Electric utility segment

6 Months Ended

Jun. 30, 2017

Electric utility subsidiary [Abstract]

Electric utility segment

Electric utility segment

Revenue taxes. The Utilities’ revenues include amounts for the recovery of various Hawaii state revenue taxes. Revenue taxes are generally recorded as an expense in the period the related revenues are recognized. However, the Utilities’ revenue tax payments to the taxing authorities in the period are based on the prior year’s billed revenues (in the case of public service company taxes and PUC fees) or on the current year’s cash collections from electric sales (in the case of franchise taxes). The Utilities included in the second quarters of 2017 and 2016 and six months ended June 30, 2017 and 2016 approximately $50 million, $44 million, $96 million and $87 million, respectively, of revenue taxes in “revenues” and in “taxes, other than income taxes” expense, in the unaudited condensed consolidated statements of income.

Unconsolidated variable interest entities.

HECO Capital Trust III.  HECO Capital Trust III (Trust III) was created and exists for the exclusive purposes of (i) issuing in March 2004 2,000,0006.50% Cumulative Quarterly Income Preferred Securities, Series 2004 (2004 Trust Preferred Securities) ($50 million aggregate liquidation preference) to the public and trust common securities ($1.5 million aggregate liquidation preference) to Hawaiian Electric, (ii) investing the proceeds of these trust securities in 2004 Debentures issued by Hawaiian Electric in the principal amount of $31.5 million and issued by Hawaii Electric Light and Maui Electric each in the principal amount of $10 million, (iii) making distributions on these trust securities and (iv) engaging in only those other activities necessary or incidental thereto. The 2004 Trust Preferred Securities are mandatorily redeemable at the maturity of the underlying debt on March 18, 2034, which maturity may be extended to no later than March 18, 2053; and are currently redeemable at the issuer’s option without premium. The 2004 Debentures, together with the obligations of the Utilities under an expense agreement and Hawaiian Electric’s obligations under its trust guarantee and its guarantee of the obligations of Hawaii Electric Light and Maui Electric under their respective debentures, are the sole assets of Trust III. Taken together, Hawaiian Electric’s obligations under the Hawaiian Electric debentures, the Hawaiian Electric indenture, the subsidiary guarantees, the trust agreement, the expense agreement and trust guarantee provide, in the aggregate, a full, irrevocable and unconditional guarantee of payments of amounts due on the Trust Preferred Securities. Trust III has at all times been an unconsolidated subsidiary of Hawaiian Electric. Since Hawaiian Electric, as the holder of 100% of the trust common securities, does not absorb the majority of the variability of Trust III, Hawaiian Electric is not the primary beneficiary and does not consolidate Trust III in accordance with accounting rules on the consolidation of VIEs. Trust III’s balance sheets as of June 30, 2017 and December 31, 2016 each consisted of $51.5 million of 2004 Debentures; $50.0 million of 2004 Trust Preferred Securities; and $1.5 million of trust common securities. Trust III’s income statements for the six months ended June 30, 2017 consisted of $1.7 million of interest income received from the 2004 Debentures; $1.6 million of distributions to holders of the Trust Preferred Securities; and $50,000 of common dividends on the trust common securities to Hawaiian Electric. As long as the 2004 Trust Preferred Securities are outstanding, Hawaiian Electric is not entitled to receive any funds from Trust III other than pro-rata distributions, subject to certain subordination provisions, on the trust common securities. In the event of a default by Hawaiian Electric in the performance of its obligations under the 2004 Debentures or under its Guarantees, or in the event any of the Utilities elect to defer payment of interest on any of their respective 2004 Debentures, then Hawaiian Electric will be subject to a number of restrictions, including a prohibition on the payment of dividends on its common stock.

Power purchase agreements.  As of June 30, 2017, the Utilities had five power purchase agreements (PPAs) for firm capacity and other PPAs with independent power producers (IPPs) and Schedule Q providers (e.g., 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.

Some of the IPPs provided sufficient information for Hawaiian Electric to determine that the IPP was not a VIE, or was either a “business” or “governmental organization,” and thus excluded from the scope of accounting standards for VIEs. Other IPPs declined to provide the information necessary for Hawaiian Electric to determine the applicability of accounting standards for VIEs. Since 2004, Hawaiian Electric has continued its efforts to obtain from the other IPPs the information necessary to make the determinations required under accounting standards for VIEs. In each year from 2005 to 2016, the Utilities sent letters to the identified IPPs requesting the required information. All of these IPPs declined to provide the necessary information, except that Kalaeloa Partners, L.P. (Kalaeloa) later agreed to provide the information pursuant to the amendments to its PPA (see below). During the negotiations of an amendment to the PPA with AES Hawaii, Inc. (AES Hawaii), management determined that Hawaiian Electric was not the primary beneficiary of AES Hawaii under the existing PPA and consolidation was not required (see below). Management has concluded that the consolidation of two entities owning wind farms was not required as Hawaii Electric Light and Maui Electric do not have variable interests in the entities because the PPAs do not require them to absorb any variability of the entities. If the requested information is ultimately received from the remaining IPPs, a possible outcome of future analyses of such information is the consolidation of one or more of such IPPs in the unaudited condensed consolidated financial statements. 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.

Pursuant to the current accounting standards for VIEs, Hawaiian Electric is deemed to have a variable interest in Kalaeloa and AES Hawaii by reason of the provisions of Hawaiian Electric’s PPA with Kalaeloa and AES Hawaii, respectively. However, management has concluded that Hawaiian Electric is not the primary beneficiary of Kalaeloa or AES Hawaii because Hawaiian Electric does not have the power to direct the activities that most significantly impact Kalaeloa’s and AES Hawaii’s economic performance nor the obligation to absorb Kalaeloa’s or AES Hawaii’s expected losses, if any, that could potentially be significant to Kalaeloa or AES Hawaii. Thus, Hawaiian Electric has not consolidated Kalaeloa or AES Hawaii in its unaudited condensed consolidated financial statements.

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.  As of June 30, 2017, purchases from all IPPs were as follows:

	Three months ended June 30				Six months ended June 30
(in millions)	2017		2016		2017		2016
Kalaeloa	$	48	$	36	$	88	$	65
AES Hawaii	35		36		64		74
HPOWER	16		17		33		33
Puna Geothermal Venture	10		5		18		12
HEP	10		4		17		15
Other IPPs 1	34		41		60		56
Total IPPs	$	153	$	139	$	280	$	255

¹  Includes wind power, solar power, feed-in tariff projects and other PPAs.

Kalaeloa Partners, L.P.  In October 1988, Hawaiian Electric entered into a PPA with Kalaeloa, subsequently approved by the PUC, which provided that Hawaiian Electric would purchase 180 megawatts (MW) of firm capacity for a period of 25 years beginning in May 1991. In October 2004, Hawaiian Electric and Kalaeloa entered into amendments to the PPA, subsequently approved by the PUC, which together effectively increased the firm capacity from 180 MW to 208 MW. The energy payments that Hawaiian Electric makes to Kalaeloa include: (1) a fuel component, with a fuel price adjustment based on the cost of low sulfur fuel oil, (2) a fuel additives cost component and (3) a non-fuel component, with an adjustment based on changes in the Gross National Product Implicit Price Deflator. The capacity payments that Hawaiian Electric makes to Kalaeloa are fixed in accordance with the PPA. Kalaeloa also has a steam delivery cogeneration contract with another customer, the term of which coincides with the PPA. The facility has been certified by the Federal Energy Regulatory Commission as a Qualifying Facility under the Public Utility Regulatory Policies Act of 1978.

Hawaiian Electric and Kalaeloa are in negotiations to address the PPA term that ended on May 23, 2016. On August 1, 2016, Hawaiian Electric and Kalaeloa entered into an agreement that neither party will give written notice of termination of the Kalaeloa PPA prior to October 31, 2017. The PPA automatically extends on a month-to-month basis as long as the parties are still negotiating in good faith. The month-to-month term extensions shall end 60 days after either party notifies the other in writing that negotiations have terminated.

AES Hawaii, Inc. Under a PPA entered into in March 1988, as amended (through Amendment No. 2) for a period of 30 years beginning September 1992, Hawaiian Electric agreed to purchase 180 MW of firm capacity from AES Hawaii. In August 2012, Hawaiian Electric filed an application with the PUC seeking an exemption from the PUC’s Competitive Bidding Framework to negotiate an amendment to the PPA to purchase 186 MW of firm capacity, and amend the energy pricing formula in the PPA. The PUC approved the exemption in April 2013, but Hawaiian Electric and AES Hawaii were not able to reach an agreement on the amendment. In June 2015, AES Hawaii filed an arbitration demand regarding a dispute about whether Hawaiian Electric was obligated to buy up to 9 MW of additional capacity based on a 1992 letter. Hawaiian Electric responded to the arbitration demand and in October 2015, AES Hawaii and Hawaiian Electric entered into a Settlement Agreement to stay the arbitration proceeding. The Settlement Agreement included certain conditions precedent which, if satisfied, would have released the parties from the claims under the arbitration proceeding. Among the conditions precedent was the successful negotiation and PUC approval of an amendment to the existing PPA.

In November 2015, Hawaiian Electric entered into Amendment No. 3 for which PUC approval was requested and subsequently denied in January 2017. Approval of Amendment No. 3 would have satisfied the final condition for effectiveness of the Settlement Agreement and resolved AES Hawaii's claims. Following the PUC's decision, the parties agreed to extend the stay of the arbitration proceeding, while settlement discussions continue.

Hu Honua Bioenergy, LLC. In May 2012, Hawaii Electric Light signed a PPA, which the PUC approved in December 2013, with Hu Honua Bioenergy, LLC (Hu Honua) for 21.5 MW of renewable, dispatchable firm capacity fueled by locally grown biomass from a facility on the island of Hawaii. Per the terms of the PPA, the Hu Honua plant was scheduled to be in service in 2016. However, Hu Honua encountered construction delays, failed to meet its obligations under the PPA and failed to provide adequate assurances that it could perform or had the financial means to perform. Hawaii Electric Light terminated the PPA on March 1, 2016. On November 30, 2016, Hu Honua filed a civil complaint in the United States District Court for the District of Hawaii that included claims purportedly arising out of the termination of Hu Honua’s PPA. On May 26, 2017, Hawaii Electric Light and Hu Honua entered into a settlement agreement that will settle all claims related to the termination of the original PPA. The settlement agreement was contingent on the PUC’s approval of an amended and restated PPA between Hawaii Electric Light and Hu Honua dated May 5, 2017. In July 2017, the PUC approved the amended and restated PPA. Hu Honua is expected to be on-line by the end of 2018.

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 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 Utilities submitted their Enterprise Information System Roadmap to the PUC in June 2014 and refiled an application for an ERP/EAM Implementation Project in July 2014 with an estimated cost of $82.4 million. In 2015, the PUC denied the request of the Utilities to defer the costs of the ERP software purchased in 2012 and these costs were written off in the third quarter of 2015.

On August 11, 2016, the PUC approved the Utilities’ request to commence the ERP/EAM Implementation Project, subject to certain conditions, including a $77.6 million cap on cost recovery as well as a requirement that the Utilities pass onto customers a minimum of $244 million in savings associated with the system over its 12-year service life. The decision and order (D&O) approved the deferral of certain project costs and allowed the accrual of allowance for funds used during construction (AFUDC), but limited the AFUDC rate to 1.75%. Pursuant to the D&O and subsequent orders, the Utilities are required to file a bottom-up, low-level analysis of the project’s benefits; performance metrics and tracking mechanism for passing the project’s benefits on to customers by September 2017; and monthly reports on the status and costs of the project.

On March 31, 2017, the Utilities filed their proposed methods of passing on to customers the estimated monetary savings attributable to the project. These proposed methods continue to be reviewed by the PUC and Consumer Advocate. The ERP/EAM Implementation Project is on schedule. The project is expected to go live by October 1, 2018. As of June 30, 2017, the Project incurred costs of $14.0 million of which $2.5 million were charged to other operation and maintenance (O&M) expense, $1.1 million relate to capital costs and $10.4 million are deferred costs.

Schofield Generating Station Project. In August 2012, the PUC approved a waiver from the competitive bidding framework to allow Hawaiian Electric to negotiate with the U.S. Army for the construction of a 50 MW utility owned and operated firm, renewable and dispatchable generation facility at Schofield Barracks. In September 2015, the PUC approved Hawaiian Electric’s application to expend $167 million for the project. In approving the project, the PUC placed a cost cap of $167 million for the project, stated 90% of the cap is allowed for cost recovery through cost recovery mechanisms other than base rates, and stated the $167 million cap will be adjusted downward due to any reduction in the cost of the engine contract due to a reduction in the foreign exchange rate. Hawaiian Electric was required to take all necessary steps to lock in the lowest possible exchange rate. On January 5, 2016, Hawaiian Electric executed window forward contracts, which lowered the cost of the engine contract by $9.7 million, resulting in a revised project cost cap of $157.3 million. Hawaiian Electric has received all of the major permits for the project, including a 35 year site lease from the U.S. Army. Construction of the facility began in October 2016, and the facility is expected to be placed in service in the second quarter of 2018. Project costs incurred as of June 30, 2017 amounted to $87.8 million. The project costs have been included for recovery in the 2017 test year rate case.

West Loch PV Project. In July 2016, Hawaiian Electric announced plans to build, own and operate a utility-owned, grid-tied 20-MW (ac) solar facility in conjunction with the Department of the Navy at a Navy/Air Force joint base. In June 2017, the PUC approved the expenditure of funds for the project, including Hawaiian Electric’s proposed project cost cap of $67 million and a performance guarantee to provide energy at 9.56 cents/KWH or less. Project costs incurred as of June 30, 2017 amounted to $0.4 million.

In approving the project, the PUC agreed the project is eligible for recovery of costs offset by related net benefits under the Major Project Interim Recovery (MPIR) guidelines (see “Decoupling” section below for MPIR guidelines). The PUC established a procedural schedule for Hawaiian Electric to provide supplemental materials to support meeting the MPIR guidelines for recovery of costs accompanied by system performance guarantee and cost savings sharing mechanisms and for the Consumer Advocate to review and comment on the information filed.  This is first instance in which the PUC is considering a request for recovery pursuant to the MPIR Guidelines.

Hamakua Energy Partners, L.P. (HEP) Asset Purchase Agreement. Hawaii Electric Light has been purchasing up to 60 MW (net) of firm capacity from HEP under a PPA that expires on December 30, 2030. The HEP plant currently contributes about 23% of the island of Hawaii’s generating capacity. In December 2015, Hawaii Electric Light entered into an agreement, subject to PUC approval, to acquire the assets of HEP for approximately $84.5 million. On May 4, 2017, the PUC denied Hawaii Electric Light’s application for approval of the Asset Purchase Agreement (APA) on the grounds that customer benefits were not sufficiently demonstrated to justify the purchase and in July 2017, Hawaii Electric Light and HEP terminated the APA.

Hawaiian Telcom. The Utilities each have separate agreements for the joint ownership and maintenance of utility poles with Hawaiian Telcom, Inc. (Hawaiian Telcom), the respective county or counties in which each utility operates and other third parties, such as the State of Hawaii. The agreements set forth various circumstances requiring pole removal/installation/replacement and the sharing of costs among the joint pole owners. The agreements allow for the cost of work done by one joint pole owner to be shared by the other joint pole owners based on the apportionment of costs in the agreements. The Utilities have maintained, replaced and installed the majority of the jointly-owned poles in each of the respective service territories, and have billed the other joint pole owners for their respective share of the costs. The counties and the State have been reimbursing the Utilities for their share of the costs. However, Hawaiian Telcom has been delinquent in reimbursing the Utilities for its share of the costs.

Hawaiian Electric has initiated a dispute resolution process to collect the unpaid amounts from Hawaiian Telcom as specified by the joint pole agreement. For Hawaii Electric Light, the agreement does not specify an alternative dispute resolution process, and thus a complaint for payment was filed with the Circuit Court in June 2016. Maui Electric has not yet commenced any legal action to recover the delinquent amounts. As of June 30, 2017, total receivables under the joint pole agreement, including interest, from Hawaiian Telcom are $22.1 million ($14.8 million at Hawaiian Electric, $6.0 million at Hawaii Electric Light, and $1.3 million at Maui Electric). Management expects to prevail on these claims but has reserved for the accrued interest of $4.9 million on the receivables.

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 into the environment 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 by merger 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 Environmental Protection Agency (EPA) has since identified environmental impacts in the subsurface soil at the Site. Although Maui Electric never operated at the Site or owned the Site property, after discussions with the EPA and the Hawaii Department of Health (DOH), Maui Electric agreed to undertake additional investigations at the Site and an adjacent parcel that Molokai Electric Company had used for equipment storage (the Adjacent Parcel) to determine the extent of environmental contamination. A 2011 assessment by a Maui Electric contractor of the Adjacent Parcel identified environmental impacts, including elevated polychlorinated biphenyls (PCBs) in the subsurface soils. In cooperation with the DOH and EPA, Maui Electric is further investigating the Site and the Adjacent Parcel to determine the extent of impacts of PCBs, residual fuel oils and other subsurface contaminants. Maui Electric has a reserve balance of $3.5 million as of June 30, 2017, representing the probable and reasonably estimated cost to complete the additional investigation and estimated cleanup costs at the Site and the Adjacent Parcel; however, final costs of remediation will depend on the results of continued investigation.

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 cleanup of PCB contamination in sediment in the area offshore of the Waiau Power Plant as part of the Pearl Harbor Superfund Site. The Navy has also requested that Hawaiian Electric reimburse the costs incurred by the Navy to investigate the area. The Navy has completed a remedial investigation and a feasibility study (FS) for the remediation of contaminated sediment at several locations in Pearl Harbor and issued its Final FS Report on June 29, 2015. On February 2, 2016, the Navy released the Proposed Plan for Pearl Harbor Sediment Remediation and Hawaiian Electric submitted comments. The extent of the contamination, the appropriate remedial measures to address it and Hawaiian Electric’s potential responsibility for any associated costs have not been determined.

On March 23, 2015, Hawaiian Electric received a letter from the EPA requesting that Hawaiian Electric submit a work plan to assess potential sources and extent of PCB contamination onshore at the Waiau Power Plant. Hawaiian Electric submitted a sampling and analysis (SAP) work plan to the EPA and the DOH. Onshore sampling at the Waiau Power Plant was completed in two phases in December 2015 and June 2016. The extent of the onshore contamination, the appropriate remedial measures to address it and any associated costs have not yet been determined.

As of June 30, 2017, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was $4.9 million. The reserve represents the probable and reasonably estimable cost to complete the onshore and offshore investigations and the remediation of PCB contamination in the offshore sediment. The final remediation costs will depend on the results of the onshore investigation and assessment of potential source control requirements, as well as the further investigation of contaminated sediment offshore from the Waiau Power Plant.

Regulatory proceedings

April 2014 regulatory orders.In April 2014, the PUC issued four orders that collectively address certain key policy, resource planning and operational issues for the Utilities. The Utilities addressed these orders as follows:

Integrated Resource Planning. The PUC did not accept the Utilities’ Integrated Resource Plan and Action Plans submission, and, in lieu of an approved plan, has commenced other initiatives to enable resource planning. The PUC directed each of Hawaiian Electric and Maui Electric to file their respective Power Supply Improvement Plans (PSIPs), which they did in August 2014. The PUC also provided its inclinations on the future of Hawaii’s electric utilities in an exhibit to the order. The exhibit provides the PUC’s perspectives on the vision, business strategies and regulatory policy changes required to align the Utilities' business model with customers’ interests and the state’s public policy goals.

Reliability Standards Working Group. The PUC ordered the Utilities to take timely actions intended to lower energy costs, improve system reliability and address emerging challenges to integrate additional renewable energy. In addition to the PSIPs mentioned above, the PUC ordered certain filing requirements, including a Distributed Generation Interconnection Plan, which the Utilities filed in August 2014.

The PUC also stated it would be opening new dockets to address (1) reliability standards, (2) the technical, economic and policy issues associated with distributed energy resources (DER) and (3) the Hawaii electricity reliability administrator, which is a third party position which the legislature has authorized the PUC to create by contract to provide support for the PUC in developing and periodically updating local grid reliability standards and procedures and interconnection requirements and overseeing grid access and operation. The PUC has not yet opened new dockets to address the first and third topics above. To address DER, the second topic, the PUC opened an investigative proceeding on August 21, 2014 (see “DER Investigative Proceeding” below).

Policy Statement and Order Regarding Demand Response Programs. The PUC provided guidance concerning the objectives and goals for demand response programs, and ordered the Utilities to develop an integrated Demand Response (DR) Portfolio Plan that will enhance system operations and reduce costs to customers. The Utilities’ Plan was filed in July 2014. Subsequently, the Utilities submitted status updates and an update and supplemental report to the Plan. In July 2015, the PUC issued an order appointing a special adviser to guide, monitor and review the Utility’s Plan design and implementation. In December 2015, the Utilities filed applications with the PUC (1) for approval of their proposed DR Portfolio Tariff Structure, Reporting Schedule and Cost Recovery of Program Costs and (2) for approval to defer and recover certain computer software and software development costs for a DR Management System through the Renewable Energy Infrastructure Program (REIP) Surcharge. The Utilities filed an updated DR Portfolio Plan in February 2017. In May 2017, the Utilities filed their reply to the statements of position submitted by the other parties and are awaiting a PUC decision.

In the DR Management System proceeding, the parties filed statements of position in December 2016 and are awaiting a PUC decision.

Review of PSIPs. Collectively, the PUC's April 2014 resource planning orders confirm the energy policy and operational priorities that will guide the Utilities' strategies and plans going forward.

In August 2014, the Utilities filed proposed PSIPs with the PUC, as required by the PUC orders issued in April 2014. Updated PSIPs were filed in April 2016, pursuant to an order issued by the PUC in November 2015 which included the PUC’s observations and concerns, and comments provided by parties and participants. The Updated PSIPs provided plans to achieve 100% renewable energy using a diverse mix of energy resources by 2045. Under these plans, the Utilities support sustainable growth of private rooftop solar, expand use of energy storage systems, empower customers by developing smart grids and offer new products and services to customers (e.g., community solar, microgrids and voluntary “demand response” programs). In December 2016, the Utilities filed a PSIP Update Report as ordered by the PUC. The updated plans describe greater and faster expansion of the Utilities’ renewable energy portfolio than in the plans filed in April 2016, and emphasize work that is in progress or planned over the next five years on each of the five islands the Utilities serve. The plans include the continued growth of private rooftop solar and describe the grid and generation modernization work needed to reliably integrate an estimated total of 165,000 private systems by 2030, more than double today’s total of 79,000, and additional grid-scale renewable energy resources.

On July 14, 2017, the PUC accepted the Utilities’ PSIP December 2016 Update Report and closed the proceeding. In its order, the PUC provided guidance regarding the implementation of the Utilities’ near-term action plan and future planning activities, requiring the Utilities to file a report that details an updated resource planning approach and schedule by March 1, 2018. The PUC order stated that it intends to use the PSIPs in conjunction with its evaluation of specific filings for approval of capital and other projects.

DER investigative proceeding. In March 2015, the PUC issued an order to address DER issues.

On June 29, 2015, the Utilities submitted their final Statement of Position in the DER proceeding, which included:

(1) new pricing provisions for future private rooftop photovoltaic (PV) systems,

(2) technical standards for advanced inverters,

(3) new options for customers including battery-equipped private rooftop PV systems,

(4) a pilot time-of-use rate,

(5) an improved method of calculating the amount of private rooftop PV that can be safely installed, and

(6) a streamlined and standardized PV application process.

On October 12, 2015, the PUC issued a D&O establishing DER reforms that: (1) promote rapid adoption of the next generation of solar PV and other distributed energy technologies; (2) encourage more competitive pricing of distributed energy resource systems; (3) lower overall energy supply costs for all customers; and (4) help to manage DER in terms of each island’s limited grid capacity.

The D&O capped the Utilities Net Energy Metering (NEM) programs at “existing” levels (i.e., for existing NEM customers and customers who already applied and were waiting for approval), closed their NEM programs to new participants, and approved new options for customers to interconnect DER to their electric grids, including Self Supply and Grid Supply tariff options.  The PUC placed caps on the availability of the Grid Supply program.  The Self Supply Program is designed for customers who do not export to the grid.

In June 2016, the PUC approved the Utilities Advanced Inverter Test Plan and the Utilities submitted the results of the testing to the PUC.

Pursuant to a PUC order, in October 2016, the Utilities submitted tariffs for a Residential Interim Time of Use program, which is limited to 2 years and 5,000 customers. The primary objective is to encourage more efficient use of the electric system and enable more cost-effective integration of renewable energy by shifting customer load from the system’s higher cost, peak demand period to the mid-day period when relatively inexpensive renewable resources are abundant.

The DER Phase 2 of this proceeding is focused on further developing competitive markets for distributed energy resources, including storage. On December 9, 2016, the PUC issued an order, establishing the statement of issues and procedural schedule to govern Phase 2 of this proceeding. Technical track issues, including DER integration analyses and revisions to interconnection standards, will be addressed before the end of 2017. More complex market issues will be addressed in late 2018.

Pursuant to PUC order, in January and February 2017, the Utilities and various DER parties submitted tariff proposals and stipulations to modify existing interim DER option and proposals, and interconnection standards to facilitate or enable interim DER options, as well as provided comments and reply comments on such tariff proposals.

In May 2017, the PUC issued a D&O that approved the parties’ stipulations filed in January and February 2017.  This D&O also instructed the development of smart export proposals and Customer Self-Supply revisions, directed working groups to collaborate to discuss Phase 2 issues, and modified the procedural schedule.  In compliance with the D&O, the Utilities are meeting regularly with the DER parties in various working groups, and preparing for the next upcoming filing on technical track issues on August 7, 2017.

Decoupling.Decoupling is a regulatory model that is intended to facilitate meeting the State of Hawaii’s goals to transition to a clean energy economy and achieve an aggressive renewable portfolio standard. The decoupling model implemented in Hawaii delinks revenues from sales and includes annual rate adjustments. The decoupling mechanism has three components: (1) a sales decoupling component via a revenue balancing account (RBA), (2) a revenue escalation component via a rate adjustment mechanism (RAM) and (3) an earnings sharing mechanism, which would provide for a reduction of revenues between rate cases in the event the utility exceeds the return on average common equity (ROACE) allowed in its most recent rate case. Decoupling provides for more timely cost recovery and earning on investments.

For the RAM years 2014 - 2016, Hawaiian Electric was allowed to record RAM revenue beginning on January 1 and to bill such amounts from June 1 of the applicable year through May 31 of the following year (current accrual method). Subsequent to 2016, Hawaiian Electric reverted to the RAM provisions initially approved in March 2011—i.e., RAM is both accrued and billed from June 1 of each year through May 31 of the following year.

2015 decoupling order. On March 31, 2015, the PUC issued an Order (the 2015 Decoupling Order) that modified the RAM portion of the decoupling mechanism to be capped at the lesser of the RAM revenue adjustment as then determined (based on an inflationary adjustment for certain O&M expenses and return on investment for certain rate base changes) and a RAM revenue adjustment calculated based on the cumulative annual compounded increase in Gross Domestic Product Price Index applied to annualized target revenues (the RAM Cap). The 2015 Decoupling Order provided a specific basis for calculating the target revenues until the next rate case, at which time the target revenues will reset. The triennial rate case cycle required under the decoupling mechanism continues to serve as the maximum period between the filing of general rate cases.

The RAM Cap impacted the Utilities' recovery of capital investments as follows:

• Hawaiian Electric's RAM revenues were limited to the RAM Cap in 2015, 2016 and 2017.

• Maui Electric's RAM revenues were limited to the RAM Cap in 2015 and 2016; however, the 2017 RAM revenues were below the RAM Cap.

• Hawaii Electric Light’s RAM revenues were below the RAM Cap in 2015, 2016 and 2017.

2017 decoupling order. On April 27, 2017, the PUC issued an Order (the 2017 Decoupling Order) that requires the establishment of specific performance incentive mechanisms and provides guidelines for interim recovery of revenues to support major projects placed in service between general rate cases.

On May 30, 2017, the Utilities filed their proposed initial tariffs to implement conventional stand-alone performance incentive mechanisms. The performance incentive mechanisms to be established are:

• Service reliability performance standards to include: 1) System Average Interruption Duration Index based on the average customer interruption time and 2) System Average Interruption Frequency Index based on the average number of customer interruptions. Target performance for each is based on each utilities’ historical 10 year average performance with a dead band of one standard deviation. The maximum penalty for each is 20 basis points applied to the common equity share of the rate base approved in the last rate case for each company. However, the maximum penalty for the initial implementation of the approved PIMs would be the 20 basis points applied to the common equity share of rate base used to determine the 2016 RAM Revenue Adjustment (or approximately $3 million for each of the standards in total for the three utilities). The maximum penalty will be updated upon issuance of an interim or final order in a rate case for each company and will remain constant in interim periods. These performance standards have penalties only.

• Call Center Performance based on utility call center 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 dead band of 3% above and below the target. The maximum penalty or incentive is 8 basis points applied to the common equity share of the rate base approved in the last rate case for each company, except for the initial implementation which will be 8 basis points applied to the common equity share of rate base used to determine the 2016 RAM Revenue Adjustment (or approximately $1.2 million penalty or incentive in total for the three utilities).

The 2017 Decoupling Order also established guidelines for MPIR. 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 net costs of approved 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 shall 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.

In the 2017 Decoupling Order, the PUC indicated that in pending and subsequent rate cases, the PUC intends to require all fuel expenses and purchased energy expenses be recovered through an appropriately modified energy cost adjustment mechanism rather than through base rates, and will consider adopting processes to periodically reset fuel efficiency measures embedded in the energy cost adjustment mechanism to account for changes in the generating system.

Annual decoupling filings. On March 31, 2017, the Utilities submitted to the PUC, their annual decoupling filings for tariffed rates that will be effective from June 1, 2017, through May 31, 2018. On May 22, 2017, Maui Electric amended its annual decoupling filing to update and revise certain cost information. The net annual incremental amounts proposed to be collected (refunded), as revised for Maui Electric, were as follows:

($ in millions)	Hawaiian Electric			Hawaii Electric Light			Maui Electric
2017 Annual incremental RAM adjusted revenues	$	12.7		$	3.2		$	1.6
Annual change in accrued earnings sharing credits	$	—		$	—		$	—
Annual change in accrued RBA balance as of December 31, 2016 (and associated revenue taxes) (refunded)	$	(2.4	)	$	(2.5	)	$	(0.2	)
Net annual incremental amount to be collected under the tariffs	$	10.3		$	0.7		$	1.4
Impact on typical residential customer monthly bill (in dollars) *	$	0.60		$	0.15		$	0.79

* Based on a 500 kilowatthour (KWH) bill for Hawaiian Electric, Maui Electric, and Hawaii Electric Light. The bill impact for Lanai and Molokai customers is expected to be an increase of $0.63, based on a 400 KWH bill.

On May 31, 2017, the PUC approved the annual decoupling filings for Hawaiian Electric and Hawaii Electric Light, and as amended on May 22, 2017, for Maui Electric, which went into effect on June 1, 2017.

Hawaiian Electric consolidated 2014 test year abbreviated and 2017 test year rate cases. On December 23, 2016, the PUC issued an order consolidating the Hawaiian Electric filings for the 2014 test year abbreviated rate case and the 2017 test year rate case. The order also found and concluded that Hawaiian Electric's abbreviated 2014 rate case filing did not comply with: (1) the Mandatory Triennial Rate Case Cycle requirement in the decoupling order that Hawaiian Electric file an application for a general rate case every three years and (2) the requirement that Hawaiian Electric file its 2014 calendar test year rate case application by June 27, 2014. The order then stated that: “[T]he determination and disposition of any rates, accounts, adjustment mechanisms, and practices that would have been subject to review in the context of a 2014 test year rate case proceeding are subject to appropriate adjustment based on evidence and findings in the consolidated rate case proceeding.”

On January 4, 2017, Hawaiian Electric filed a motion for clarification and/or partial reconsideration of the PUC’s order. On March 14, 2017, the PUC issued an order to address Hawaiian Electric’s motion, stating that the PUC is not initiating an investigation/enforcement proceeding against Hawaiian Electric regarding its compliance with the decoupling order, and the transfer and consolidation of Hawaiian Electric’s 2014 abbreviated rate case with the 2017 rate case is intended to ensure that ratepayers receive the attendant benefits of Hawaiian Electric’s decision to voluntarily forgo a general rate increase in base rates for its mandated 2014 test year. As directed, on April 12, 2017, Hawaiian Electric filed a supplement to its 2017 rate case filing, addressing the items raised in the order and explaining why Hawaiian Electric’s forgoing of a general rate increase in the 2014 test year should not result in any further adjustments to Hawaiian Electric’s revenue requirement in the 2017 test year.

On April 26, 2017, the PUC issued an Order regarding the supplement to Hawaiian Electric’s 2017 rate case filing, requesting updated pension and OPEB regulatory asset and liability schedules, by May 12, 2017, to reflect the use of the 2014 net periodic pension cost (NPPC) and net periodic benefits costs (NPBC) for the pension and OPEB tracking mechanisms and with amortization of such regulatory assets and liabilities beginning May 1, 2015. On May 12, 2017, Hawaiian Electric filed these schedules and on May 31, 2017, supplemented its May 12, 2017 filing to show the cumulative impact of the 2015-2017 change in employee benefits transferred to capital as a result of the change in the amortization of the pension and OPEB regulatory assets and liabilities.

On June 28, 2017, the PUC issued an order designating the filing date of Hawaiian Electric’s completed rate case application to be May 31, 2017, rather than December 16, 2016, the date of the filing of Hawaiian Electric’s rate case application. The revised date of the completed application coincided with the date that Hawaiian Electric filed supplemental pension-related information described above. On July 28, 2017, the PUC issued a procedural schedule with an interim D&O tentatively scheduled for December 15, 2017, and an evidentiary hearing in early March 2018.

Condensed consolidating financial information. Hawaiian Electric is not required to provide separate financial statements or other disclosures concerning Hawaii Electric Light and Maui Electric to holders of the 2004 Debentures issued by Hawaii Electric Light and Maui Electric to Trust III since all of their voting capital stock is owned, and their obligations with respect to these securities have been fully and unconditionally guaranteed, on a subordinated basis, by Hawaiian Electric. Consolidating information is provided below for Hawaiian Electric and each of its subsidiaries for the periods ended and as of the dates indicated.

Hawaiian Electric also 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, (b) under their respective private placement note agreements and the Hawaii Electric Light notes and Maui Electric notes issued thereunder and (c) relating to the trust preferred securities of Trust III. 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 (unaudited)

Three months ended June 30, 2017

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Revenues	$	394,414		81,710		80,765		—	(14	)	$	556,875
Expenses
Fuel oil	99,814			14,475		26,970		—	—		141,259
Purchased power	116,458			23,482		13,127		—	—		153,067
Other operation and maintenance	70,961			17,558		17,855		—	—		106,374
Depreciation	32,723			9,686		5,747		—	—		48,156
Taxes, other than income taxes	37,619			7,702		7,651		—	—		52,972
Total expenses	357,575			72,903		71,350		—	—		501,828
Operating income	36,839			8,807		9,415		—	(14	)	55,047
Allowance for equity funds used during construction	2,659			134		234		—	—		3,027
Equity in earnings of subsidiaries	7,936			—		—		—	(7,936	)	—
Interest expense and other charges, net	(12,562		)	(2,996	)	(2,670	)	—	14		(18,214		)
Allowance for borrowed funds used during construction	988			55		100		—	—		1,143
Income before income taxes	35,860			6,000		7,079		—	(7,936	)	41,003
Income taxes	9,946			2,235		2,679		—	—		14,860
Net income	25,914			3,765		4,400		—	(7,936	)	26,143
Preferred stock dividends of subsidiaries	—			133		96		—	—		229
Net income attributable to Hawaiian Electric	25,914			3,632		4,304		—	(7,936	)	25,914
Preferred stock dividends of Hawaiian Electric	270			—		—		—	—		270
Net income for common stock	$	25,644		3,632		4,304		—	(7,936	)	$	25,644

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income (unaudited)

Three months ended June 30, 2017

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Net income for common stock	$	25,644		3,632		4,304		—	(7,936	)	$	25,644
Other comprehensive income (loss), net of taxes:
Derivatives qualified as cash flow hedges:
Reclassification adjustment to net income, net of tax benefits	—			—		—		—	—		—
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 benefits	3,621			449		344		—	(793	)	3,621
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(3,581		)	(448	)	(343	)	—	791		(3,581		)
Other comprehensive income (loss), net of taxes	40			1		1		—	(2	)	40
Comprehensive income attributable to common shareholder	$	25,684		3,633		4,305		—	(7,938	)	$	25,684

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income (unaudited)

Three months ended June 30, 2016

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Revenues	$	347,010		73,652		74,758		—	(25	)	$	495,395
Expenses
Fuel oil	62,234			11,748		17,917		—	—		91,899
Purchased power	103,062			19,360		16,636		—	—		139,058
Other operation and maintenance	68,197			15,116		16,250		—	—		99,563
Depreciation	31,522			9,449		5,789		—	—		46,760
Taxes, other than income taxes	33,414			6,905		7,110		—	—		47,429
Total expenses	298,429			62,578		63,702		—	—		424,709
Operating income	48,581			11,074		11,056		—	(25	)	70,686
Allowance for equity funds used during construction	1,559			206		232		—	—		1,997
Equity in earnings of subsidiaries	10,883			—		—		—	(10,883	)	—
Interest expense and other charges, net	(10,345		)	(2,669	)	(2,114	)	—	25		(15,103		)
Allowance for borrowed funds used during construction	587			79		94		—	—		760
Income before income taxes	51,265			8,690		9,268		—	(10,883	)	58,340
Income taxes	15,138			3,337		3,509		—	—		21,984
Net income	36,127			5,353		5,759		—	(10,883	)	36,356
Preferred stock dividends of subsidiaries	—			133		96		—	—		229
Net income attributable to Hawaiian Electric	36,127			5,220		5,663		—	(10,883	)	36,127
Preferred stock dividends of Hawaiian Electric	270			—		—		—	—		270
Net income for common stock	$	35,857		5,220		5,663		—	(10,883	)	$	35,857

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income (unaudited)

Three months ended June 30, 2016

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Net incomefor common stock	$	35,857		5,220		5,663		—	(10,883	)	$	35,857
Other comprehensive income (loss), net of taxes:
Derivatives qualified as cash flow hedges:
Effective portion of foreign currency hedge net unrealized loss, net of tax benefits	(745		)	—		—		—	—		(745		)
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 benefits	3,391			401		357		—	(758	)	3,391
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(3,401		)	(402	)	(359	)	—	761		(3,401		)
Other comprehensive income (loss), net of taxes	(755		)	(1	)	(2	)	—	3		(755		)
Comprehensive income attributable to common shareholder	$	35,102		5,219		5,661		—	(10,880	)	$	35,102

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income (unaudited)

Six months ended June 30, 2017

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Revenues	$	757,257		160,692		157,558		—	(21	)	$	1,075,486
Expenses
Fuel oil	197,815			31,732		55,982		—	—		285,529
Purchased power	216,605			42,071		21,515		—	—		280,191
Other operation and maintenance	138,239			33,074		35,301		—	—		206,614
Depreciation	65,445			19,371		11,556		—	—		96,372
Taxes, other than income taxes	72,659			15,152		14,984		—	—		102,795
Total expenses	690,763			141,400		139,338		—	—		971,501
Operating income	66,494			19,292		18,220		—	(21	)	103,985
Allowance for equity funds used during construction	4,715			249		462		—	—		5,426
Equity in earnings of subsidiaries	16,539			—		—		—	(16,539	)	—
Interest expense and other charges, net	(24,619		)	(6,000	)	(5,120	)	—	21		(35,718		)
Allowance for borrowed funds used during construction	1,737			100		195		—	—		2,032
Income before income taxes	64,866			13,641		13,757		—	(16,539	)	75,725
Income taxes	17,217			5,158		5,243		—	—		27,618
Net income	47,649			8,483		8,514		—	(16,539	)	48,107
Preferred stock dividends of subsidiaries	—			267		191		—	—		458
Net income attributable to Hawaiian Electric	47,649			8,216		8,323		—	(16,539	)	47,649
Preferred stock dividends of Hawaiian Electric	540			—		—		—	—		540
Net income for common stock	$	47,109		8,216		8,323		—	(16,539	)	$	47,109

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income (unaudited)

Six months ended June 30, 2017

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Net income for common stock	$	47,109		8,216		8,323		—	(16,539	)	$	47,109
Other comprehensive income (loss), net of taxes:
Derivatives qualifying as cash flow hedges:
Reclassification adjustment to net income, net of tax benefits	454			—		—		—	—		454
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 benefits	7,239			952		810		—	(1,762	)	7,239
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(7,194		)	(951	)	(810	)	—	1,761		(7,194		)
Other comprehensive income (loss), net of taxes	499			1		—		—	(1	)	499
Comprehensive income attributable to common shareholder	$	47,608		8,217		8,323		—	(16,540	)	$	47,608

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income (unaudited)

Six months ended June 30, 2016

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Revenues	$	684,185		146,835		146,464		—	(37	)	$	977,447
Expenses
Fuel oil	136,319			26,122		43,198		—	—		205,639
Purchased power	194,979			36,157		23,781		—	—		254,917
Other operation and maintenance	137,755			31,557		34,159		—	—		203,471
Depreciation	63,044			18,898		11,599		—	—		93,541
Taxes, other than income taxes	66,098			13,796		13,973		—	—		93,867
Total expenses	598,195			126,530		126,710		—	—		851,435
Operating income	85,990			20,305		19,754		—	(37	)	126,012
Allowance for equity funds used during construction	2,965			333		438		—	—		3,736
Equity in earnings of subsidiaries	18,812			—		—		—	(18,812	)	—
Interest expense and other charges, net	(22,210		)	(5,634	)	(4,604	)	—	37		(32,411		)
Allowance for borrowed funds used during construction	1,116			128		178		—	—		1,422
Income before income taxes	86,673			15,132		15,766		—	(18,812	)	98,759
Income taxes	24,909			5,683		5,945		—	—		36,537
Net income	61,764			9,449		9,821		—	(18,812	)	62,222
Preferred stock dividends of subsidiaries	—			267		191		—	—		458
Net income attributable to Hawaiian Electric	61,764			9,182		9,630		—	(18,812	)	61,764
Preferred stock dividends of Hawaiian Electric	540			—		—		—	—		540
Net income for common stock	$	61,224		9,182		9,630		—	(18,812	)	$	61,224

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income (unaudited)

Six months ended June 30, 2016

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Net incomefor common stock	$	61,224		9,182		9,630		—	(18,812	)	$	61,224
Other comprehensive income, net of taxes:
Derivatives qualifying as cash flow hedges:
Effective portion of foreign currency hedge net unrealized gain, net of taxes	257			—		—		—	—		257
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 benefits	6,627			859		775		—	(1,634	)	6,627
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(6,623		)	(860	)	(777	)	—	1,637		(6,623		)
Other comprehensive income, net of taxes	261			(1	)	(2	)	—	3		261
Comprehensive income attributable to common shareholder	$	61,485		9,181		9,628		—	(18,809	)	$	61,485

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet (unaudited)

June 30, 2017

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consoli- dating adjustments		Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	43,971		6,191		3,016		—	—		$	53,178
Plant and equipment	4,318,460			1,267,529		1,125,429		—	—		6,711,418
Less accumulated depreciation	(1,423,042		)	(518,266	)	(488,789	)	—	—		(2,430,097		)
Construction in progress	232,965			16,734		22,739		—	—		272,438
Utility property, plant and equipment, net	3,172,354			772,188		662,395		—	—		4,606,937
Nonutility property, plant and equipment, less accumulated depreciation	5,763			115		1,532		—	—		7,410
Total property, plant and equipment, net	3,178,117			772,303		663,927		—	—		4,614,347
Investment in wholly owned subsidiaries, at equity	553,764			—		—		—	(553,764	)	—
Current assets
Cash and cash equivalents	29,988			7,104		5,389		101	—		42,582
Advances to affiliates	—			4,100		1,000		—	(5,100	)	—
Customer accounts receivable, net	88,614			18,847		18,700		—	—		126,161
Accrued unbilled revenues, net	74,640			14,166		14,790		—	—		103,596
Other accounts receivable, net	9,707			2,471		1,042		—	(9,536	)	3,684
Fuel oil stock, at average cost	51,489			8,135		12,768		—	—		72,392
Materials and supplies, at average cost	30,716			8,852		17,531		—	—		57,099
Prepayments and other	25,695			7,294		3,602		—	(251	)	36,340
Regulatory assets	65,891			3,981		4,295		—	—		74,167
Total current assets	376,740			74,950		79,117		101	(14,887	)	516,021
Other long-term assets
Regulatory assets	638,480			119,108		106,522		—	—		864,110
Unamortized debt expense	497			84		109		—	—		690
Other	48,164			13,778		14,045		—	—		75,987
Total other long-term assets	687,141			132,970		120,676		—	—		940,787
Total assets	$	4,795,762		980,223		863,720		101	(568,651	)	$	6,071,155
Capitalization and liabilities
Capitalization
Common stock equity	$	1,803,506		291,760		261,903		101	(553,764	)	$	1,803,506
Cumulative preferred stock—not subject to mandatory redemption	22,293			7,000		5,000		—	—		34,293
Long-term debt, net	915,208			213,677		189,960		—	—		1,318,845
Total capitalization	2,741,007			512,437		456,863		101	(553,764	)	3,156,644
Current liabilities
Short-term borrowings from non-affiliates	43,990			—		—		—	—		43,990
Short-term borrowings from affiliate	5,100			—		—		—	(5,100	)	—
Accounts payable	123,986			19,796		18,593		—	—		162,375
Interest and preferred dividends payable	13,584			3,806		2,113		—	(6	)	19,497
Taxes accrued	98,156			23,394		20,964		—	(251	)	142,263
Regulatory liabilities	126			713		2,044		—	—		2,883
Other	38,964			8,920		14,786		—	(9,530	)	53,140
Total current liabilities	323,906			56,629		58,500		—	(14,887	)	424,148
Deferred credits and other liabilities
Deferred income taxes	542,109			111,616		106,023		—	224		759,972
Regulatory liabilities	297,006			98,844		32,897		—	—		428,747
Unamortized tax credits	59,537			16,246		15,603		—	—		91,386
Defined benefit pension and other postretirement benefit plans liability	435,614			73,246		78,858		—	—		587,718
Other	49,798			13,803		15,959		—	(224	)	79,336
Total deferred credits and other liabilities	1,384,064			313,755		249,340		—	—		1,947,159
Contributions in aid of construction	346,785			97,402		99,017		—	—		543,204
Total capitalization and liabilities	$	4,795,762		980,223		863,720		101	(568,651	)	$	6,071,155

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet (unaudited)

December 31, 2016

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consoli- dating adjustments		Hawaiian Electric Consolidated
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	43,956		6,181		3,016		—	—		$	53,153
Plant and equipment	4,241,060			1,255,185		1,109,487		—	—		6,605,732
Less accumulated depreciation	(1,382,972		)	(507,666	)	(478,644	)	—	—		(2,369,282		)
Construction in progress	180,194			12,510		19,038		—	—		211,742
Utility property, plant and equipment, net	3,082,238			766,210		652,897		—	—		4,501,345
Nonutility property, plant and equipment, less accumulated depreciation	5,760			115		1,532		—	—		7,407
Total property, plant and equipment, net	3,087,998			766,325		654,429		—	—		4,508,752
Investment in wholly owned subsidiaries,at equity	550,946			—		—		—	(550,946	)	—
Current assets
Cash and cash equivalents	61,388			10,749		2,048		101	—		74,286
Advances to affiliates	—			3,500		10,000		—	(13,500	)	—
Customer accounts receivable, net	86,373			20,055		17,260		—	—		123,688
Accrued unbilled revenues, net	65,821			13,564		12,308		—	—		91,693
Other accounts receivable, net	7,652			2,445		1,416		—	(6,280	)	5,233
Fuel oil stock, at average cost	47,239			8,229		10,962		—	—		66,430
Materials and supplies, at average cost	29,928			7,380		16,371		—	—		53,679
Prepayments and other	16,502			5,352		2,179		—	(933	)	23,100
Regulatory assets	60,185			3,483		2,364		—	—		66,032
Total current assets	375,088			74,757		74,908		101	(20,713	)	504,141
Other long-term assets
Regulatory assets	662,232			120,863		108,324		—	—		891,419
Unamortized debt expense	151			23		34		—	—		208
Other	43,743			13,573		13,592		—	—		70,908
Total other long-term assets	706,126			134,459		121,950		—	—		962,535
Total assets	$	4,720,158		975,541		851,287		101	(571,659	)	$	5,975,428
Capitalization and liabilities
Capitalization
Common stock equity	$	1,799,787		291,291		259,554		101	(550,946	)	$	1,799,787
Cumulative preferred stock—not subject to mandatory redemption	22,293			7,000		5,000		—	—		34,293
Long-term debt, net	915,437			213,703		190,120		—	—		1,319,260
Total capitalization	2,737,517			511,994		454,674		101	(550,946	)	3,153,340
Current liabilities
Short-term borrowings from affiliate	13,500			—		—		—	(13,500	)	—
Accounts payable	86,369			18,126		13,319		—	—		117,814
Interest and preferred dividends payable	15,761			4,206		2,882		—	(11	)	22,838
Taxes accrued	120,176			28,100		25,387		—	(933	)	172,730
Regulatory liabilities	—			2,219		1,543		—	—		3,762
Other	41,352			7,637		12,501		—	(6,269	)	55,221
Total current liabilities	277,158			60,288		55,632		—	(20,713	)	372,365
Deferred credits and other liabilities
Deferred income taxes	524,433			108,052		100,911		—	263		733,659
Regulatory liabilities	281,112			93,974		31,845		—	—		406,931
Unamortized tax credits	57,844			15,994		15,123		—	—		88,961
Defined benefit pension and other postretirement benefit plans liability	444,458			75,005		80,263		—	—		599,726
Other	49,191			13,024		14,969		—	(263	)	76,921
Total deferred credits and other liabilities	1,357,038			306,049		243,111		—	—		1,906,198
Contributions in aid of construction	348,445			97,210		97,870		—	—		543,525
Total capitalization and liabilities	$	4,720,158		975,541		851,287		101	(571,659	)	$	5,975,428

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Changes in Common Stock Equity (unaudited)

Six months ended June 30, 2017

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Balance, December 31, 2016	$	1,799,787		291,291		259,554		101	(550,946	)	$	1,799,787
Net income for common stock	47,109			8,216		8,323		—	(16,539	)	47,109
Other comprehensive income, net of taxes	499			1		—		—	(1	)	499
Common stock dividends	(43,884		)	(7,748	)	(5,973	)	—	13,721		(43,884		)
Common stock issuance expenses	(5		)	—		(1	)	—	1		(5		)
Balance, June 30, 2017	$	1,803,506		291,760		261,903		101	(553,764	)	$	1,803,506

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Changes in Common Stock Equity (unaudited)

Six months ended June 30, 2016

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Balance, December 31, 2015	$	1,728,325		292,702		263,725		101	(556,528	)	$	1,728,325
Net income for common stock	61,224			9,182		9,630		—	(18,812	)	61,224
Other comprehensive income (loss), net of taxes	261			(1	)	(2	)	—	3		261
Common stock dividends	(46,800		)	(6,604	)	(6,530	)	—	13,134		(46,800		)
Common stock issuance expenses	(4		)	(4	)	—		—	4		(4		)
Balance, June 30, 2016	$	1,743,006		295,275		266,823		101	(562,199	)	$	1,743,006

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows (unaudited)

Six months ended June 30, 2017

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Cash flows from operating activities
Net income	$	47,649		8,483		8,514		—	(16,539	)	$	48,107
Adjustments to reconcile net income to net cash provided by operating activities:
Equity in earnings of subsidiaries	(16,589		)	—		—		—	16,539		(50		)
Common stock dividends received from subsidiaries	13,771			—		—		—	(13,721	)	50
Depreciation of property, plant and equipment	65,445			19,371		11,556		—	—		96,372
Other amortization	1,875			905		1,482		—	—		4,262
Deferred income taxes	15,060			3,590		4,988		—	(39	)	23,599
Allowance for equity funds used during construction	(4,715		)	(249	)	(462	)	—	—		(5,426		)
Other	1,089			699		(173	)	—	—		1,615
Changes in assets and liabilities:
Decrease (increase) in accounts receivable	(5,100		)	1,182		(1,067	)	—	3,256		(1,729		)
Increase in accrued unbilled revenues	(8,819		)	(602	)	(2,482	)	—	—		(11,903		)
Decrease (increase) in fuel oil stock	(4,250		)	94		(1,806	)	—	—		(5,962		)
Increase in materials and supplies	(788		)	(1,472	)	(1,160	)	—	—		(3,420		)
Decrease (increase) in regulatory assets	11,378			(1,575	)	(1,624	)	—	—		8,179
Increase in accounts payable	39,954			3,291		8,392		—	—		51,637
Change in prepaid and accrued income taxes, tax credits and revenue taxes	(29,430		)	(6,290	)	(4,725	)	—	(465	)	(40,910		)
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability	355			26		(79	)	—	—		302
Change in other assets and liabilities	(12,727		)	129		1,807		—	(3,256	)	(14,047		)
Net cash provided by operating activities	114,158			27,582		23,161		—	(14,225	)	150,676
Cash flows from investing activities
Capital expenditures	(153,554		)	(24,744	)	(23,782	)	—	—		(202,080		)
Contributions in aid of construction	14,078			1,870		1,623		—	—		17,571
Other	4,820			619		307		—	504		6,250
Advances from affiliates	—			(600	)	9,000		—	(8,400	)	—
Net cash used in investing activities	(134,656		)	(22,855	)	(12,852	)	—	(7,896	)	(178,259		)
Cash flows from financing activities
Common stock dividends	(43,884		)	(7,748	)	(5,973	)	—	13,721		(43,884		)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(540		)	(267	)	(191	)	—	—		(998		)
Proceeds from issuance of special purpose revenue bonds	162,000			28,000		75,000		—			265,000
Funds transferred for redemption of special purpose revenue bonds	(162,000		)	(28,000	)	(75,000	)	—	—		(265,000		)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	35,590			—		—		—	8,400		43,990
Other	(2,068		)	(357	)	(804	)	—	—		(3,229		)
Net cash used in financing activities	(10,902		)	(8,372	)	(6,968	)	—	22,121		(4,121		)
Net increase (decrease) in cash and cash equivalents	(31,400		)	(3,645	)	3,341		—	—		(31,704		)
Cash and cash equivalents, beginning of period	61,388			10,749		2,048		101	—		74,286
Cash and cash equivalents, end of period	$	29,988		7,104		5,389		101	—		$	42,582

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows (unaudited)

Six months ended June 30, 2016

(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Cash flows from operating activities
Net income	$	61,764		9,449		9,821		—	(18,812	)	$	62,222
Adjustments to reconcile net income to net cash provided by operating activities:
Equity in earnings of subsidiaries	(18,862		)	—		—		—	18,812		(50		)
Common stock dividends received from subsidiaries	13,184			—		—		—	(13,134	)	50
Depreciation of property, plant and equipment	63,044			18,898		11,599		—	—		93,541
Other amortization	1,919			911		963		—	—		3,793
Deferred income taxes	23,954			2,538		5,623		—	3		32,118
Allowance for equity funds used during construction	(2,965		)	(333	)	(438	)	—	—		(3,736		)
Other	1,383			1,611		(12	)	—	—		2,982
Changes in assets and liabilities:
Decrease in accounts receivable	14,177			2,007		729		—	(231	)	16,682
Decrease (increase) in accrued unbilled revenues	(2,941		)	634		(908	)	—	—		(3,215		)
Decrease in fuel oil stock	6,015			924		2,705		—	—		9,644
Increase in materials and supplies	(1,748		)	(708	)	(26	)	—	—		(2,482		)
Decrease (increase) in regulatory assets	(3,974		)	2,138		1,159		—	—		(677		)
Increase in accounts payable	17,150			208		6,069		—	—		23,427
Change in prepaid and accrued income taxes, tax credits and revenue taxes	(21,371		)	(192	)	(6,626	)	—	(3	)	(28,192		)
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability	299			27		(89	)	—	—		237
Change in other assets and liabilities	(11,803		)	11		(659	)	—	231		(12,220		)
Net cash provided by operating activities	139,225			38,123		29,910		—	(13,134	)	194,124
Cash flows from investing activities
Capital expenditures	(152,283		)	(27,436	)	(17,613	)	—	—		(197,332		)
Contributions in aid of construction	12,824			1,605		2,381		—	—		16,810
Other	132			169		30		—	—		331
Advances from affiliates	—			(3,000	)	(11,000	)	—	14,000		—
Net cash used in investing activities	(139,327		)	(28,662	)	(26,202	)	—	14,000		(180,191		)
Cash flows from financing activities
Common stock dividends	(46,800		)	(6,604	)	(6,530	)	—	13,134		(46,800		)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(540		)	(267	)	(191	)	—	—		(998		)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	50,995			—		—		—	(14,000	)	36,995
Other	8			(8	)	—		—	—		—
Net cash provided by (used in) financing activities	3,663			(6,879	)	(6,721	)	—	(866	)	(10,803		)
Net increase (decrease) in cash and cash equivalents	3,561			2,582		(3,013	)	—	—		3,130
Cash and cash equivalents, beginning of period	16,281			2,682		5,385		101	—		24,449
Cash and cash equivalents, end of period	$	19,842		5,264		2,372		101	—		$	27,579