for equity funds used during construction1,999 131 297 — — 2,427 
Equity in earnings of subsidiaries12,028 — — — (12,028)— 
Retirement defined benefits expense—other than service costs741 166 (30)— — 877 
Interest expense and other charges, net(12,943)(2,590)(2,616)— 1 (18,148)
Allowance for borrowed funds used during construction676 44 107 — — 827 
Income before income taxes57,608 6,454 9,141 — (12,028)61,175 
Income taxes6,996 1,433 1,906 — — 10,335 
Net income50,612 5,021 7,235 — (12,028)50,840 
Preferred stock dividends of subsidiaries— 133 95 — — 228 
Net income attributable to Hawaiian Electric
50,612 4,888 7,140 — (12,028)50,612 
Preferred stock dividends of Hawaiian Electric270 — — — — 270 
Net income for common stock$50,342 4,888 7,140 — (12,028)$50,342 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Three months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net income for common stock$50,342 4,888 7,140 — (12,028)$50,342 
Other comprehensive income, net of taxes:      
Retirement benefit plans:      
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits2,905 393 393 — (786)2,905 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(2,799)(391)(393)— 784 (2,799)
Other comprehensive income, net of taxes106 2 — — (2)106 
Comprehensive income attributable to common shareholder
$50,448 4,890 7,140 — (12,030)$50,448 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Three months ended September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui Electric
Other subsidiaries
Consolidating adjustments
Hawaiian Electric
Consolidated
Revenues$398,877 82,172 81,629 — (110)$562,568 
Expenses
Fuel oil70,557 17,047 17,438 — — 105,042 
Purchased power116,249 17,665 15,111 — — 149,025 
Other operation and maintenance71,179 17,565 22,499 — — 111,243 
Depreciation37,853 9,760 8,076 — — 55,689 
Taxes, other than income taxes38,005 7,512 7,534 — — 53,051 
   Total expenses333,843 69,549 70,658 — — 474,050 
Operating income65,034 12,623 10,971 — (110)88,518 
Allowance for equity funds used during construction1,902 208 237 — — 2,347 
Equity in earnings of subsidiaries14,912 — — — (14,912)— 
Retirement defined benefits expense—other than service costs(591)194 (35)— — (432)
Interest expense and other charges, net(11,970)(2,519)(2,457)— 110 (16,836)
Allowance for borrowed funds used during construction659 65 77 — — 801 
Income before income taxes69,946 10,571 8,793 — (14,912)74,398 
Income taxes9,611 2,378 1,846 13,835 
Net income60,335 8,193 6,947 — (14,912)60,563 
Preferred stock dividends of subsidiaries— 133 95 — 228 
Net income attributable to Hawaiian Electric
60,335 8,060 6,852 — (14,912)60,335 
Preferred stock dividends of Hawaiian Electric270 — — — — 270 
Net income for common stock$60,065 8,060 6,852 — (14,912)$60,065 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Three months ended September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net income for common stock$60,065 8,060 6,852 — (14,912)$60,065 
Other comprehensive income (loss), net of taxes:      
Retirement benefit plans:      
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits5,769 885 770 — (1,655)5,769 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(5,721)(887)(767)— 1,654 (5,721)
Other comprehensive income (loss), net of taxes48 (2)3 — (1)48 
Comprehensive income attributable to common shareholder
$60,113 8,058 6,855 — (14,913)$60,113 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Nine months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric
Consolidated
Revenues$1,301,297 276,974 267,992 — (21)$1,846,242 
Expenses
Fuel oil306,982 57,175 83,088 — — 447,245 
Purchased power370,240 76,992 43,288 — — 490,520 
Other operation and maintenance230,429 57,350 61,401 — — 349,180 
Depreciation116,733 30,151 25,238 — — 172,122 
Taxes, other than income taxes124,167 25,865 25,153 — — 175,185 
   Total expenses1,148,551 247,533 238,168 — — 1,634,252 
Operating income152,746 29,441 29,824 — (21)211,990 
Allowance for equity funds used during construction5,677 403 915 — — 6,995 
Equity in earnings of subsidiaries35,282 — — — (35,282)— 
Retirement defined benefits expense—other than service costs2,511 503 (96)— — 2,918 
Interest expense and other charges, net(38,604)(7,744)(7,799)— 21 (54,126)
Allowance for borrowed funds used during construction1,921 136 329 — — 2,386 
Income before income taxes159,533 22,739 23,173 — (35,282)170,163 
Income taxes23,122 5,152 4,792 — — 33,066 
Net income136,411 17,587 18,381 — (35,282)137,097 
Preferred stock dividends of subsidiaries— 400 286 — — 686 
Net income attributable to Hawaiian Electric136,411 17,187 18,095 — (35,282)136,411 
Preferred stock dividends of Hawaiian Electric810 — — — — 810 
Net income for common stock$135,601 17,187 18,095 — (35,282)$135,601 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Nine months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric Consolidated
Net income for common stock$135,601 17,187 18,095 — (35,282)$135,601 
Other comprehensive income, net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of taxes14,596 2,062 1,915 — (3,977)14,596 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(14,421)(2,059)(1,915)— 3,974 (14,421)
Other comprehensive income, net of taxes175 3 — — (3)175 
Comprehensive income attributable to common shareholder$135,776 17,190 18,095 — (35,285)$135,776 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Income
Nine months ended September 30, 2020

(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric
Consolidated
Revenues$1,200,677 249,970 244,043 — (465)$1,694,225 
Expenses
Fuel oil268,382 55,733 66,599 — — 390,714 
Purchased power333,146 53,032 39,501 — — 425,679 
Other operation and maintenance231,090 54,250 63,491 — — 348,831 
Depreciation113,724 29,281 24,230 — — 167,235 
Taxes, other than income taxes115,179 23,324 22,986 — — 161,489 
   Total expenses1,061,521 215,620 216,807 — — 1,493,948 
Operating income139,156 34,350 27,236 — (465)200,277 
Allowance for equity funds used during construction5,452 520 584 — — 6,556 
Equity in earnings of subsidiaries37,492 — — — (37,492)— 
Retirement defined benefits expense—other than service costs(1,683)581 (93)— — (1,195)
Interest expense and other charges, net(36,471)(7,536)(7,226)— 465 (50,768)
Allowance for borrowed funds used during construction1,887 163 191 — — 2,241 
Income before income taxes145,833 28,078 20,692 — (37,492)157,111 
Income taxes18,724 6,372 4,220 — — 29,316 
Net income127,109 21,706 16,472 — (37,492)127,795 
Preferred stock dividends of subsidiaries— 400 286 — — 686 
Net income attributable to Hawaiian Electric127,109 21,306 16,186 — (37,492)127,109 
Preferred stock dividends of Hawaiian Electric810 — — — — 810 
Net income for common stock$126,299 21,306 16,186 — (37,492)$126,299 


Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Comprehensive Income
Nine months ended September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther subsidiariesConsolidating adjustmentsHawaiian Electric Consolidated
Net income for common stock$126,299 21,306 16,186 — (37,492)$126,299 
Other comprehensive income (loss), net of taxes:
Retirement benefit plans:
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits16,137 2,384 2,072 — (4,456)16,137 
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes(16,038)(2,382)(2,072)— 4,454 (16,038)
Other comprehensive income, net of taxes99 2 — — (2)99 
Comprehensive income attributable to common shareholder$126,398 21,308 16,186 — (37,494)$126,398 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsi-
diaries		Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Assets      
Property, plant and equipment
Utility property, plant and equipment      
Land$42,410 5,606 3,594 — — $51,610 
Plant and equipment5,063,487 1,375,782 1,230,451 — — 7,669,720 
Less accumulated depreciation(1,766,707)(619,003)(562,005)— — (2,947,715)
Construction in progress172,417 17,966 31,135 — — 221,518 
Utility property, plant and equipment, net3,511,607 780,351 703,175 — — 4,995,133 
Nonutility property, plant and equipment, less accumulated depreciation
5,303 115 1,532 — — 6,950 
Total property, plant and equipment, net3,516,910 780,466 704,707 — — 5,002,083 
Investment in wholly owned subsidiaries, at equity639,900 — — — (639,900)— 
Current assets      
Cash and cash equivalents25,981 3,788 6,621 77 — 36,467 
Restricted cash6,313 — — — — 6,313 
Advances to affiliates700 — — — (700)— 
Customer accounts receivable, net118,776 29,371 26,090 — — 174,237 
Accrued unbilled revenues, net93,949 17,660 17,470 — — 129,079 
Other accounts receivable, net20,732 3,843 3,616 — (22,075)6,116 
Fuel oil stock, at average cost71,072 13,079 16,650 — — 100,801 
Materials and supplies, at average cost43,094 10,107 19,796 — — 72,997 
Prepayments and other41,706 5,232 7,023 — — 53,961 
Regulatory assets47,004 2,966 6,254 — — 56,224 
Total current assets469,327 86,046 103,520 77 (22,775)636,195 
Other long-term assets      
Operating lease right-of-use assets96,026 23,271 327 — — 119,624 
Regulatory assets489,746 108,093 103,141 — — 700,980 
Other112,298 19,008 18,448 — (5,728)144,026 
Total other long-term assets698,070 150,372 121,916 — (5,728)964,630 
Total assets$5,324,207 1,016,884 930,143 77 (668,403)$6,602,908 
Capitalization and liabilities      
Capitalization      
Common stock equity$2,193,919 323,691 316,132 77 (639,900)$2,193,919 
Cumulative preferred stock—not subject to mandatory redemption
22,293 7,000 5,000 — — 34,293 
Long-term debt, net1,176,477 246,360 253,386 — — 1,676,223 
Total capitalization3,392,689 577,051 574,518 77 (639,900)3,904,435 
Current liabilities      
Current portion of operating lease liabilities61,505 3,354 35 — — 64,894 
Short-term borrowings from affiliate— 700 — — (700)— 
Accounts payable101,685 24,640 20,550 — — 146,875 
Interest and preferred dividends payable20,390 3,750 4,471 — (1)28,610 
Taxes accrued, including revenue taxes136,016 31,338 29,014 — — 196,368 
Regulatory liabilities21,257 4,164 6,840 — — 32,261 
Other71,738 14,488 20,503 — (22,223)84,506 
Total current liabilities412,591 82,434 81,413 — (22,924)553,514 
Deferred credits and other liabilities      
Operating lease liabilities47,585 19,917 300 — — 67,802 
Deferred income taxes284,245 51,822 60,486 — — 396,553 
Regulatory liabilities672,712 177,877 92,662 — — 943,251 
Unamortized tax credits78,215 14,577 13,586 — — 106,378 
Defined benefit pension and other postretirement benefit plans liability
364,749 74,183 76,619 — (5,579)509,972 
Other71,421 19,023 30,559 — — 121,003 
Total deferred credits and other liabilities1,518,927 357,399 274,212 — (5,579)2,144,959 
Total capitalization and liabilities$5,324,207 1,016,884 930,143 77 (668,403)$6,602,908 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Balance Sheet
December 31, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsi-diaries		Consoli-
dating
adjustments		Hawaiian Electric
Consolidated
Assets      
Property, plant and equipment
Utility property, plant and equipment      
Land$42,411 5,606 3,594 — — $51,611 
Plant and equipment4,960,470 1,352,885 1,195,988 — — 7,509,343 
Less accumulated depreciation(1,677,256)(597,606)(544,217)— — (2,819,079)
Construction in progress143,616 13,043 31,683 — — 188,342 
Utility property, plant and equipment, net3,469,241 773,928 687,048 — — 4,930,217 
Nonutility property, plant and equipment, less accumulated depreciation
5,306 115 1,532 — — 6,953 
Total property, plant and equipment, net3,474,547 774,043 688,580 — — 4,937,170 
Investment in wholly owned subsidiaries, at equity
626,890 — — — (626,890)— 
Current assets      
Cash and cash equivalents42,205 3,046 2,032 77 — 47,360 
Restricted cash15,966 — — — — 15,966 
Advances to affiliates26,700 — — — (26,700)— 
Customer accounts receivable, net102,736 23,989 21,107 — — 147,832 
Accrued unbilled revenues, net73,628 13,631 13,777 — — 101,036 
Other accounts receivable, net17,984 3,028 2,856 — (16,195)7,673 
Fuel oil stock, at average cost38,777 8,471 10,990 — — 58,238 
Materials and supplies, at average cost38,786 9,896 18,662 — — 67,344 
Prepayments and other34,306 5,197 4,580 — — 44,083 
Regulatory assets22,095 1,954 6,386 — — 30,435 
Total current assets413,183 69,212 80,390 77 (42,895)519,967 
Other long-term assets      
Operating lease right-of-use assets125,858 1,443 353 — — 127,654 
Regulatory assets513,192 114,461 108,620 — — 736,273 
Other98,307 17,992 20,010 — — 136,309 
Total other long-term assets737,357 133,896 128,983 — — 1,000,236 
Total assets$5,251,977 977,151 897,953 77 (669,785)$6,457,373 
Capitalization and liabilities      
Capitalization
Common stock equity$2,141,918 317,451 309,363 77 (626,891)$2,141,918 
Cumulative preferred stock—not subject to mandatory redemption
22,293 7,000 5,000 — — 34,293 
Long-term debt, net1,116,426 216,447 228,429 — — 1,561,302 
Total capitalization3,280,637 540,898 542,792 77 (626,891)3,737,513 
Current liabilities     
Current portion of operating lease liabilities64,599 98 33 — — 64,730 
Short-term borrowings-non-affiliate49,979 — — — — 49,979 
Short-term borrowings-affiliate— 18,800 7,900 — (26,700)— 
Accounts payable97,102 19,570 17,177 — — 133,849 
Interest and preferred dividends payable14,480 3,138 2,790 — (58)20,350 
Taxes accrued, including revenue taxes135,018 29,869 27,637 — — 192,524 
Regulatory liabilities20,224 8,785 8,292 — — 37,301 
Other57,926 13,851 18,621 — (16,136)74,262 
Total current liabilities439,328 94,111 82,450 — (42,894)572,995 
Deferred credits and other liabilities     
Operating lease liabilities67,824 1,344 326 — — 69,494 
Deferred income taxes282,685 54,108 61,005 — — 397,798 
Regulatory liabilities656,270 173,938 92,277 — — 922,485 
Unamortized tax credits82,563 15,363 13,989 — — 111,915 
Defined benefit pension and other postretirement benefit plans liability
373,112 77,679 79,741 — — 530,532 
Other69,558 19,710 25,373 — — 114,641 
Total deferred credits and other liabilities1,532,012 342,142 272,711 — — 2,146,865 
Total capitalization and liabilities$5,251,977 977,151 897,953 77 (669,785)$6,457,373 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Changes in Common Stock Equity
Nine months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Balance, December 31, 2020$2,141,918 317,451 309,363 77 (626,891)$2,141,918 
Net income for common stock135,601 17,187 18,095 — (35,282)135,601 
Other comprehensive income, net of taxes175 3 — — (3)175 
Common stock dividends(83,775)(10,950)(11,326)— 22,276 (83,775)
Balance, September 30, 2021$2,193,919 323,691 316,132 77 (639,900)$2,193,919 
 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Changes in Common Stock Equity
Nine months ended September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Balance, December 31, 2019$2,047,352 298,998 292,870 101 (591,969)$2,047,352 
Net income for common stock126,299 21,306 16,186 — (37,492)126,299 
Other comprehensive income, net of taxes99 2 — — (2)99 
Common stock dividends(80,352)(12,240)(10,788)— 23,028 (80,352)
Dissolution of subsidiary— — — (24)24 — 
Balance, September 30, 2020$2,093,398 308,066 298,268 77 (606,411)$2,093,398 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Cash Flows
Nine months ended September 30, 2021
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net cash provided by operating activities$157,191 32,698 30,643 — (22,276)$198,256 
Cash flows from investing activities      
Capital expenditures(137,916)(33,511)(32,319)— — (203,746)
Advances from affiliates26,000 — — — (26,000)— 
Other4,136 1,121 900 — — 6,157 
Net cash used in investing activities(107,780)(32,390)(31,419)— (26,000)(197,589)
Cash flows from financing activities      
Common stock dividends(83,775)(10,950)(11,326)— 22,276 (83,775)
Preferred stock dividends of Hawaiian Electric and subsidiaries(810)(400)(286)— — (1,496)
Repayment of short-term debt(50,000)— — — — (50,000)
Proceeds from issuance of long-term debt60,000 30,000 25,000 — — 115,000 
Net decrease in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less— (18,100)(7,900)— 26,000 — 
Other(703)(116)(123)— — (942)
Net cash provided by (used in) financing activities(75,288)434 5,365 — 48,276 (21,213)
Net increase (decrease) in cash and cash equivalents(25,877)742 4,589 — — (20,546)
Cash, cash equivalents and restricted cash, beginning of period58,171 3,046 2,032 77 — 63,326 
Cash, cash equivalents and restricted cash, end of period32,294 3,788 6,621 77 — 42,780 
Less: Restricted cash(6,313)— — — — (6,313)
Cash and cash equivalents, end of period$25,981 3,788 6,621 77 — $36,467 
Hawaiian Electric Company, Inc. and Subsidiaries
Condensed Consolidating Statement of Cash Flows
Nine months ended September 30, 2020
(in thousands)Hawaiian ElectricHawaii Electric LightMaui ElectricOther
subsidiaries		Consolidating
adjustments		Hawaiian Electric
Consolidated
Net cash provided by operating activities$205,645 27,256 34,678 — (22,624)$244,955 
Cash flows from investing activities     
Capital expenditures (180,088)(48,750)(38,644)— — (267,482)
Advances from (to) affiliates(800)8,000 — — (7,200)— 
Other5,636 1,056 1,031 (24)(404)7,295 
Net cash used in investing activities(175,252)(39,694)(37,613)(24)(7,604)(260,187)
Cash flows from financing activities     
Common stock dividends(80,352)(12,240)(10,788)— 23,028 (80,352)
Preferred stock dividends of Hawaiian Electric and subsidiaries(810)(400)(286)— — (1,496)
Proceeds from issuance of short-term debt100,000 — — — — 100,000 
Repayment of short-term debt(100,000)— — — — (100,000)
Proceeds from issuance of long-term debt205,000 10,000 40,000 — — 255,000 
Repayment of long-term debt(95,000)(14,000)— — — (109,000)
Net increase (decrease) in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less(46,987)26,500 (25,700)— 7,200 (38,987)
Other(1,249)(67)(253)— — (1,569)
Net cash provided by (used in) financing activities(19,398)9,793 2,973 — 30,228 23,596 
Net increase (decrease) in cash and cash equivalents10,995 (2,645)38 (24)— 8,364 
Cash, cash equivalents and restricted cash, beginning of period32,988 7,008 1,797 101 — 41,894 
Cash, cash equivalents and restricted cash, end of period43,983 4,363 1,835 77 — 50,258 
Less: Restricted cash(20,458)— — — — (20,458)
Cash and cash equivalents, end of period$23,525 4,363 1,835 77 — $29,800