UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

ý QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, ~~2017~~2018

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934



Exact Name of Registrant as	Commission	I.R.S. Employer
Specified in Its Charter	File Number	Identification No.
HAWAIIAN ELECTRIC INDUSTRIES, INC.	1-8503	99-0208097
and Principal Subsidiary
HAWAIIAN ELECTRIC COMPANY, INC.	1-4955	99-0040500

State of Hawaii

(State or other jurisdiction of incorporation or organization)

Hawaiian Electric Industries, Inc. – 1001 Bishop Street, Suite 2900, Honolulu, Hawaii 96813

Hawaiian Electric Company, Inc. – 900 Richards Street, Honolulu, Hawaii 96813

(Address of principal executive offices and zip code)

Hawaiian Electric Industries, Inc. – (808) 543-5662

Hawaiian Electric Company, Inc. – (808) 543-7771

(Registrant’s telephone number, including area code)

Not applicable

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.



Hawaiian Electric Industries, Inc. Yes x No o		Hawaiian Electric Company, Inc. Yes x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).



Hawaiian Electric Industries, Inc. Yes x No o		Hawaiian Electric Company, Inc. Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Securities Exchange Act of 1934.



Hawaiian Electric Industries, Inc.	Large accelerated filer x	Hawaiian Electric Company, Inc.	Large accelerated filer o
	Accelerated filer o		Accelerated filer o
	Non-accelerated filer o		Non-accelerated filer x
	(Do not check if a smaller reporting company)		(Do not check if a smaller reporting company)
	Smaller reporting company o		Smaller reporting company o
	Emerging growth company o		Emerging growth company o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.



Hawaiian Electric Industries, Inc. o		Hawaiian Electric Company, Inc. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).



Hawaiian Electric Industries, Inc. Yes o No x		Hawaiian Electric Company, Inc. Yes o No x

APPLICABLE ONLY TO CORPORATE ISSUERS:

Indicate the number of shares outstanding of each of the issuers’ classes of common stock, as of the latest practicable date.



Class of Common Stock		Outstanding July 27, ~~2017~~2018
Hawaiian Electric Industries, Inc. (Without Par Value)		~~108,785,486~~108,879,245 Shares
Hawaiian Electric Company, Inc. ($6-2/3 Par Value)		~~16,019,785~~16,142,216 Shares (not publicly traded)

Hawaiian Electric Industries, Inc. (HEI) is the sole holder of Hawaiian Electric Company, Inc. (Hawaiian Electric) common stock.

This combined Form 10-Q is separately filed by HEI and Hawaiian Electric. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. No registrant makes any representation as to information relating to the other registrant, except that information relating to Hawaiian Electric is also attributed to HEI.

Hawaiian Electric Industries, Inc. and Subsidiaries

Hawaiian Electric Company, Inc. and Subsidiaries

Form 10-Q—Quarter ended June 30, ~~2017~~2018

TABLE OF CONTENTS



Page No.
ii	Glossary of Terms
iv	Cautionary Note Regarding Forward-Looking Statements

	PART I. FINANCIAL INFORMATION
1	Item 1.	Financial Statements
		Hawaiian Electric Industries, Inc. and Subsidiaries
1		Condensed Consolidated Statements of Income (unaudited) - three and six months ended June 30, ~~2017~~2018 and ~~2016~~2017
2		Condensed Consolidated Statements of Comprehensive Income (unaudited) - three and six months ended June 30, ~~2017~~2018 and ~~2016~~2017
3		Condensed Consolidated Balance Sheets (unaudited) - June 30, ~~2017~~2018 and December 31, ~~2016~~2017
4		Condensed Consolidated Statements of Changes in Shareholders’ Equity (unaudited) - six months ended June 30, ~~2017~~2018 and ~~2016~~2017
5		Condensed Consolidated Statements of Cash Flows (unaudited) - six months ended June 30, ~~2017~~2018 and ~~2016~~2017
		Hawaiian Electric Company, Inc. and Subsidiaries
6		Condensed Consolidated Statements of Income (unaudited) - three and six months ended June 30, ~~2017~~2018 and ~~2016~~2017
6		Condensed Consolidated Statements of Comprehensive Income (unaudited) - three and six months ended June 30, ~~2017~~2018 and ~~2016~~2017
7		Condensed Consolidated Balance Sheets (unaudited) - June 30, ~~2017~~2018 and December 31, ~~2016~~2017
8		Condensed Consolidated Statements of Changes in Common Stock Equity (unaudited) - six months ended June 30, ~~2017~~2018 and ~~2016~~2017
9		Condensed Consolidated Statements of Cash Flows (unaudited) - six months ended June 30, ~~2017~~2018 and ~~2016~~2017
10		Notes to Condensed Consolidated Financial Statements (unaudited)
5962	Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations
5962		HEI consolidated
6366		Electric Utilities
7578		Bank
8486	Item 3.	Quantitative and Qualitative Disclosures About Market Risk
8487	Item 4.	Controls and Procedures

	PART II.	OTHER INFORMATION
8587	Item 1.	Legal Proceedings
8587	Item 1A.	Risk Factors
8688	Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds
8688	Item 5.	Other Information
8789	Item 6.	Exhibits
8890	Signatures

Hawaiian Electric Industries, Inc. and Subsidiaries

Hawaiian Electric Company, Inc. and Subsidiaries

Form 10-Q—Quarter ended June 30, ~~2017~~2018

GLOSSARY OF TERMS



Terms		Definitions
ADIT		Accumulated deferred income tax balances
AES Hawaii		AES Hawaii, Inc.
AFUDC		Allowance for funds used during construction
AOCI		Accumulated other comprehensive income/(loss)
ASC		Accounting Standards Codification
ASB		American Savings Bank, F.S.B., a wholly-owned subsidiary of ASB Hawaii, Inc.
ASB Hawaii		ASB Hawaii, Inc. (formerly American Savings Holdings, Inc.), a wholly owned subsidiary of Hawaiian Electric Industries, Inc. and the parent company of American Savings Bank, F.S.B.
ASU		Accounting Standards Update
CIAC		Contributions in aid of construction
CIP CT-1		Campbell Industrial Park 110 MW combustion turbine No. 1
Company		Hawaiian Electric Industries, Inc. and its direct and indirect subsidiaries, including, without limitation, Hawaiian Electric Company, Inc. and its subsidiaries (listed under Hawaiian Electric); ASB Hawaii, Inc. and its subsidiary, American Savings Bank, F.S.B.; ~~HEI Properties, Inc. (dissolved in 2015~~Pacific Current, LLC and ~~wound up in 2017)~~its subsidiaries, Hamakua Holdings, LLC (and its subsidiary, Hamakua Energy, LLC) and Mauo Holdings, LLC (and its subsidiary, Mauo, LLC); ~~and~~ The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.).; and HEI Properties, Inc. (dissolved in 2015 and wound up in 2017)
Consumer Advocate		Division of Consumer Advocacy, Department of Commerce and Consumer Affairs of the State of Hawaii
CBRE		Community-based renewable energy
DER		Distributed energy resources
D&O		Decision and order from the PUC
DG		~~Distributed generation~~
Dodd-Frank Act		Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010
DOH		Department of Health of the State of Hawaii
DRIP		HEI Dividend Reinvestment and Stock Purchase Plan
~~DSM~~		~~Demand-side management~~
ECAC		Energy cost adjustment clause
ECRC		Energy cost recovery clause
EIP		2010 Equity and Incentive Plan, as amended and restated
EPA		Environmental Protection Agency — federal
EPS		Earnings per share
ERP/EAM		Enterprise Resource Planning/Enterprise Asset Management
EVE		Economic value of equity
Exchange Act		Securities Exchange Act of 1934
FASB		Financial Accounting Standards Board
FDIC		Federal Deposit Insurance Corporation
federal		U.S. Government
FHLB		Federal Home Loan Bank
FHLMC		Federal Home Loan Mortgage Corporation
FNMA		Federal National Mortgage Association
FRB		Federal Reserve Board
GAAP		Accounting principles generally accepted in the United States of America

GLOSSARY OF TERMS, continued



Terms		Definitions
GNMA		Government National Mortgage Association
Hawaii Electric Light		Hawaii Electric Light Company, Inc., an electric utility subsidiary of Hawaiian Electric Company, Inc.
Hawaiian Electric		Hawaiian Electric Company, Inc., an electric utility subsidiary of Hawaiian Electric Industries, Inc. and parent company of Hawaii Electric Light Company, Inc., Maui Electric Company, Limited, HECO Capital Trust III (unconsolidated financing subsidiary), Renewable Hawaii, Inc. and Uluwehiokama Biofuels Corp.
~~HEP~~Hamakua Energy		Hamakua Energy, LLC, an indirect subsidiary of HEI and successor in interest to Hamakua Energy Partners, L.P., an affiliate of Arclight Capital Partners (a Boston based private equity firm focused on energy infrastructure investments) and successor in interest to Encogen Hawaii, L.P.
HEI		Hawaiian Electric Industries, Inc., direct parent company of Hawaiian Electric Company, Inc., ASB Hawaii, Inc., HEI Properties, Inc. (dissolved in 2015 and wound up in 2017) ~~and~~, The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.) and Pacific Current, LLC
HEIRSP		Hawaiian Electric Industries Retirement Savings Plan
HELOC		Home equity line of credit
HPOWER		City and County of Honolulu with respect to a power purchase agreement for a refuse-fired plant
IPP		Independent power producer
Kalaeloa		Kalaeloa Partners, L.P.
KWH		Kilowatthour/s (as applicable)
~~LNG~~		~~Liquefied natural gas~~
LTIP		Long-term incentive plan
Maui Electric		Maui Electric Company, Limited, an electric utility subsidiary of Hawaiian Electric Company, Inc.
~~Merger~~		As provided in the Merger Agreement (see below), merger of NEE Acquisition Sub II, Inc. with and into HEI, with HEI surviving, and then merger of HEI with and into NEE Acquisition Sub I, LLC, with NEE Acquisition Sub I, LLC surviving as a wholly owned subsidiary of NextEra Energy, Inc.
~~Merger Agreement~~		~~Agreement and Plan of Merger by and among HEI, NextEra Energy, Inc., NEE Acquisition Sub II, Inc. and NEE Acquisition Sub I, LLC, dated December 3, 2014 and terminated July 16, 2016~~
MPIR		Major Project Interim Recovery
MSR		Mortgage servicing right
Mauo		Mauo, LLC, an indirect subsidiary of HEI
MW		Megawatt/s (as applicable)
~~NEE~~		~~NextEra Energy, Inc.~~
NEM		Net energy metering
NII		Net interest income
NPBC		Net periodic benefit costs
NPPC		Net periodic pension costs
O&M		Other operation and maintenance
OCC		Office of the Comptroller of the Currency
OPEB		Postretirement benefits other than pensions
Pacific Current		Pacific Current, LLC, a wholly owned subsidiary of HEI and parent company of Hamakua Holdings, LLC and Mauo Holdings, LLC
PIMs		Performance incentive mechanisms
PPA		Power purchase agreement
PPAC		Purchased power adjustment clause
PSIPs		Power Supply Improvement Plans
PUC		Public Utilities Commission of the State of Hawaii
PV		Photovoltaic
RAM		Rate adjustment mechanism
RBA		Revenue balancing account
RFP		Request for proposals
ROACE		Return on average common equity
RORB		Return on rate base
RPS		Renewable portfolio standards
SEC		Securities and Exchange Commission
See		Means the referenced material is incorporated by reference
~~Spin-Off~~Tax Act		~~The previously planned distribution~~2017 Tax Cuts and Jobs Act (H.R. 1, An Act to ~~HEI shareholders of all~~provide for reconciliation pursuant to titles II and V of the ~~common stock of ASB Hawaii immediately prior to~~concurrent resolution on the ~~Merger, which was terminated~~budget for fiscal year 2018)
TDR		Troubled debt restructuring
Trust III		HECO Capital Trust III
Utilities		Hawaiian Electric Company, Inc., Hawaii Electric Light Company, Inc. and Maui Electric Company, Limited
VIE		Variable interest entity

iii

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This report and other presentations made by Hawaiian Electric Industries, Inc. (HEI) and Hawaiian Electric Company, Inc. (Hawaiian Electric) and their subsidiaries contain “forward-looking statements,” which include statements that are predictive in nature, depend upon or refer to future events or conditions and usually include words such as “will,” “expects,” “anticipates,” “intends,” “plans,” “believes,” “predicts,” “estimates” or similar expressions. In addition, any statements concerning future financial performance, ongoing business strategies or prospects or possible future actions are also forward-looking statements. Forward-looking statements are based on current expectations and projections about future events and are subject to risks, uncertainties and the accuracy of assumptions concerning HEI and its subsidiaries (collectively, the Company), the performance of the industries in which they do business and economic, political and market factors, among other things. These forward-looking statements are not guarantees of future performance.

Risks, uncertainties and other important factors that could cause actual results to differ materially from those described in forward-looking statements and from historical results include, but are not limited to, the following:

international, national and local economic and political ~~conditions—including~~conditions--including the state of the Hawaii tourism, defense and construction industries; the strength or weakness of the Hawaii and continental U.S. real estate markets (including the fair value and/or the actual performance of collateral underlying loans held by ASB, which could result in higher loan loss provisions and write-offs); decisions concerning the extent of the presence of the federal government and military in Hawaii; the implications and potential impacts of U.S. and foreign capital and credit market conditions and federal, state and international responses to those conditions; and the potential impacts of global developments (including global economic conditions and uncertainties; ~~the effects of the United Kingdom’s referendum to withdraw from the European Union;~~ unrest; the conflict in Syria; the effects of changes that have or may occur in U.S. policy, such as with respect to immigration and trade; terrorist ~~acts by ISIS or others;~~acts; potential conflict or crisis with North Korea; and potential pandemics);

the effects of future actions or inaction of the U.S. government or related agencies, including those related to the U.S. debt ceiling, monetary policy, trade policy and tariffs, and other policy and regulation changes advanced or proposed by President Trump and his administration;

weather and natural disasters (e.g., hurricanes, earthquakes, tsunamis, lightning strikes, lava flows and the potential effects of climate change, such as more severe storms and rising sea levels), including their impact on the Company's and Utilities' operations and the economy;

the timing and extent of changes in interest rates and the shape of the yield curve;

the ability of the Company and the Utilities to access the credit and capital markets (e.g., to obtain commercial paper and other short-term and long-term debt financing, including lines of credit, and, in the case of HEI, to issue common stock) under volatile and challenging market conditions, and the cost of such financings, if available;

the risks inherent in changes in the value of the Company’s pension and other retirement plan assets and ASB’s securities available for sale;

changes in laws, regulations (including tax regulations), market conditions and other factors that result in changes in assumptions used to calculate retirement benefits costs and funding requirements;

the impact of the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 (Dodd-Frank Act) and of the rules and regulations that the Dodd-Frank Act requires to be promulgated;

increasing competition in the banking industry (e.g., increased price competition for deposits, or an outflow of deposits to alternative investments, which may have an adverse impact on ASB’s cost of funds);

the impacts of the termination of the Merger with NextEra Energy, Inc. (NEE) and the resulting loss of NEE’s resources, expertise and support (e.g., financial and technological), including potentially higher costs and longer lead times to increase levels of renewable energy and to complete projects like Enterprise Resource Planning/Enterprise Asset Management (ERP/EAM) and smart grids, and a higher cost of capital;

the potential delay by the Public Utilities Commission of the State of Hawaii (PUC) in considering (and potential disapproval of actual or proposed) renewable energy proposals and related costs; reliance by the Utilities on outside parties such as the state, independent power producers (IPPs) and developers; and uncertainties surrounding technologies, solar power, wind power, biofuels, environmental assessments required to meet renewable portfolio standards (RPS) goals and the impacts of implementation of the renewable energy proposals on future costs of electricity;

the ability of the Utilities to develop, implement and recover the costs of implementing the Utilities’ action plans included in their updated Power Supply Improvement Plans (PSIPs), Demand Response Portfolio Plan, Distributed Generation Interconnection Plan, Grid Modernization Plans, and business model changes, which have been and are continuing to be developed and updated in response to the orders issued by the PUC, inthe PUC’s April 2014 statement of its ~~April 2014~~ inclinations on the future of Hawaii’s electric utilities and the vision, business strategies and regulatory policy changes required to align the Utilities’ business model with customer interests and the state’s public policy goals, and subsequent orders of the PUC;

capacity and supply constraints or difficulties, especially if generating units (utility-owned or IPP-owned) fail or measures such as demand-side management, ~~(DSM),~~ distributed generation, ~~(DG),~~ combined heat and power or other firm capacity supply-side resources fall short of achieving their forecasted benefits or are otherwise insufficient to reduce or meet peak demand;

fuel oil price changes, delivery of adequate fuel by suppliers and the continued availability to the electric utilities of their energy cost adjustment clauses (ECACs);

the continued availability to the electric utilities or modifications of other cost recovery mechanisms, including the purchased power adjustment clauses (PPACs), rate adjustment mechanisms (RAMs) and pension and postretirement benefits other than pensions (OPEB) tracking mechanisms, and the continued decoupling of revenues from sales to mitigate the effects of declining kilowatthour sales;

the ability of the Utilities to achieve performance incentive mechanisms currently in place;

the impact from the PUC’s implementation of performance-based ratemaking for the Utilities pursuant to Senate Bill No. 2939 SD2, including the potential addition of new performance incentive mechanisms, third party proposals to the PUC’s implementation of PBR, and the implications of not achieving performance incentive goals;

the impact of fuel price volatility on customer satisfaction and political and regulatory support for the Utilities;

the risks associated with increasing reliance on renewable energy, including the availability and cost of non-fossil fuel supplies for renewable energy generation and the operational impacts of adding intermittent sources of renewable energy to the electric grid;

the growing risk that energy production from renewable generating resources may be curtailed and the interconnection of additional resources will be constrained as more generating resources are added to the Utilities' electric systems and as customers reduce their energy usage;

the ability of IPPs to deliver the firm capacity anticipated in their power purchase agreements (PPAs);

the potential that, as IPP contracts near the end of their terms, there may be less economic incentive for the IPPs to make investments in their units to ensure the availability of their units;

the ability of the Utilities to negotiate, periodically, favorable agreements for significant resources such as fuel supply contracts and collective bargaining agreements;

new technological developments that could affect the operations and prospects of the Utilities and ASB or their ~~competitors;~~

~~new technological developments,~~competitors such as the commercial development of energy storage and microgrids ~~that could affect the operations of the Utilities;~~and banking through alternative channels;

cyber security risks and the potential for cyber incidents, including potential incidents at HEI, ~~ASB~~its third-party vendors, and ~~the Utilities~~its subsidiaries (including at ASB branches and electric utility plants) and incidents at data processing centers they use, to the extent not prevented by intrusion detection and prevention systems, anti-virus software, firewalls and other general information technology controls;

any failure in the implementation of the ERP/EAM system could adversely affect the Utilities’ ability to timely and accurately report financial information and make payments to vendors and employees;

federal, state, county and international governmental and regulatory actions, such as existing, new and changes in laws, rules and regulations applicable to HEI, the Utilities and ASB (including changes in taxation, increases in capital requirements, regulatory policy changes, environmental laws and regulations (including resulting compliance costs and risks of fines and penalties and/or liabilities), the regulation of greenhouse gas emissions, governmental fees and assessments (such as Federal Deposit Insurance Corporation assessments), and potential carbon “cap and trade” legislation that may fundamentally alter costs to produce electricity and accelerate the move to renewable generation);

developments in laws, regulations and policies governing protections for historic, archaeological and cultural sites, and plant and animal species and habitats, as well as developments in the implementation and enforcement of such laws, regulations and policies;

discovery of conditions that may be attributable to historical chemical releases, including any necessary investigation and remediation, and any associated enforcement, litigation or regulatory oversight;

decisions by the PUC in rate cases and other proceedings (including the risks of delays in the timing of decisions, adverse changes in final decisions from interim decisions and the disallowance of project costs as a result of adverse regulatory audit reports or otherwise);

decisions by the PUC and by other agencies and courts on land use, environmental and other permitting issues (such as required corrective actions, restrictions and penalties that may arise, such as with respect to environmental conditions or RPS);

potential enforcement actions by the Office of the Comptroller of the Currency (OCC), the Federal Reserve Board (FRB), the Federal Deposit Insurance Corporation (FDIC) and/or other governmental authorities (such as consent orders, required corrective actions, restrictions and penalties that may arise, for example, with respect to compliance deficiencies under existing or new banking and consumer protection laws and regulations or with respect to capital adequacy);

the ability of the Utilities to recover increasing costs and earn a reasonable return on capital investments not covered by RAMs;

the risks associated with the geographic concentration of HEI’s businesses and ASB’s loans, ASB’s concentration in a single product type (i.e., first mortgages) and ASB’s significant credit relationships (i.e., concentrations of large loans and/or credit lines with certain customers);

changes in accounting principles applicable to HEI ~~the Utilities~~ and ~~ASB,~~its subsidiaries, including the adoption of new U.S. accounting standards, the potential discontinuance of regulatory accounting and the effects of potentially required consolidation of variable interest entities (VIEs) or required ~~capital~~capital/finance lease or on-balance-sheet operating lease accounting for PPAs with IPPs;

changes by securities rating agencies in their ratings of the securities of HEI and Hawaiian Electric and the results of financing efforts;

faster than expected loan prepayments that can cause an acceleration of the amortization of premiums on loans and investments and the impairment of mortgage-servicing assets of ASB;

changes in ASB’s loan portfolio credit profile and asset quality which may increase or decrease the required level of provision for loan losses, allowance for loan losses and charge-offs;

changes in ASB’s deposit cost or mix which may have an adverse impact on ASB’s cost of funds;

the final outcome of tax positions taken by HEI ~~the Utilities~~ and ~~ASB;~~its subsidiaries;

the risks of suffering losses and incurring liabilities that are uninsured (e.g., damages to the Utilities’ transmission and distribution system and losses from business interruption) or underinsured (e.g., losses not covered as a result of insurance deductibles or other exclusions or exceeding policy limits);

the ability of the Company’s non-regulated subsidiary, Pacific Current, LLC, to achieve its performance and growth objectives, which in turn could affect its ability to service its non-recourse debt;

the Company’s reliance on third parties and the risk of their non-performance; and

other risks or uncertainties described elsewhere in this report and in other reports (e.g., “Item 1A. Risk Factors” in the Company’s Annual Report on Form 10-K) previously and subsequently filed by HEI and/or Hawaiian Electric with the Securities and Exchange Commission (SEC).

Forward-looking statements speak only as of the date of the report, presentation or filing in which they are made. Except to the extent required by the federal securities laws, HEI, Hawaiian Electric, ASB, Pacific Current and their subsidiaries undertake no obligation to publicly update or revise any forward-looking statements, whether written or oral and whether as a result of new information, future events or otherwise.

PART I - FINANCIAL INFORMATION

Item 1. Financial Statements

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Income (unaudited)


	Three months ended June 30						Six months ended June 30						Three months ended June 30						Six months ended June 30
(in thousands, except per share amounts)	2017			2016			2017			2016			2018			2017			2018			2017
Revenues
Electric utility	$	556,875		$	495,395		$	1,075,486		$	977,447		$	608,126		$	556,875		$	1,178,553		$	1,075,486
Bank	75,329			70,749			148,185			139,589			77,104			75,329			152,523			148,185
Other	77			100			172			168			47			77			75			172
Total revenues	632,281			566,244			1,223,843			1,117,204			685,277			632,281			1,331,151			1,223,843
Expenses
Electric utility	501,828			424,709			971,501			851,435			552,982			500,393			1,072,040			968,643
Bank	50,533			50,525			99,229			99,771			50,187			50,332			100,719			98,833
Other	4,024			5,555			9,355			11,692			3,309			3,754			7,704			8,827
Total expenses	556,385			480,789			1,080,085			962,898			606,478			554,479			1,180,463			1,076,303
Operating income (loss)
Electric utility	55,047			70,686			103,985			126,012			55,144			56,482			106,513			106,843
Bank	24,796			20,224			48,956			39,818			26,917			24,997			51,804			49,352
Other	(3,947		)	(5,455		)	(9,183		)	(11,524		)	(3,262		)	(3,677		)	(7,629		)	(8,655		)
Total operating income	75,896			85,455			143,758			154,306			78,799			77,802			150,688			147,540
Retirement defined benefits expense—other than service costs													(1,564		)	(1,906		)	(3,397		)	(3,782		)
Interest expense, net—other than on deposit liabilities and other bank borrowings	(20,440		)	(17,301		)	(40,008		)	(37,427		)	(22,001		)	(20,440		)	(43,519		)	(40,008		)
Allowance for borrowed funds used during construction	1,143			760			2,032			1,422			1,365			1,143			2,809			2,032
Allowance for equity funds used during construction	3,027			1,997			5,426			3,736			2,983			3,027			6,277			5,426
Income before income taxes	59,626			70,911			111,208			122,037			59,582			59,626			112,858			111,208
Income taxes	20,492			26,310			37,408			44,611			13,055			20,492			25,611			37,408
Net income	39,134			44,601			73,800			77,426			46,527			39,134			87,247			73,800
Preferred stock dividends of subsidiaries	473			473			946			946			473			473			946			946
Net income for common stock	$	38,661		$	44,128		$	72,854		$	76,480		$	46,054		$	38,661		$	86,301		$	72,854
Basic earnings per common share	$	0.36		$	0.41		$	0.67		$	0.71		$	0.42		$	0.36		$	0.79		$	0.67
Diluted earnings per common share	$	0.36		$	0.41		$	0.67		$	0.71		$	0.42		$	0.36		$	0.79		$	0.67
Dividends declared per common share	$	0.31		$	0.31		$	0.62		$	0.62		$	0.31		$	0.31		$	0.62		$	0.62
Weighted-average number of common shares outstanding	108,750			107,962			108,712			107,791			108,842			108,750			108,830			108,712
Net effect of potentially dilutive shares	47			171			157			187			121			47			223			157
Weighted-average shares assuming dilution	108,797			108,133			108,869			107,978			108,963			108,797			109,053			108,869

~~The accompanying notes are an integral part of these condensed consolidated financial statements.~~This report should be read in conjunction with the Notes herein and the Notes to Consolidated Financial Statements appearing in the 2017 Form 10-K.

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (unaudited)

Three months ended June 30 Six months ended June 30
(in thousands) 2017 2016 2017 2016
Net income for common stock $ 38,661
$ 44,128
$ 72,854
$ 76,480
Other comprehensive income (loss), net of taxes:

Net unrealized gains on available-for-sale investment securities:

Net unrealized gains on available-for-sale investment securities arising during the period, net of taxes of $1,334, $1,925, $1,482 and $6,830, respectively 2,021
2,916
2,244
10,344
Reclassification adjustment for net realized gains included in net income, net of taxes of nil, $238, nil and $238, respectively —
(360 ) —
(360 )
Derivatives qualifying as cash flow hedges:

Effective portion of foreign currency hedge net unrealized gains (losses) arising during the period, net of (taxes) benefits of nil, $475, nil and ($163), respectively —
(745 ) —
257
Reclassification adjustment to net income, net of tax benefits of nil, nil, $289 and $35, respectively —
—
454
54
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 of $2,508, $2,362, $5,010 and $4,619, respectively 3,930
3,698
7,851
7,236
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $2,281, $2,166, $4,582 and $4,218, respectively (3,581 ) (3,401 ) (7,194 ) (6,623 )
Other comprehensive income, net of taxes 2,370
2,108
3,355
10,908
Comprehensive income attributable to Hawaiian Electric Industries, Inc. $ 41,031
$ 46,236
$ 76,209
$ 87,388



	Three months ended June 30						Six months ended June 30
(in thousands)	2018			2017			2018			2017
Net income for common stock	$	46,054		$	38,661		$	86,301		$	72,854
Other comprehensive income (loss), net of taxes:
Net unrealized gains (losses) on available-for-sale investment securities:
Net unrealized gains (losses) on available-for-sale investment securities arising during the period, net of tax benefits (taxes) of $1,592, $(1,334), $6,459 and $(1,482), respectively	(4,348		)	2,021			(17,645		)	2,244
Derivatives qualifying as cash flow hedges:
Reclassification adjustment to net income, net of tax benefits of nil, nil, nil and $289, respectively	—			—			—			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 of $1,862, $2,508, $3,654 and $5,010, respectively	5,350			3,930			10,496			7,851
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $1,674, $2,281, $3,277 and $4,582, respectively	(4,827		)	(3,581		)	(9,449		)	(7,194		)
Other comprehensive income (loss), net of taxes	(3,825		)	2,370			(16,598		)	3,355
Comprehensive income attributable to Hawaiian Electric Industries, Inc.	$	42,229		$	41,031		$	69,703		$	76,209

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets (unaudited)


(dollars in thousands)	June 30, 2017			December 31, 2016			June 30, 2018			December 31, 2017
Assets
Cash and cash equivalents	$	210,381		$	278,452		$	254,665		$	261,881
Accounts receivable and unbilled revenues, net	249,539			237,950			299,771			263,209
Available-for-sale investment securities, at fair value	1,302,886			1,105,182			1,409,528			1,401,198
Held-to-maturity investment securities, at amortized cost							62,630			44,515
Stock in Federal Home Loan Bank, at cost	11,706			11,218			10,158			9,706
Loans receivable held for investment, net	4,688,278			4,683,160
Loans held for investment, net							4,721,941			4,617,131
Loans held for sale, at lower of cost or fair value	5,261			18,817			5,248			11,250
Property, plant and equipment, net of accumulated depreciation of $2,508,291 and $2,444,348 at June 30, 2017 and December 31, 2016, respectively	4,726,524			4,603,465
Property, plant and equipment, net of accumulated depreciation of $2,615,259 and $2,553,295 at June 30, 2018 and December 31, 2017, respectively							4,611,949			4,460,248
Regulatory assets	938,277			957,451			860,410			869,297
Other	478,763			447,621			565,614			513,535
Goodwill	82,190			82,190			82,190			82,190
Total assets	$	12,693,805		$	12,425,506		$	12,884,104		$	12,534,160
Liabilities and shareholders’ equity
Liabilities
Accounts payable	$	194,755		$	143,279		$	213,832		$	193,714
Interest and dividends payable	22,124			25,225			27,594			25,837
Deposit liabilities	5,724,386			5,548,929			6,116,109			5,890,597
Short-term borrowings—other than bank	49,789			—			202,857			117,945
Other bank borrowings	188,130			192,618			126,930			190,859
Long-term debt, net—other than bank	1,618,647			1,619,019			1,783,009			1,683,797
Deferred income taxes	750,413			728,806			375,832			388,430
Regulatory liabilities	431,630			410,693			905,216			880,770
Contributions in aid of construction	543,204			543,525
Defined benefit pension and other postretirement benefit plans liability	626,795			638,854			494,541			509,514
Other	434,610			473,512			500,873			521,018
Total liabilities	10,584,483			10,324,460			10,746,793			10,402,481
Preferred stock of subsidiaries - not subject to mandatory redemption	34,293			34,293			34,293			34,293
Commitments and contingencies (Notes 3 and 4)
Shareholders’ equity
Preferred stock, no par value, authorized 10,000,000 shares; issued: none	—			—			—			—
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding: 108,785,486 shares and 108,583,413 shares at June 30, 2017 and December 31, 2016, respectively	1,660,403			1,660,910
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding: 108,879,245 shares and 108,787,807 shares at June 30, 2018 and December 31, 2017, respectively							1,665,901			1,662,491
Retained earnings	444,400			438,972			495,656			476,836
Accumulated other comprehensive loss, net of tax benefits	(29,774		)	(33,129		)	(58,539		)	(41,941		)
Total shareholders’ equity	2,075,029			2,066,753			2,103,018			2,097,386
Total liabilities and shareholders’ equity	$	12,693,805		$	12,425,506		$	12,884,104		$	12,534,160

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Changes in Shareholders’ Equity (unaudited)


	Common stock				Retained			Accumulated other comprehensive						Common stock				Retained			Accumulated other comprehensive
(in thousands)	Shares	Amount			Earnings			income (loss)			Total			Shares	Amount			Earnings			income (loss)			Total
Balance, December 31, 2017														108,788	$	1,662,491		$	476,836		$	(41,941	)	$	2,097,386
Net income for common stock														—	—			86,301			—			86,301
Other comprehensive loss, net of tax benefits														—	—			—			(16,598		)	(16,598		)
Issuance of common stock, net of expenses														91	3,410			—			—			3,410
Common stock dividends														—	—			(67,481		)	—			(67,481		)
Balance, June 30, 2018														108,879	$	1,665,901		$	495,656		$	(58,539	)	$	2,103,018
Balance, December 31, 2016	108,583	$	1,660,910		$	438,972		$	(33,129	)	$	2,066,753		108,583	$	1,660,910		$	438,972		$	(33,129	)	$	2,066,753
Net income for common stock	—	—			72,854			—			72,854			—	—			72,854			—			72,854
Other comprehensive income, net of taxes	—	—			—			3,355			3,355			—	—			—			3,355			3,355
Issuance of common stock, net of expenses	202	(507		)	—			—			(507		)	202	(507		)	—			—			(507		)
Common stock dividends	—	—			(67,426		)	—			(67,426		)	—	—			(67,426		)	—			(67,426		)
Balance, June 30, 2017	108,785	$	1,660,403		$	444,400		$	(29,774	)	$	2,075,029		108,785	$	1,660,403		$	444,400		$	(29,774	)	$	2,075,029
Balance, December 31, 2015	107,460	$	1,629,136		$	324,766		$	(26,262	)	$	1,927,640
Net income for common stock	—	—			76,480			—			76,480
Other comprehensive income, net of taxes	—	—			—			10,908			10,908
Issuance of common stock, net of expenses	727	18,002			—			—			18,002
Common stock dividends	—	—			(66,848		)	—			(66,848		)
Balance, June 30, 2016	108,187	$	1,647,138		$	334,398		$	(15,354	)	$	1,966,182

Hawaiian Electric Industries, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows (unaudited)


	Six months ended June 30						Six months ended June 30
(in thousands)	2017			2016			2018			2017
Cash flows from operating activities
Net income	$	73,800		$	77,426		$	87,247		$	73,800
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property, plant and equipment	100,062			97,148			106,063			100,062
Other amortization	6,101			4,840			20,603			6,101
Provision for loan losses	6,741			9,519			6,304			6,741
Loans receivable originated and purchased, held for sale	(69,595		)	(98,004		)
Proceeds from sale of loans receivable, held for sale	79,944			98,457
Loans originated and purchased, held for sale							(78,313		)	(69,595		)
Proceeds from sale of loans, held for sale							77,382			79,944
Deferred income taxes	17,047			21,738			(9,672		)	17,047
Share-based compensation expense	3,285			2,011			4,414			3,285
Allowance for equity funds used during construction	(5,426		)	(3,736		)	(6,277		)	(5,426		)
Other	246			2,982			(147		)	246
Changes in assets and liabilities
Decrease (increase) in accounts receivable and unbilled revenues, net	(12,394		)	12,894
Decrease (increase) in fuel oil stock	(5,962		)	9,644
Increase in accounts receivable and unbilled revenues, net							(41,526		)	(12,394		)
Increase in fuel oil stock							(19,867		)	(5,962		)
Decrease (increase) in regulatory assets	8,179			(11,752		)	(19,600		)	8,179
Increase in accounts, interest and dividends payable	55,451			20,837			31,784			43,530
Change in prepaid and accrued income taxes, tax credits and utility revenue taxes	(37,954		)	622			(26,558		)	(37,954		)
Increase in defined benefit pension and other postretirement benefit plans liability	420			95
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability							(871		)	420
Change in other assets and liabilities	(33,922		)	(18,878		)	(22,695		)	(33,922		)
Net cash provided by operating activities	186,023			225,843			108,271			174,102
Cash flows from investing activities
Available-for-sale investment securities purchased	(295,510		)	(176,598		)	(133,698		)	(295,510		)
Principal repayments on available-for-sale investment securities	99,663			102,716			108,379			99,663
Proceeds from sale of available-for-sale investment securities	—			16,423
Purchases of held-to-maturity investment securities							(20,450		)	—
Principal repayments of held-to-maturity investment securities							2,270			—
Purchase of stock from Federal Home Loan Bank	(2,868		)	(2,773		)	(7,533		)	(2,868		)
Redemption of stock from Federal Home Loan Bank	2,380			2,233			7,080			2,380
Net increase in loans held for investment	(20,326		)	(155,930		)	(111,521		)	(20,326		)
Proceeds from sale of commercial loans	13,493			14,105			7,149			13,493
Proceeds from sale of real estate acquired in settlement of loans	185			553			589			185
Capital expenditures	(222,246		)	(203,631		)	(259,898		)	(210,325		)
Contributions in aid of construction	17,571			16,810			13,573			17,571
Contributions to low income housing investments							(3,279		)	—
Other	8,216			1,106			5,919			8,216
Net cash used in investing activities	(399,442		)	(384,986		)	(391,420		)	(387,521		)
Cash flows from financing activities
Net increase in deposit liabilities	175,457			206,949			123,137			175,457
Net increase in short-term borrowings with original maturities of three months or less	49,789			12,922			84,881			49,789
Net increase (decrease) in retail repurchase agreements	9,048			(27,158		)
Net increase in retail repurchase agreements							38,446			9,048
Proceeds from other bank borrowings	59,500			55,835			177,000			59,500
Repayments of other bank borrowings	(73,034		)	(84,369		)	(177,000		)	(73,034		)
Proceeds from issuance of long-term debt	265,000			75,000			100,000			265,000
Repayment of long-term debt and funds transferred for redemption of special purpose revenue bonds	(265,000		)	(75,000		)	(878		)	(265,000		)
Withheld shares for employee taxes on vested share-based compensation	(3,787		)	(2,345		)	(996		)	(3,787		)
Net proceeds from issuance of common stock	—			7,668
Common stock dividends	(67,426		)	(55,591		)	(67,481		)	(67,426		)
Preferred stock dividends of subsidiaries	(946		)	(946		)	(946		)	(946		)
Other	(3,253		)	2,908			(230		)	(3,253		)
Net cash provided by financing activities	145,348			115,873			275,933			145,348
Net decrease in cash and cash equivalents	(68,071		)	(43,270		)	(7,216		)	(68,071		)
Cash and cash equivalents, beginning of period	278,452			300,478			261,881			278,452
Cash and cash equivalents, end of period	$	210,381		$	257,208		$	254,665		$	210,381

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Statements of Income (unaudited)


	Three months ended June 30						Six months ended June 30						Three months ended June 30						Six months ended June 30
(in thousands)	2017			2016			2017			2016			2018			2017			2018			2017
Revenues	$	556,875		$	495,395		$	1,075,486		$	977,447		$	608,126		$	556,875		$	1,178,553		$	1,075,486
Expenses
Fuel oil	141,259			91,899			285,529			205,639			171,717			141,259			338,685			285,529
Purchased power	153,067			139,058			280,191			254,917			160,738			153,067			300,648			280,191
Other operation and maintenance	106,374			99,563			206,614			203,471			112,642			104,939			220,252			203,756
Depreciation	48,156			46,760			96,372			93,541			50,361			48,156			100,827			96,372
Taxes, other than income taxes	52,972			47,429			102,795			93,867			57,524			52,972			111,628			102,795
Total expenses	501,828			424,709			971,501			851,435			552,982			500,393			1,072,040			968,643
Operating income	55,047			70,686			103,985			126,012			55,144			56,482			106,513			106,843
Allowance for equity funds used during construction	3,027			1,997			5,426			3,736			2,983			3,027			6,277			5,426
Retirement defined benefits expense—other than service costs													(988		)	(1,435		)	(2,252		)	(2,858		)
Interest expense and other charges, net	(18,214		)	(15,103		)	(35,718		)	(32,411		)	(18,160		)	(18,214		)	(35,854		)	(35,718		)
Allowance for borrowed funds used during construction	1,143			760			2,032			1,422			1,365			1,143			2,809			2,032
Income before income taxes	41,003			58,340			75,725			98,759			40,344			41,003			77,493			75,725
Income taxes	14,860			21,984			27,618			36,537			8,676			14,860			17,851			27,618
Net income	26,143			36,356			48,107			62,222			31,668			26,143			59,642			48,107
Preferred stock dividends of subsidiaries	229			229			458			458			229			229			458			458
Net income attributable to Hawaiian Electric	25,914			36,127			47,649			61,764			31,439			25,914			59,184			47,649
Preferred stock dividends of Hawaiian Electric	270			270			540			540			270			270			540			540
Net income for common stock	$	25,644		$	35,857		$	47,109		$	61,224		$	31,169		$	25,644		$	58,644		$	47,109

HEI owns all of the common stock of Hawaiian Electric. Therefore, per share data with respect to shares of common stock of Hawaiian Electric are not meaningful.

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Statements of Comprehensive Income (unaudited)


	Three months ended June 30						Six months ended June 30						Three months ended June 30						Six months ended June 30
(in thousands)	2017			2016			2017			2016			2018			2017			2018			2017
Net income for common stock	$	25,644		$	35,857		$	47,109		$	61,224		$	31,169		$	25,644		$	58,644		$	47,109
Other comprehensive income (loss), net of taxes:
Derivatives qualifying as cash flow hedges:
Effective portion of foreign currency hedge net unrealized gains (losses) arising during the period, net of (taxes) benefits of nil, $475, nil and ($163), respectively	—			(745		)	—			257
Reclassification adjustment to net income, net of tax benefits of nil, nil, $289 and nil, respectively	—			—			454			—
Reclassification adjustment to net income, net of tax benefits of nil, nil, nil and $289, respectively													—			—			—			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 of $2,306, $2,160, $4,610 and $4,221, respectively	3,621			3,391			7,239			6,627
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $2,281, $2,166, $4,582 and $4,218, respectively	(3,581		)	(3,401		)	(7,194		)	(6,623		)
Other comprehensive income (loss), net of taxes	40			(755		)	499			261
Adjustment for amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits of $1,683, $2,306, $3,297 and $4,610, respectively													4,853			3,621			9,506			7,239
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $1,674, $2,281, $3,277 and $4,582, respectively													(4,827		)	(3,581		)	(9,449		)	(7,194		)
Other comprehensive income, net of taxes													26			40			57			499
Comprehensive income attributable to Hawaiian Electric Company, Inc.	$	25,684		$	35,102		$	47,608		$	61,485		$	31,195		$	25,684		$	58,701		$	47,608

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Balance Sheets (unaudited)


(dollars in thousands, except par value)	June 30, 2017			December 31, 2016			June 30, 2018			December 31, 2017
Assets
Property, plant and equipment
Utility property, plant and equipment
Land	$	53,178		$	53,153		$	52,914		$	53,177
Plant and equipment	6,711,418			6,605,732			6,652,982			6,401,040
Less accumulated depreciation	(2,430,097		)	(2,369,282		)	(2,534,428		)	(2,476,352		)
Construction in progress	272,438			211,742			165,608			263,094
Utility property, plant and equipment, net	4,606,937			4,501,345			4,337,076			4,240,959
Nonutility property, plant and equipment, less accumulated depreciation of $1,233 as of June 30, 2017 and $1,232 as of December 31, 2016	7,410			7,407
Nonutility property, plant and equipment, less accumulated depreciation of $1,253 as of June 30, 2018 and $1,251 as of December 31, 2017							7,581			7,580
Total property, plant and equipment, net	4,614,347			4,508,752			4,344,657			4,248,539
Current assets
Cash and cash equivalents	42,582			74,286			20,860			12,517
Customer accounts receivable, net	126,161			123,688			157,260			127,889
Accrued unbilled revenues, net	103,596			91,693			110,839			107,054
Other accounts receivable, net	3,684			5,233			6,896			7,163
Fuel oil stock, at average cost	72,392			66,430			107,016			86,873
Materials and supplies, at average cost	57,099			53,679			57,941			54,397
Prepayments and other	36,340			23,100			29,240			25,355
Regulatory assets	74,167			66,032			103,566			88,390
Total current assets	516,021			504,141			593,618			509,638
Other long-term assets
Regulatory assets	864,110			891,419			756,844			780,907
Unamortized debt expense	690			208
Other	75,987			70,908			108,595			91,529
Total other long-term assets	940,787			962,535			865,439			872,436
Total assets	$	6,071,155		$	5,975,428		$	5,803,714		$	5,630,613
Capitalization and liabilities
Capitalization
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 16,019,785 shares at June 30, 2017 and December 31, 2016)	$	106,818		$	106,818
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 16,142,216 shares at June 30, 2018 and December 31, 2017)							$	107,634		$	107,634
Premium on capital stock	601,486			601,491			614,667			614,675
Retained earnings	1,095,025			1,091,800			1,131,185			1,124,193
Accumulated other comprehensive income (loss), net of taxes	177			(322		)
Accumulated other comprehensive loss, net of tax benefits							(1,162		)	(1,219		)
Common stock equity	1,803,506			1,799,787			1,852,324			1,845,283
Cumulative preferred stock — not subject to mandatory redemption	34,293			34,293			34,293			34,293
Long-term debt, net	1,318,845			1,319,260			1,418,474			1,318,516
Total capitalization	3,156,644			3,153,340			3,305,091			3,198,092
Commitments and contingencies (Note 3)
Current liabilities
Current portion of long-term debt							49,983			49,963
Short-term borrowings from non-affiliates	43,990			—			91,880			4,999
Accounts payable	162,375			117,814			153,759			159,610
Interest and preferred dividends payable	19,497			22,838			22,684			22,575
Taxes accrued	142,263			172,730
Taxes accrued, including revenue taxes							172,063			199,101
Regulatory liabilities	2,883			3,762			9,787			3,401
Other	53,140			55,221			59,203			59,456
Total current liabilities	424,148			372,365			559,359			499,105
Deferred credits and other liabilities
Deferred income taxes	759,972			733,659			388,875			394,041
Regulatory liabilities	428,747			406,931			895,429			877,369
Unamortized tax credits	91,386			88,961			92,798			90,369
Defined benefit pension and other postretirement benefit plans liability	587,718			599,726			457,953			472,948
Other	79,336			76,921			104,209			98,689
Total deferred credits and other liabilities	1,947,159			1,906,198			1,939,264			1,933,416
Contributions in aid of construction	543,204			543,525
Total capitalization and liabilities	$	6,071,155		$	5,975,428		$	5,803,714		$	5,630,613

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Statements of Changes in Common Stock Equity (unaudited)


	Common stock			Premium on capital			Retained			Accumulated other comprehensive						Common stock			Premium on capital			Retained			Accumulated other comprehensive
(in thousands)	Shares	Amount		stock			earnings			income (loss)			Total			Shares	Amount		stock			earnings			income (loss)			Total
Balance, December 31, 2017																16,142	$	107,634	$	614,675		$	1,124,193		$	(1,219	)	$	1,845,283
Net income for common stock																—	—		—			58,644			—			58,644
Other comprehensive income, net of taxes																—	—		—			—			57			57
Common stock dividends																—	—		—			(51,652		)	—			(51,652		)
Common stock issuance expenses																—	—		(8		)	—			—			(8		)
Balance, June 30, 2018																16,142	$	107,634	$	614,667		$	1,131,185		$	(1,162	)	$	1,852,324
Balance, December 31, 2016	16,020	$	106,818	$	601,491		$	1,091,800		$	(322	)	$	1,799,787		16,020	$	106,818	$	601,491		$	1,091,800		$	(322	)	$	1,799,787
Net income for common stock	—	—		—			47,109			—			47,109			—	—		—			47,109			—			47,109
Other comprehensive income, net of taxes	—	—		—			—			499			499			—	—		—			—			499			499
Common stock dividends	—	—		—			(43,884		)	—			(43,884		)	—	—		—			(43,884		)	—			(43,884		)
Common stock issuance expenses	—	—		(5		)	—			—			(5		)	—	—		(5		)	—			—			(5		)
Balance, June 30, 2017	16,020	$	106,818	$	601,486		$	1,095,025		$	177		$	1,803,506		16,020	$	106,818	$	601,486		$	1,095,025		$	177		$	1,803,506
Balance, December 31, 2015	15,805	$	105,388	$	578,930		$	1,043,082		$	925		$	1,728,325
Net income for common stock	—	—		—			61,224			—			61,224
Other comprehensive income, net of taxes	—	—		—			—			261			261
Common stock dividends	—	—		—			(46,800		)	—			(46,800		)
Common stock issuance expenses	—	—		(4		)	—			—			(4		)
Balance, June 30, 2016	15,805	$	105,388	$	578,926		$	1,057,506		$	1,186		$	1,743,006

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidated Statements of Cash Flows (unaudited)


	Six months ended June 30						Six months ended June 30
(in thousands)	2017			2016			2018			2017
Cash flows from operating activities
Net income	$	48,107		$	62,222		$	59,642		$	48,107
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation of property, plant and equipment	96,372			93,541			100,827			96,372
Other amortization	4,262			3,793			13,021			4,262
Deferred income taxes	23,599			32,118			(8,343		)	23,599
Allowance for equity funds used during construction	(5,426		)	(3,736		)	(6,277		)	(5,426		)
Other	1,615			2,982			978			1,615
Changes in assets and liabilities
Decrease (increase) in accounts receivable	(1,729		)	16,682
Increase in accounts receivable							(34,068		)	(1,729		)
Increase in accrued unbilled revenues	(11,903		)	(3,215		)	(3,785		)	(11,903		)
Decrease (increase) in fuel oil stock	(5,962		)	9,644
Increase in fuel oil stock							(20,143		)	(5,962		)
Increase in materials and supplies	(3,420		)	(2,482		)	(3,544		)	(3,420		)
Decrease (increase) in regulatory assets	8,179			(677		)	(19,600		)	8,179
Increase in accounts payable	51,637			23,427			18,284			39,716
Change in prepaid and accrued income taxes, tax credits and revenue taxes	(40,910		)	(28,192		)	(31,061		)	(40,910		)
Increase in defined benefit pension and other postretirement benefit plans liability	302			237
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability							(1,961		)	302
Change in other assets and liabilities	(14,047		)	(12,220		)	5,866			(14,047		)
Net cash provided by operating activities	150,676			194,124			69,836			138,755
Cash flows from investing activities
Capital expenditures	(202,080		)	(197,332		)	(213,220		)	(190,159		)
Contributions in aid of construction	17,571			16,810			13,573			17,571
Other	6,250			331			4,301			6,250
Net cash used in investing activities	(178,259		)	(180,191		)	(195,346		)	(166,338		)
Cash flows from financing activities
Common stock dividends	(43,884		)	(46,800		)	(51,652		)	(43,884		)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(998		)	(998		)	(998		)	(998		)
Proceeds from issuance of special purpose revenue bonds	265,000			—
Proceeds from issuance of long-term debt							100,000			265,000
Funds transferred for redemption of special purpose revenue bonds	(265,000		)	—			—			(265,000		)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less	43,990			36,995			86,881			43,990
Other	(3,229		)	—			(378		)	(3,229		)
Net cash used in financing activities	(4,121		)	(10,803		)
Net cash provided by (used in) financing activities							133,853			(4,121		)
Net increase (decrease) in cash and cash equivalents	(31,704		)	3,130			8,343			(31,704		)
Cash and cash equivalents, beginning of period	74,286			24,449			12,517			74,286
Cash and cash equivalents, end of period	$	42,582		$	27,579		$	20,860		$	42,582

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS(Unaudited)

~~(Unaudited)~~

Note 1 · Basis of presentation

The accompanying unaudited condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the United States of America (GAAP) for interim financial information, the instructions to SEC Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete financial statements. In preparing the unaudited condensed consolidated financial statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the balance sheet and the reported amounts of revenues and expenses for the period. Actual results could differ significantly from those estimates. The accompanying unaudited condensed consolidated financial statements and the following notes should be read in conjunction with the audited consolidated financial statements and the notes thereto in HEI’s and Hawaiian Electric’s Form 10-K for the year ended December 31, ~~2016~~2017.

In the opinion of HEI’s and Hawaiian Electric’s management, the accompanying unaudited condensed consolidated financial statements contain all material adjustments required by GAAP to fairly state consolidated HEI’s and Hawaiian Electric’s financial positions as of June 30, ~~2017~~2018 and December 31, ~~2016~~2017, and the results of their operations for the three and six months ended June 30, 2018 and 2017 and ~~2016 and their~~ cash flows for the six months ended June 30, ~~2017~~2018 and ~~2016.~~2017. All such adjustments are of a normal recurring nature, unless otherwise disclosed below or in other referenced material. Results of operations for interim periods are not necessarily indicative of results for the full year.

Recent accounting pronouncements.

Revenues from contracts with customers. In May 2014, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The core principle of the guidance in ASU No. 2014-09 is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. To achieve that core principle, an entity should: (1) identify the contract/s with a customer, (2) identify the performance obligations in the contract, (3) determine the transaction price, (4) allocate the transaction price to the performance obligations in the contract, and (5) recognize revenue when, or as, the entity satisfies a performance obligation. ASU No. 2014-09 also requires disclosure of the nature, amount, timing and uncertainty of revenue and cash flows arising from contracts with customers.

As of June 30, 2017, the Company has identified its revenue streams from, and performance obligations related to, contracts with customers and has performed an analysis of these revenue streams for the impacts of Topic 606. The majority of the revenue subject to Topic 606 is the Utilities’ electric sales revenue and the Company and Hawaiian Electric do not expect a material impact on the timing or pattern of revenue recognition upon adoption of ASU No. 2014-09. The Company and Hawaiian Electric ~~expect changes to the presentation and disclosure of revenues. The Company plans to adopt~~adopted ASU No. 2014-09 (and subsequently issued revenue-related ASUs, as applicable) in the first quarter of ~~2018 using~~2018. There was no cumulative effect adjustment and no impact on the ~~modified retrospective approach. The Company continues~~timing or pattern of revenue recognition, but ASU No. 2014-09 required changes with respect to ~~monitor developments in industry-specific application guidance~~the Company’s and ~~evaluate further impacts of Topic 606.~~Hawaiian Electric’s revenue disclosures. See Note 7.

Financial instruments. In January 2016, the FASB issued ASU No. 2016-01, “Financial Instruments-Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities,” which, among other things:

Requires equity investments (except those accounted for under the equity method of accounting, or those that result in consolidation of the investee) to be measured at fair value with changes in fair value recognized in net income.

Requires public business entities to use the exit price notion when measuring the fair value of financial instruments for disclosure purposes.

Requires separate presentation of financial assets and financial liabilities by measurement category and form of financial asset (i.e., securities or loans and receivables).

Eliminates the requirement for public business entities to disclose the method(s) and significant assumptions used to estimate the fair value that is required to be disclosed for financial instruments measured at amortized cost.

The Company ~~plans to adopt~~adopted ASU No. 2016-01 in the first quarter of 2018 and ~~expects changes to disclosures, but otherwise believes~~ the impact of adoption ~~will~~was not be material to the Company’s and Hawaiian Electric’s consolidated financial statements.

Cash flows. In August 2016, the FASB issued ASU No. 2016-15, “Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments,” which provides guidance on eight specific cash flow issues - debt prepayment or debt extinguishment costs, settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate-owned life insurance policies (including bank-owned life insurance policies), distributions received from equity method investees, beneficial interests in securitization transactions, and separately identifiable cash flows and application of the predominance principle.

The Company adopted ASU No. 2016-15 in the first quarter of 2018 using a retrospective transition method and there was no impact from the adoption to the Company’s and Hawaiian Electric’s consolidated statements of cash flows.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Restricted cash. In November 2016, the FASB issued ASU No. 2016-18, “Statement of Cash Flows (Topic 230): Restricted Cash,” which requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents.

The Company adopted ASU No. 2016-18 in the first quarter of 2018 using a retrospective transition method and the impact of adoption was not material to the Company’s and Hawaiian Electric’s consolidated statements of cash flows.

Definition of a Business. In January 2017, the FASB issued ASU No. 2017-01, “Business Combinations—Clarifying the Definition of a Business.” This update clarifies the definition of a business and adds guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The Company adopted ASU No. 2017-01 in the first quarter of 2018 and the impact of adoption was not material to the Company’s and Hawaiian Electric’s consolidated financial statements.

Net periodic pension cost and net periodic postretirement benefit cost. In March 2017, the FASB issued ASU No. 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” which requires that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. It also requires the other components of net periodic pension cost (NPPC) and net periodic postretirement benefit cost (NPBC) as defined in paragraphs 715-30-35-4 and 715-60-35-9 to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations. Additionally, only the service cost component is eligible for capitalization under GAAP, when applicable.

The Company adopted ASU No. 2017-07 in the first quarter of 2018: (1) retrospectively for the presentation in the income statement of the service cost component and the other components of NPPC and NPBC, and (2) prospectively for the capitalization in assets of the service cost component of NPPC and NPBC for Hawaiian Electric and its subsidiaries. HEI and ASB do not capitalize pension and OPEB costs.

In settlement agreements in the 2018 Maui Electric, 2017 Hawaiian Electric and 2016 Hawaii Electric Light rate cases, Maui Electric, Hawaiian Electric and Hawaii Electric Light, respectively, and the Consumer Advocate agreed to the deferral of the non-service cost components of NPPC and NPBC, which would have been capitalized prior to ASU No. 2017-07, as part of the pension tracking mechanism. The PUC approved this treatment in the final decision and order (D&O) in the Hawaiian Electric and Hawaii Electric Light rate cases. The treatment under the settlement agreements was followed beginning in 2018 until each utility’s next rate case. In each utility’s next rate case, rates established would include recovery of the deferred non-service cost components and seek to adopt the capitalization policy which reflects the requirements of ASU No. 2017-07 (i.e., only the service cost components of NPPC and NPBC will be capitalized).

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Thus, the adoption of ASU 2017-07 in the first quarter of 2018 does not have a net income impact. The following table summarizes the impact to the prior period financial statements of the adoption of ASU No. 2017-07:



	Three months ended June 30, 2017									Six months ended June 30, 2017
(in thousands)	As previously filed			Adjustment from adoption of ASU No. 2017-07			As currently reported			As previously filed			Adjustment from adoption of ASU No. 2017-07			As currently reported
HEI Condensed Consolidated Income Statement
Expenses
Electric utility	$	501,828		$	(1,435	)	$	500,393		$	971,501		$	(2,858	)	$	968,643
Bank	50,533			(201		)	50,332			99,229			(396		)	98,833
Other	4,024			(270		)	3,754			9,355			(528		)	8,827
Total expenses	556,385			(1,906		)	554,479			1,080,085			(3,782		)	1,076,303
Operating income
Electric utility	55,047			1,435			56,482			103,985			2,858			106,843
Bank	24,796			201			24,997			48,956			396			49,352
Other	(3,947		)	270			(3,677		)	(9,183		)	528			(8,655		)
Total operating income	75,896			1,906			77,802			143,758			3,782			147,540
Retirement defined benefits expense--other than service costs	—			(1,906		)	(1,906		)	—			(3,782		)	(3,782		)
Hawaiian Electric Condensed Consolidated Income Statement
Other operation and maintenance	106,374			(1,435		)	104,939			206,614			(2,858		)	203,756
Total expense	501,828			(1,435		)	500,393			971,501			(2,858		)	968,643
Operating income	55,047			1,435			56,482			103,985			2,858			106,843
Retirement defined benefits expense--other than service costs	—			(1,435		)	(1,435		)	—			(2,858		)	(2,858		)
Hawaiian Electric Condensed Consolidating Income Statement (in Note 3)
Hawaiian Electric (parent only)
Other operation and maintenance	70,961			(1,302		)	69,659			138,239			(2,587		)	135,652
Total expense	357,575			(1,302		)	356,273			690,763			(2,587		)	688,176
Operating income	36,839			1,302			38,141			66,494			2,587			69,081
Retirement defined benefits expense--other than service costs	—			(1,302		)	(1,302		)	—			(2,587		)	(2,587		)
Hawaii Electric Light
Other operation and maintenance	17,558			85			17,643			33,074			168			33,242
Total expense	72,903			85			72,988			141,400			168			141,568
Operating income	8,807			(85		)	8,722			19,292			(168		)	19,124
Retirement defined benefits expense--other than service costs	—			85			85			—			168			168
Maui Electric
Other operation and maintenance	17,855			(218		)	17,637			35,301			(439		)	34,862
Total expense	71,350			(218		)	71,132			139,338			(439		)	138,899
Operating income	9,415			218			9,633			18,220			439			18,659
Retirement defined benefits expense--other than service costs	—			(218		)	(218		)	—			(439		)	(439		)
ASB Statements of Income Data (in Note 4)
Compensation and employee benefits	24,742			(201		)	24,541			47,979			(396		)	47,583
Other expense	4,705			201			4,906			9,016			396			9,412

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Derivatives and Hedging. In August 2017, the FASB issued ASU No. 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities,” which is intended to improve and simplify accounting rules around hedge accounting. The amendments in ASU No. 2017-12 improve the financial reporting of hedging relationships to better portray the economic results of an entity’s risk management activities and financial reporting for hedging relationships through changes to both the designation and measurement guidance for qualifying hedging relationships and the presentation of hedge results in the financial statements. The amendments also expand and refine hedge accounting for both nonfinancial and financial risk components and align the recognition and presentation of the effects of the hedging instrument and the hedged item in the financial statements. For public business entities, the new guidance is effective for annual periods beginning after December 15, 2018, including interim periods within those annual periods, but early adoption is permitted. The Company early adopted ASU No. 2017-12 in the second quarter of 2018, with an effective date of April 1, 2018, and the adoption did not have a material impact on the Company’s consolidated financial statements.

Leases. In February 2016, the FASB issued ASU No. 2016-02, “Leases (Topic 842),” which requires that lessees recognize a liability to make lease payments (the lease liability) and a right-of-use asset, representing its right to use the underlying asset for the lease term, for all leases (except short-term leases) at the commencement date. For leases with a term of 12 months or less, a lessee is permitted to make an accounting policy election and recognize lease expense for such leases generally on a straight-line basis over the lease term. For finance leases, a lessee is required to recognize interest on the lease liability separately from amortization of the right-of-use asset in the ~~condensed consolidated~~ statement of income. For operating leases, a lessee is required to recognize a single lease cost, calculated so that the cost of the lease is allocated over the lease term on a generally straight-line basis.

The Company plans to adopt ASU No. 2016-02 in the first quarter of 2019 and ~~has not yet determined~~is currently analyzing the ~~method or~~potential impact of ~~adoption.~~

~~Stock compensation. In March 2016,~~adoption, including the ~~FASB issued~~impact of electing certain practical expedients available under the standard. The Company has reviewed its agreements and has compiled a preliminary inventory of its operating leases and other arrangements that meet the definition of a lease under the new standard. The Company is in the process of analyzing the measurement provisions of the new standard and their impact to its existing lease arrangements that fall within the scope of ASU No. ~~2016-09, “Compensation-Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting,” which simplifies several aspects of the accounting~~ ~~for share-based payment transactions.~~

The Company adopted ASU No. 2016-09 in the first quarter of 2017. From January 1, 2017, all excess tax benefits and tax deficiencies are recognized as income tax expense or benefit in the income statement. From January 1, 2017, no excess tax benefits or deficiencies are included in determining the assumed proceeds under the treasury stock method of calculating diluted EPS. As of January 1, 2017, HEI adopted an accounting policy to account for forfeitures when they occur.

From January 1, 2017, HEI retrospectively applied the cashflow guidance for taxes paid (equivalent to the value of withheld shares for tax withholding purposes) and excess tax benefits. Excess tax benefits will be classified along with other income tax cash flows as an operating activity and the cash payments made to taxing authorities on the employees’ behalf for withheld shares are classified as financing activities on the HEI unaudited condensed consolidated statements of cash flows for all periods that are presented.2016-02.

Credit ~~Losses~~losses. In June 2016, the FASB issued ASU No. 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments,” which is intended to improve financial reporting by requiring timelier recording of credit losses on loans and other financial instruments held by financial institutions and other organizations. ASU No. 2016-13 requires the measurement of all expected credit losses for financial assets held at the reporting date (based on historical experience, current conditions and reasonable and supportable forecasts) and enhanced disclosures to help financial statement users better understand significant estimates and judgments used in estimating credit losses, as well as the credit quality and underwriting standards of an organization’s portfolio. In addition, ASU No. 2016-13 amends the accounting for credit losses on available-for-sale (AFS) debt securities and purchased financial assets with credit deterioration. The other-than-temporary impairment model of accounting for credit losses on AFS debt securities will be replaced with an estimate of expected credit losses only when the fair value is below the amortized cost of the asset. The length of time the fair value of an AFS debt security has been below the amortized cost will no longer impact the determination of whether a credit loss exists. The AFS debt security model will also require the use of an allowance to record the estimated losses (and subsequent recoveries). The accounting for the initial recognition of the estimated expected credit losses for purchased financial assets with credit deterioration would be recognized through an allowance for credit losses with an offset to the cost basis of the related financial asset at acquisition (i.e., there is no impact to net income at initial recognition).

The Company plans to adopt ASU No. 2016-13 in the first quarter of ~~2020~~2020. The guidance is to be applied on a modified retrospective basis with the cumulative effect of initially applying the amendments recognized in retained earnings at the date of initial application. The Company has assembled a project team that meets regularly to evaluate the provisions of this ASU, identify additional data requirements necessary and determine an approach for implementation. The team has ~~not yet determined~~assigned roles and responsibilities and developed key tasks to complete and a general timeline to be followed. The Company is evaluating the ~~impact~~effect that this ASU will have on the consolidated financial statements and disclosures. Economic conditions and the composition of ~~adoption.~~the Company’s loan portfolio at the time of adoption will influence the extent of the adopting accounting adjustment.

~~Cash Flows~~. ~~In August 2016, the FASB issued ASU No. 2016-15, “Statement~~Condensed Consolidated Statements of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments,” which provides guidance on eight specific cash flow issues - debt prepayment or debt extinguishment costs, settlement of zero-coupon debt instruments or other debt instruments with coupon interest rates that are insignificant in relationerror. Subsequent to the ~~effective interest rate~~issuance of interim Condensed Consolidated Financial Statements (unaudited) for the ~~borrowing, contingent consideration payments made after a business combination, proceeds from~~quarter ended June 30, 2017, the ~~settlement of insurance claims, proceeds from~~Company and the settlement of corporate-owned life insurance policies (including bank-owned life insurance policies), distributions received from equity method investees, beneficial interests in securitization transactions, and separately identifiable cash flows and application of the predominance principle.

~~The Company plans to adopt ASU No. 2016-15 in the first quarter of 2018 using a retrospective transition method and has not yet determined the impact of adoption.~~

~~Restricted cash. In November 2016, the FASB issued ASU No. 2016-18, “Statement~~Utilities identified an error within their previously reported interim Condensed Consolidated Statements of Cash Flows ~~(Topic 230): Restricted~~(unaudited). The timing of certain capital expenditure payments, including those that had retainage balances or were related to certain capitalized amounts were not reflected timely. The Company and the Utilities have evaluated the effect of the error, both qualitatively and quantitatively, and concluded that it is immaterial to their respective previously issued condensed consolidated financial statements. For the six months ended June 30, 2017, the correction of this error resulted in decreases in Net Cash” which requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash or restricted cash equivalents. Provided by Operating Activities

~~The~~NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

(impacting the change in Accounts, Interest and Dividends Payable for the Company ~~plans~~and Accounts Payable for the Utilities) and Net Cash Used in Investing Activities (impacting the Capital Expenditures for the Company and the Utilities) of $12 million.

Reclassifications. Reclassifications made to ~~adopt ASU No. 2016-18~~prior year-end financial statements to conform to 2018 presentation include a reclassification of contributions in aid of construction (CIAC) balances to “Property, plant and equipment, net” and “Total property, plant and equipment, net” for the ~~first quarter of 2018 using a retrospective transition method and believes the impact of adoption will not be material to the Company’s~~Company and Hawaiian ~~Electric’s consolidated statements of cash flows.~~

~~Goodwill impairment. In January 2017,~~Electric, respectively, which reduced the FASB issued ASU No. 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” Prior to the adoption of ASU No. 2017-04, an entity was required to perform a two-step test to determine the amount, if any, of goodwill impairment. In Step 1, an entity compared the fair value of a reporting unit with its carrying amount, including goodwill. If the carrying amountamounts of the reporting unit exceeded its fair value, the entity performed Step 2 and compared the implied fair value of goodwill with the carrying amount of that goodwill for that reporting unit. An impairment charge equal to the amount by which the carrying amount of goodwill for the reporting unit exceeded the implied fair value of that goodwill would then be recorded. ASU No. 2017-04 removes the second step of the test. An entity will apply a one-step quantitative test and record the amount of goodwill impairment as the excess of a reporting unit's carrying amount over its fair value. ASU No. 2017-04 does not amend the optional qualitative assessment of goodwill impairment.respective balances.

The Company plans to adopt ASU No. 2017-04 prospectively in the fourth quarter of 2017 and believes the impact of adoption will not be material to the Company’s and Hawaiian Electric’s consolidated financial statements.

~~Net periodic pension cost and net periodic postretirement benefit cost~~. In March 2017, the FASB issued ASU No. 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” which requires that an employer report the service cost component in the same line item or items as other compensation costs arising from services rendered by the pertinent employees during the period. It also requires the other components of net periodic pension cost and net periodic postretirement benefit cost as defined in paragraphs 715-30-35-4 and 715-60-35-9 to be presented in the income statement separately from the service cost component and outside a subtotal of income from operations. Additionally, only the service cost component is eligible for capitalization under GAAP, when applicable.

~~The Company plans to adopt ASU No. 2017-07 in the first quarter of 2018 and has not yet determined the impact of adoption.~~

Note 2 · Segment financial information


(in thousands)	Electric utility		Bank		Other			Total		Electric utility		Bank		Other			Total
Three months ended June 30, 2018
Revenues from external customers										$	608,112	$	77,104	$	61		$	685,277
Intersegment revenues (eliminations)										14		—		(14		)	—
Revenues										$	608,126	$	77,104	$	47		$	685,277
Income (loss) before income taxes										$	40,344	$	26,514	$	(7,276	)	$	59,582
Income taxes (benefit)										8,676		5,953		(1,574		)	13,055
Net income (loss)										31,668		20,561		(5,702		)	46,527
Preferred stock dividends of subsidiaries										499		—		(26		)	473
Net income (loss) for common stock										$	31,169	$	20,561	$	(5,676	)	$	46,054
Six months ended June 30, 2018
Revenues from external customers										$	1,178,526	$	152,523	$	102		$	1,331,151
Intersegment revenues (eliminations)										27		—		(27		)	—
Revenues										$	1,178,553	$	152,523	$	75		$	1,331,151
Income (loss) before income taxes										$	77,493	$	51,014	$	(15,649	)	$	112,858
Income taxes (benefit)										17,851		11,493		(3,733		)	25,611
Net income (loss)										59,642		39,521		(11,916		)	87,247
Preferred stock dividends of subsidiaries										998		—		(52		)	946
Net income (loss) for common stock										$	58,644	$	39,521	$	(11,864	)	$	86,301
Total assets (at June 30, 2018)										$	5,803,714	$	6,983,583	$	96,807		$	12,884,104
Three months ended June 30, 2017
Revenues from external customers	$	556,836	$	75,329	$	116		$	632,281	$	556,836	$	75,329	$	116		$	632,281
Intersegment revenues (eliminations)	39		—		(39		)	—		39		—		(39		)	—
Revenues	$	556,875	$	75,329	$	77		$	632,281	$	556,875	$	75,329	$	77		$	632,281
Income (loss) before income taxes	$	41,003	$	24,796	$	(6,173	)	$	59,626	$	41,003	$	24,796	$	(6,173	)	$	59,626
Income taxes (benefit)	14,860		8,063		(2,431		)	20,492		14,860		8,063		(2,431		)	20,492
Net income (loss)	26,143		16,733		(3,742		)	39,134		26,143		16,733		(3,742		)	39,134
Preferred stock dividends of subsidiaries	499		—		(26		)	473		499		—		(26		)	473
Net income (loss) for common stock	$	25,644	$	16,733	$	(3,716	)	$	38,661	$	25,644	$	16,733	$	(3,716	)	$	38,661
Six months ended June 30, 2017
Revenues from external customers	$	1,075,402	$	148,185	$	256		$	1,223,843	$	1,075,402	$	148,185	$	256		$	1,223,843
Intersegment revenues (eliminations)	84		—		(84		)	—		84		—		(84		)	—
Revenues	$	1,075,486	$	148,185	$	172		$	1,223,843	$	1,075,486	$	148,185	$	172		$	1,223,843
Income (loss) before income taxes	$	75,725	$	48,956	$	(13,473	)	$	111,208	$	75,725	$	48,956	$	(13,473	)	$	111,208
Income taxes (benefit)	27,618		16,410		(6,620		)	37,408		27,618		16,410		(6,620		)	37,408
Net income (loss)	48,107		32,546		(6,853		)	73,800		48,107		32,546		(6,853		)	73,800
Preferred stock dividends of subsidiaries	998		—		(52		)	946		998		—		(52		)	946
Net income (loss) for common stock	$	47,109	$	32,546	$	(6,801	)	$	72,854	$	47,109	$	32,546	$	(6,801	)	$	72,854
Total assets (at June 30, 2017)	$	6,071,155	$	6,610,877	$	11,773		$	12,693,805
Three months ended June 30, 2016
Revenues from external customers	$	495,349	$	70,749	$	146		$	566,244
Intersegment revenues (eliminations)	46		—		(46		)	—
Revenues	$	495,395	$	70,749	$	100		$	566,244
Income (loss) before income taxes	$	58,340	$	20,224	$	(7,653	)	$	70,911
Income taxes (benefit)	21,984		6,939		(2,613		)	26,310
Net income (loss)	36,356		13,285		(5,040		)	44,601
Preferred stock dividends of subsidiaries	499		—		(26		)	473
Net income (loss) for common stock	$	35,857	$	13,285	$	(5,014	)	$	44,128
Six months ended June 30, 2016
Revenues from external customers	$	977,394	$	139,589	$	221		$	1,117,204
Intersegment revenues (eliminations)	53		—		(53		)	—
Revenues	$	977,447	$	139,589	$	168		$	1,117,204
Income (loss) before income taxes	$	98,759	$	39,818	$	(16,540	)	$	122,037
Income taxes (benefit)	36,537		13,860		(5,786		)	44,611
Net income (loss)	62,222		25,958		(10,754		)	77,426
Preferred stock dividends of subsidiaries	998		—		(52		)	946
Net income (loss) for common stock	$	61,224	$	25,958	$	(10,702	)	$	76,480
Total assets (at December 31, 2016)	$	5,975,428	$	6,421,357	$	28,721		$	12,425,506
Total assets (at December 31, 2017)										$	5,630,613	$	6,798,659	$	104,888		$	12,534,160

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Intercompany electricity sales of the Utilities to the bank and “other” segments are not eliminated because those segments would need to purchase electricity from another source if it were not provided by the Utilities and the profit on such sales is nominal.

Bank fees that ASB charges the Utilities and “other” segments are not eliminated because those segments would pay fees to another financial institution if they were to bank with another institution and the profit on such fees is nominal.

Hamakua Energy’s sales to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation. Hamakua Energy's profit on electricity sales to Hawaii Electric Light is not required to be eliminated because the PPA was approved by the PUC and it is probable that, through the ratemaking process, future revenue from Hawaii Electric Light’s sale of the electricity will approximate its purchase price from Hamakua Energy under the PPA.

Note 3 · 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. For the second quarters of 2018 and 2017 and the six months ended June 30, 2018 and 2017, the Utilities’ revenues include recovery of revenue taxes of approximately $54 million, $50 million, $105 million and $96 million, respectively, which amounts are included in “Taxes, other than income taxes” expense, in the unaudited condensed consolidated statements of income. However, the ~~Utilities’~~Utilities pay revenue ~~tax payments~~taxes to the taxing authorities in the period ~~are~~ based on (1) the prior year’s billed revenues (in the case of public service company taxes and PUC fees) in the current year or on(2) 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.~~ after year-end.

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 2,000,000 6.50% 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 have the power to direct the activities that most significantly impact the economic performance of Trust III nor the obligation to absorb ~~the majority of the variability of~~its expected losses, if any, that could potentially be significant to 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~~2018 and December 31, ~~2016~~2017 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, 2018 and 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~~2018, the Utilities had five ~~power purchase agreements (PPAs)~~PPAs for firm capacity and other PPAs with independent power producers (IPPs) and Schedule Q providers ~~(e.g.~~(i.e., customers with cogeneration and/or power production facilities who buy power from or sell power to the Utilities), none of which ~~are~~is currently required to be consolidated as VIEs.

~~Some~~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 the predecessor of 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 the predecessor of 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 the predecessor of Hamakua Energy in its unaudited condensed consolidated financial statements. In November 2017, HEI acquired the Hamakua project through Hamakua Energy, an indirect subsidiary of Pacific Current, and has consolidated it in HEI’s unaudited condensed consolidated financial statements since the acquisition.

For the other PPAs with IPPs, the Utilities have concluded that the consolidation of the IPPs ~~provided sufficient information for Hawaiian Electric to determine that the IPP~~ was not ~~a VIE,~~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 ~~was either~~the IPPs were considered a ~~“business” or~~ “governmental organization,” and thus excluded from the scope of accounting standards for VIEs. ~~Other~~Two IPPs of as-available energy declined to provide the information necessary for ~~Hawaiian Electric~~Utilities 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~~both 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~~VIEs 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.IPP.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

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~~Purchases from all IPPs were as follows:


	Three months ended June 30				Six months ended June 30				Three months ended June 30				Six months ended June 30
(in millions)	2017		2016		2017		2016		2018		2017		2018		2017
Kalaeloa	$	48	$	36	$	88	$	65	$	52	$	48	$	92	$	88
AES Hawaii	35		36		64		74		32		35		69		64
HPOWER	16		17		33		33		17		16		32		33
Puna Geothermal Venture	10		5		18		12		4		10		15		18
HEP	10		4		17		15
Hamakua Energy									15		10		22		17
Other IPPs ¹	34		41		60		56		41		34		71		60
Total IPPs	$	153	$	139	$	280	$	255	$	161	$	153	$	301	$	280


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

Kalaeloa Partners, L.P. ~~In October~~Under a 1988 PPA, as amended, Hawaiian Electric ~~entered into a PPA with Kalaeloa, subsequently approved by the PUC, which provided that Hawaiian Electric would~~is committed to purchase ~~180 megawatts (MW)~~208 MW of firm capacity ~~for a period of 25 years beginning in May 1991. In October 2004,~~from Kalaeloa. 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~~currently 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~~faith, but would end 60 days after either party notifies the other in writing that negotiations have terminated. Hawaiian Electric and Kalaeloa have agreed that neither party will terminate the PPA prior to October 31, 2018. This agreement contemplates continued negotiations between the parties and accounts for time needed for PUC approval of a negotiated resolution.

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~~settlement agreement to stay the arbitration proceeding. The ~~Settlement Agreement~~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~~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.~~continued. In February 2018, Hawaiian Electric reached agreement with AES Hawaii on Amendment No. 4, which was submitted to the PUC for approval in April 2018. Amendment No. 4, among other things, provides (1) that AES Hawaii will make certain operational commitments to improve reliability, (2) for inclusion of AES Hawaii in the Utilities’ greenhouse gas partnership, (3) provisions to allow AES Hawaii to reduce coal combustion by modifying its fuel consumption to include biomass upon approval by Hawaiian Electric, and (4) for release of an option agreement by Hawaiian Electric for land owned by AES Hawaii. Amendment No. 4 includes a stay of the arbitration proceeding pending review by the PUC. If approved by the PUC, Amendment No. 4 will resolve AES Hawaii’s claims. In June 2018, the PUC issued an order suspending the Amendment No. 4 docket pending a DOH decision on AES’ request for approval of its Emission Reduction Plan and partnership with Hawaiian Electric.

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~~Under 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,

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

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. On August 25, 2017, the PUC’s approval was appealed by a third party. The appeal is still pending. 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~~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.~~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,~~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~~benefits associated with the system over its 12-year service life. The ~~decision and order (D&O)~~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, in September 2017, the Utilities ~~are required to file~~filed a bottom-up, low-level analysis of the project’s ~~benefits;~~benefits and performance metrics and tracking mechanism for passing the project’s benefits on to ~~customers by September 2017;~~customers.

On November 30, 2017, the PUC issued an order, which, among other things, directed the Utilities to file a position statement regarding the reasonableness of the project, a reworked low-level benefits analysis and ~~monthly~~initial details of the metrics that will be used to demonstrate the achievement of benefits. On December 18, 2017, the Utilities filed their response to the order, re-affirming the need for the project and guaranteed minimum level of $244 million in benefits to customers. The response further noted that in Hawaiian Electric’s 2017 test year rate case, Hawaiian Electric and the Consumer Advocate have agreed in principle to a “rate case-centric” approach for a benefits delivery mechanism pending PUC approval. On January 4, 2018, the Consumer Advocate filed a statement of position (SOP) on the Utilities’ response, stating that it does not recommend revocation of the PUC’s prior conditional approval of the project or reductions to the previously ordered cost caps, and continues to recommend the use of a rate case-centric approach to facilitate pass through of the system’s benefits to customers. The Utilities filed a response to the Consumer Advocate’s SOP on January 11, 2018, noting among other things that the Consumer Advocate’s SOP is in general alignment with the Utilities’ position on the project. 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~~project continue to be ~~reviewed by~~filed. The parties have reached substantive agreement regarding the ~~PUC and Consumer Advocate.~~ approach for delivering system benefits to customers, but are still in the process of developing an annual enterprise systems benefits report.

The ERP/EAM Implementation Project is ~~on schedule. The project is~~ expected to go live byin October 1, 2018. As of June 30, ~~2017,~~2018, the Project incurred costs of ~~$14.0~~$61.2 million of which ~~$2.5~~$10.6 million were charged to other operation and maintenance (O&M) expense, ~~$1.1~~$2.6 million relate to capital costs and ~~$10.4~~$48.0 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~~35-year site lease from the U.S. Army. Construction of the facility began in October 2016, and the facility ~~is expected to be~~was placed in service inon June 7, 2018. A request to recover the ~~second quarter~~capital costs of the project through the newly-established Major Project Interim Recovery (MPIR) adjustment mechanism was approved by the PUC on June 27, 2018. (See “Decoupling” section below for MPIR guidelines and capital cost recovery discussion.) A decision on recovery of related operation and maintenance expense (approximately $1.8 million annualized) during the interim period (i.e., between the in-service date and the next rate case) is pending. Project costs incurred as of June 30, ~~2017~~2018 amounted to ~~$87.8~~$141.5 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~~on property owned by the Department of the ~~Navy at a Navy/Air Force joint base.~~Navy. 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~~less to ~~$0.4 million.~~the system.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

In approving the project, the PUC agreed that the project is eligible for recovery of costs offset by related net benefits under the ~~Major Project Interim Recovery (MPIR) guidelines (see~~newly-established MPIR adjustment mechanism. (See “Decoupling” section below for MPIR ~~guidelines). The PUC established a procedural schedule for~~guidelines and capital cost recovery discussion.) Hawaiian Electric ~~to provide~~provided supplemental materials in August 2017, as requested by the PUC, to support meeting the MPIR guidelines, ~~for recovery of costs~~ accompanied by system performance guarantee and cost savings sharing ~~mechanisms~~mechanisms. A decision on these matters is pending.

Hawaiian Electric executed a fixed-price Engineering, Procurement, and Construction (EPC) contract 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~~project on December ~~30, 2030.~~6, 2017. The ~~HEP plant currently contributes about 23%~~EPC contract includes the cost of the ~~island of Hawaii’s generating capacity. In December 2015, Hawaii Electric Light entered into an agreement,~~solar panels for the project, which is not subject to ~~PUC approval,~~modification due to ~~acquire~~any tariffs that may be imposed under the ~~assets of HEP for approximately $84.5 million. On May 4, 2017, the PUC denied Hawaii Electric Light’s application for approval~~current photovoltaic (PV) cell and module import tariffs. Construction of the ~~Asset Purchase Agreement (APA) on~~facility began in the ~~grounds that customer benefits were not sufficiently demonstrated~~second quarter of 2018, and the facility is expected to ~~justify~~be placed in service in the ~~purchase and in July 2017, Hawaii Electric Light and HEP terminated the APA.~~second quarter of 2019. Project costs incurred as of June 30, 2018 amounted to $9.1 million.

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. This dispute resolution process is stayed pending PUC approval of a settlement agreement further

described below. 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. This complaint is stayed pending PUC approval of a

settlement agreement further described below. Maui Electric has not yet commenced any legal action to recover the delinquent

amounts. On April 4, 2018, the Utilities and Hawaiian Telcom entered into several agreements, subject to PUC approval, for the purchase by the Utilities of Hawaiian Telcom’s interest in all the joint poles, and licensing and operating agreement between the Utilities and Hawaiian Telcom subsequent to the transfer of the joint pole interest to the Utilities. Consideration of approximately $48 million to be paid for Hawaiian Telcom’s interest in the poles will be offset in part by the receivables owed by Hawaiian Telcom to the Utilities. As of June 30, ~~2017, total~~2018, receivables under the joint pole agreement, ~~including~~net of a reserve for a portion of the interest, from Hawaiian Telcom are ~~$22.1~~$17.4 million ($~~14.8~~11.6 million at Hawaiian Electric, ~~$6.0~~$4.7 million at Hawaii Electric Light, and ~~$1.3~~$1.1 million at Maui Electric). ~~Management~~Although PUC approval has not yet been received, management expects the net receivable amounts will be realized. The remaining consideration for acquiring Hawaiian Telcom’s interest in the joint poles is to ~~prevail on these claims but has reserved~~be settled through the set-off of current and future license fees due from Hawaiian Telcom, after which Hawaiian Telcom would make cash payments for license fees under the ~~accrued interest of $4.9 million on the receivables.~~agreement.

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~~$2.7 million as of June 30, ~~2017,~~2018, 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.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

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~~Appropriate remedial measures are being developed to address 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,~~2018, the reserve account balance recorded by Hawaiian Electric to address the PCB contamination was ~~$4.9~~$4.7 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.~~Plant by the Navy.

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 in 2011, delinks revenues from sales and includes annual rate adjustments. The decoupling mechanism has ~~three~~the following major components: (1) a sales decoupling component via a revenue balancing account (RBA), (2) a revenue escalation component via a rate adjustment mechanism (RAM), (3) major project interim recovery component (MPIR), (4) performance incentive mechanisms (PIMs), and ~~(3)~~(5) 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.~~Under the decoupling mechanism, triennial general rate cases are required.

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~~Rate adjustment mechanism. 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~~reset upon the issuance of an interim or final D&O in a rate ~~case cycle required under the decoupling mechanism continues to serve as the maximum period between the filing of general rate cases.~~case.

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~~2017 and ~~2017.~~2018.

Maui Electric's RAM revenues ~~were limited to the RAM Cap~~ in ~~2015~~2017 and ~~2016; however, the 2017 RAM revenues~~2018 were below the RAM Cap.

Hawaii Electric Light’s RAM revenues in 2017 and 2018 were below the RAM ~~Cap~~Cap.

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. Subsequent to 2016, Hawaiian Electric reverted to the RAM provisions initially approved in ~~2015, 2016~~March 2011—i.e., RAM is both accrued and ~~2017.~~billed from June 1 of each year through May 31 of the following year.

~~2017 decoupling order~~Major project interim recovery. On April 27, 2017, the PUC issued an Order ~~(the 2017 Decoupling Order)~~ that ~~requires the establishment of specific performance incentive mechanisms and provides~~provided 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~~approved 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~~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

InNOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

are not recovered through the ~~2017 Decoupling Order,~~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.

The PUC ~~indicated that~~has approved recovery of a capped portion of the Schofield generating station through the MPIR mechanism. Hawaiian Electric has filed an MPIR for Schofield of $6.6 million in annual revenues, which would adjust revenues in July through December 2018 and be collected in customer bills beginning in June 2019.

Performance incentive mechanisms. The PUC has ordered the following performance incentive mechanisms (PIM), which will be reflected in the annual decoupling filing beginning in 2019. The PIM tariff requires the performance targets, deadbands and the amount of maximum financial incentives used to determine the PIM financial incentive levels for each of the PIMs to be re-determined upon issuance of an interim or final order in a general rate case for each utility.

Service Quality performance incentives are measured on a calendar-year basis beginning in 2018.

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 rate base (or maximum penalties of approximately $6.2 million - pending adjustment to $6.7 million as a result of the final orders for the Hawaiian Electric and ~~subsequent~~Hawaii Electric Light rate cases - for both indices in total for the ~~PUC intends~~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 incentive is 8 basis points applied to ~~require all fuel expenses~~the common equity share of each respective utility’s rate base (or maximum penalties or incentives of approximately $1.2 million - pending adjustment to $1.3 million as a result of the final orders for the Hawaiian Electric and ~~purchased energy expenses be recovered~~Hawaii Electric Light rate cases - in total for the three utilities).

Demand Response measured by the demand response resources acquired in 2018. The award is equal to 5% of the total of the annual maintenance cost for cost-effective demand response capability contracted with aggregators by December 31, 2018. The maximum award is $0.5 million for the three utilities in total and there are no penalties. This incentive applies to one-time performance in 2018 only.

Procurement of low-cost variable renewable resources through ~~an appropriately modified energy cost adjustment mechanism rather than through base rates,~~the request for proposal process in 2018 measured by comparison of the procurement price to target prices. The incentive is 20% of savings determined by comparing procured price to a target of 11.5 cents per kilowatt-hour for renewable projects with storage capability and ~~will consider adopting processes to periodically reset fuel efficiency measures embedded~~9.5 cents per kilowatt-hour for energy-only renewable projects. This incentive has a cap of $3.5 million for the three utilities in ~~the energy cost adjustment mechanism to account for changes in the generating system.~~total and has no penalty.

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), from June 1, 2018 through May 31, 2019 are as ~~revised for~~follows:



(in millions)	Hawaiian Electric		Hawaii Electric Light		Maui Electric
2018 Annual incremental RAM adjusted revenues	$	13.8	$	3.4	$	2.0
Annual change in accrued RBA balance as of December 31, 2017 (and associated revenue taxes)	$	6.6	$	0.7	$	3.2
2017 Tax Act Adjustment	$	—	$	—	$	(2.8	)
Net annual incremental amount to be collected under the tariffs	$	20.4	$	4.1	$	2.4

* 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 onincorporated 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~~$2.8 million adjustment into its 2018 annual decoupling ~~filings~~filing to incorporate the impact of the lower corporate income tax rate and the exclusion of the domestic production activities deduction, as a result of the 2017 Tax Cuts and Jobs Act (the Tax Act). Tax adjustments for Hawaiian Electric and Hawaii Electric Light are described in the discussion below of their respective on-going rate cases.

Performance-based regulation proceeding. On April 18, 2018, the PUC issued an order, instituting a proceeding to investigate performance-based regulation (PBR). The PUC intends to provide a forum to collaboratively develop modifications or new components to better align utility and customer interests. The PUC stated that PBR seeks to utilize both revenue adjustment mechanisms and performance mechanisms to more strongly align utilities’ incentives with customer interests.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

The order stated that, in general, the PUC is interested in ratemaking elements and/or mechanisms that result in:

Greater cost control and reduced rate volatility;

Efficient investment and allocation of resources regardless of classification as ~~amended~~capital or operating expense;

Fair distribution of risks between utilities and customers; and

Fulfillment of State policy goals.

The PUC envisions that the PBR components through this investigation are those that: (a) target areas of current utility performance that may benefit from improvement; and (b) reward the utility for achieving specific outcomes that are in the public interest and/or penalize the utility for not achieving said outcomes. To that end, through this investigation, the PUC intends to: (1) identify specific areas of utility performance that should be improved; (2) determine appropriate metrics for measuring successful outcomes in those areas; and (3) establish reasonable financial rewards and/or penalties that are sufficient to incent the utility to achieve those outcomes.

The order indicated that the proceeding would have two phases. Phase 1 would examine the current regulatory framework and identify those areas of utility performance that are deserving of further focus for PBR framework development and/or PIMs in Phase 2. A subsequent order established a procedural process and schedule for Phase I, which the PUC anticipated would take approximately nine months.

On July 10, 2018, the PUC submitted a Staff Report to provide the Parties with an initial set of proposed regulatory goals and outcomes to respond to, or expand upon, and to offer alternatives. Specifically, the Staff Report: (a) provides an overview of Phase 1 of the proceeding; (b) discusses the terms and concepts that form the PBR process framework; and (c) proposes three overarching goals (enhance customer experience, improve utility performance, advance societal outcomes) along with a preliminary set of associated outcomes to help guide PBR evaluation and development.

On July 23 and 24, 2018, the PUC held a technical workshop on ~~May 22, 2017, for Maui Electric,~~goals and outcomes, attended by the parties in the proceeding.

Performance-based ratemaking legislation. On April 24, 2018, Senate Bill No. 2939 SD2 was signed into law, which ~~went into effect~~establishes performance metrics that the PUC shall consider while establishing performance incentives and penalty mechanisms under a performance-based ratemaking model. The law requires that the PUC establish these performance-based ratemaking mechanisms on ~~June~~or before January 1, ~~2017.~~2020. The PUC opened a proceeding on April 18, 2018. See “Performance-based regulation proceeding” above.

Most recent rate proceedings.

Hawaiian Electric consolidated 2014 ~~test year abbreviated~~ and 2017 test year rate cases. OnIn June 2014, Hawaiian Electric submitted its 2014 test year rate case filing, stating that it intended to forgo the opportunity to seek a general rate increase in base rates. In December ~~23,~~ 2016, Hawaiian Electric filed an application with the PUC for a general rate increase, and 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 thatcases. On February 16, 2018, Hawaiian Electric ~~file~~implemented an ~~application for a general rate case every three years and (2) the requirement that~~interim increase of $36.0 million. On April 13, 2018, Hawaiian Electric ~~file~~implemented an additional interim rate adjustment to adjust rates for the impact of the Tax Act.

On June 22, 2018, the PUC issued its Final D&O, approving final rate relief of a $37.7 million increase before the Tax Act impact reduction of $38.3 million, based on an ROACE of 9.5% and an overall rate of return of 7.57%. The PUC indicated that the ECRC mechanism shall reflect a 98/2% risk-sharing split between ratepayers and Hawaiian Electric, with an annual maximum exposure cap of $2.5 million.

Maui Electric consolidated 2015 and 2018 test year rate cases. In December 2014, ~~calendar~~Maui Electric submitted its 2015 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~~filing, proposing no change 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,~~its base rates. In August 2017, the PUC issued an order ~~to address Hawaiian Electric’s motion, stating that~~consolidating the Maui Electric filings for the 2015 and 2018 test year rate cases. In October 2017, Maui Electric filed its 2018 test year rate case application with 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 forgofor a general rate increase of $30.1 million over revenues at current effective rates (for a 9.3% increase in ~~base rates for its mandated 2014~~revenues) based on a 2018 test ~~year. As directed,~~year and an 8.05% rate of return (which incorporates a ROACE of 10.6% and a capital structure that includes a 56.9% common equity capitalization) on ~~April 12, 2017, Hawaiian~~a $473 million rate base. Subsequently, in accordance with a PUC order, on February 26, 2018, Maui Electric filed revised schedules to reflect the following adjustments resulting from the Tax Act in its 2018 test year revenue requirement: (1) $8.1 million income tax expense reduction; (2) $0.5 million annual amortization credit for excess accumulated deferred income tax balances (ADIT); and (3) $7.1 million increase in rate base resulting from the decrease in ADIT for bonus depreciation loss and CIAC taxability.

Maui Electric and the Consumer Advocate filed a ~~supplement~~stipulated settlement letter and the Parties’ joint statement of probable entitlement on June 15, 2018 and July 6, 2018, respectively. The stipulated settlement resolved all issues between the parties,

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

except for the narrow issue of whether the ROACE should be reduced from 9.75% by up to ~~its 2017 rate case filing, addressing~~25 basis points based solely on the ~~items raised~~impact of decoupling, considering current circumstances and relevant precedents. The parties agreed that the ROACE issue shall be addressed based on the information contained in the ~~order~~record without the need for an evidentiary hearing, and ~~explaining why Hawaiian Electric’s forgoing~~further agreed to the use of a 9.50% ROACE for the limited purpose of determining the revenue requirement for the interim order. The joint statement of probable entitlement reflects a general rate increase of $6.4 million over revenues at current effective rates (for a 1.95% increase in revenues) based on 7.43% rate of return (which incorporates a ROACE of 9.5% and a capital structure that includes a 57% common equity capitalization) on a $465 million rate base. The general rate increase would be $12.5 million over revenues at current effective rates with the depreciation rates approved in the ~~2014~~depreciation proceeding. In the decision and order issued on July 30, 2018 in the depreciation proceeding, the PUC ordered that the effective date of the approved depreciation rates shall coincide with the effective date of interim or final rates in each of the Utilities’ subsequent general rate case proceedings, beginning with Maui Electric’s 2018 test year ~~should not result~~rate case. The PUC may consider the Parties’ joint statement of probable entitlement in ~~any further adjustments to Hawaiian Electric’s revenue requirement in the 2017~~issuing its interim order. The interim D&O is scheduled for August 13, 2018.

Hawaii Electric Light 2016 test ~~year.~~

~~On April 26, 2017,~~year rate case. In September 2016, Hawaii Electric Light filed an application with the PUC ~~issued an Order regarding the supplement to Hawaiian Electric’s 2017~~for a general 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.increase.

~~On June 28,~~In August 2017, the PUC issued an order ~~designating~~granting an interim rate increase of $9.9 million based on the ~~filing date~~Stipulated Settlement Letter of ~~Hawaiian Electric’s completed~~Hawaii Electric Light and the Consumer Advocate filed on July 11, 2017 and an ROACE of 9.5% and subject to refund with interest, if it exceeds amounts allowed in a final order. The interim rate ~~case application~~increase was implemented on August 31, 2017. On May 1, 2018, Hawaii Electric Light implemented an interim rate reduction of $9.9 million which was primarily to ~~be May 31, 2017, rather than December 16, 2016,~~incorporate the ~~date~~effects 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. Tax Act.

On ~~July 28, 2017,~~June 29, 2018, the PUC issued ~~a procedural schedule with an~~its Final D&O, approving the rates implemented in the interim ~~D&O tentatively scheduled~~rate reduction.

Tax Cuts and Jobs Act impact on utility rates. The Utilities began tracking the impact of the Tax Cuts and Jobs Act of 2017 (Tax Act) as of January 1, 2018. Each Utility accrued regulatory liabilities for ~~December 15,~~estimated tax savings from January 1 to the date incorporated in rates. Hawaiian Electric’s rates for the 2017 ~~and an evidentiary hearing~~test year reflected the Tax Act reductions effective April 13, 2018. Hawaii Electric Light’s rates for the 2016 test year reflect the Tax Act reductions effective May 1, 2018. Adjustments to Maui Electric’s current rates for the Tax Act are incorporated in ~~early March~~the annual Revenue Balancing Account adjustment which became effective on June 1, 2018. See discussion in “Decoupling” section above.

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.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income ~~(unaudited)~~

Three months ended June 30, ~~2017~~2018


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Revenues	$	394,414		81,710		80,765		—	(14	)	$	556,875		$	431,699		89,548		86,938		—	(59	)	$	608,126
Expenses
Fuel oil	99,814			14,475		26,970		—	—		141,259			120,007			19,432		32,278		—	—		171,717
Purchased power	116,458			23,482		13,127		—	—		153,067			121,812			24,664		14,262		—	—		160,738
Other operation and maintenance	70,961			17,558		17,855		—	—		106,374			76,845			19,015		16,782		—	—		112,642
Depreciation	32,723			9,686		5,747		—	—		48,156			34,391			10,038		5,932		—	—		50,361
Taxes, other than income taxes	37,619			7,702		7,651		—	—		52,972			40,951			8,408		8,165		—	—		57,524
Total expenses	357,575			72,903		71,350		—	—		501,828			394,006			81,557		77,419		—	—		552,982
Operating income	36,839			8,807		9,415		—	(14	)	55,047			37,693			7,991		9,519		—	(59	)	55,144
Allowance for equity funds used during construction	2,659			134		234		—	—		3,027			2,588			124		271		—	—		2,983
Equity in earnings of subsidiaries	7,936			—		—		—	(7,936	)	—			9,080			—		—		—	(9,080	)	—
Retirement defined benefits expense—other than service costs														(554		)	(105	)	(329	)	—	—		(988		)
Interest expense and other charges, net	(12,562		)	(2,996	)	(2,670	)	—	14		(18,214		)	(12,930		)	(2,922	)	(2,367	)	—	59		(18,160		)
Allowance for borrowed funds used during construction	988			55		100		—	—		1,143			1,150			77		138		—	—		1,365
Income before income taxes	35,860			6,000		7,079		—	(7,936	)	41,003			37,027			5,165		7,232		—	(9,080	)	40,344
Income taxes	9,946			2,235		2,679		—	—		14,860			5,588			1,269		1,819		—	—		8,676
Net income	25,914			3,765		4,400		—	(7,936	)	26,143			31,439			3,896		5,413		—	(9,080	)	31,668
Preferred stock dividends of subsidiaries	—			133		96		—	—		229			—			133		96		—	—		229
Net income attributable to Hawaiian Electric	25,914			3,632		4,304		—	(7,936	)	25,914			31,439			3,763		5,317		—	(9,080	)	31,439
Preferred stock dividends of Hawaiian Electric	270			—		—		—	—		270			270			—		—		—	—		270
Net income for common stock	$	25,644		3,632		4,304		—	(7,936	)	$	25,644		$	31,169		3,763		5,317		—	(9,080	)	$	31,169

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income ~~(unaudited)~~

Three months ended June 30, ~~2017~~2018


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			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		$	31,169		3,763		5,317		—	(9,080	)	$	31,169
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			4,853			734		649		—	(1,383	)	4,853
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(3,581		)	(448	)	(343	)	—	791		(3,581		)	(4,827		)	(733	)	(649	)	—	1,382		(4,827		)
Other comprehensive income (loss), net of taxes	40			1		1		—	(2	)	40
Other comprehensive income, net of taxes														26			1		—		—	(1	)	26
Comprehensive income attributable to common shareholder	$	25,684		3,633		4,305		—	(7,938	)	$	25,684		$	31,195		3,764		5,317		—	(9,081	)	$	31,195

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income ~~(unaudited)~~

Three months ended June 30, ~~2016~~2017


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Revenues	$	347,010		73,652		74,758		—	(25	)	$	495,395		$	394,414		81,710		80,765		—	(14	)	$	556,875
Expenses
Fuel oil	62,234			11,748		17,917		—	—		91,899			99,814			14,475		26,970		—	—		141,259
Purchased power	103,062			19,360		16,636		—	—		139,058			116,458			23,482		13,127		—	—		153,067
Other operation and maintenance	68,197			15,116		16,250		—	—		99,563			69,659			17,643		17,637		—	—		104,939
Depreciation	31,522			9,449		5,789		—	—		46,760			32,723			9,686		5,747		—	—		48,156
Taxes, other than income taxes	33,414			6,905		7,110		—	—		47,429			37,619			7,702		7,651		—	—		52,972
Total expenses	298,429			62,578		63,702		—	—		424,709			356,273			72,988		71,132		—	—		500,393
Operating income	48,581			11,074		11,056		—	(25	)	70,686			38,141			8,722		9,633		—	(14	)	56,482
Allowance for equity funds used during construction	1,559			206		232		—	—		1,997			2,659			134		234		—	—		3,027
Equity in earnings of subsidiaries	10,883			—		—		—	(10,883	)	—			7,936			—		—		—	(7,936	)	—
Retirement defined benefits expense—other than service costs														(1,302		)	85		(218	)	—	—		(1,435		)
Interest expense and other charges, net	(10,345		)	(2,669	)	(2,114	)	—	25		(15,103		)	(12,562		)	(2,996	)	(2,670	)	—	14		(18,214		)
Allowance for borrowed funds used during construction	587			79		94		—	—		760			988			55		100		—	—		1,143
Income before income taxes	51,265			8,690		9,268		—	(10,883	)	58,340			35,860			6,000		7,079		—	(7,936	)	41,003
Income taxes	15,138			3,337		3,509		—	—		21,984			9,946			2,235		2,679		—	—		14,860
Net income	36,127			5,353		5,759		—	(10,883	)	36,356			25,914			3,765		4,400		—	(7,936	)	26,143
Preferred stock dividends of subsidiaries	—			133		96		—	—		229			—			133		96		—	—		229
Net income attributable to Hawaiian Electric	36,127			5,220		5,663		—	(10,883	)	36,127			25,914			3,632		4,304		—	(7,936	)	25,914
Preferred stock dividends of Hawaiian Electric	270			—		—		—	—		270			270			—		—		—	—		270
Net income for common stock	$	35,857		5,220		5,663		—	(10,883	)	$	35,857		$	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, ~~2016~~2017


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Net income for common stock	$	35,857		5,220		5,663		—	(10,883	)	$	35,857		$	25,644		3,632		4,304		—	(7,936	)	$	25,644
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			3,621			449		344		—	(793	)	3,621
Reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes	(3,401		)	(402	)	(359	)	—	761		(3,401		)	(3,581		)	(448	)	(343	)	—	791		(3,581		)
Other comprehensive income (loss), net of taxes	(755		)	(1	)	(2	)	—	3		(755		)
Other comprehensive income, net of taxes														40			1		1		—	(2	)	40
Comprehensive income attributable to common shareholder	$	35,102		5,219		5,661		—	(10,880	)	$	35,102		$	25,684		3,633		4,305		—	(7,938	)	$	25,684

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income ~~(unaudited)~~

Six months ended June 30, ~~2017~~2018


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			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		$	832,879		177,481		168,294		—	(101	)	$	1,178,553
Expenses
Fuel oil	197,815			31,732		55,982		—	—		285,529			234,505			37,919		66,261		—	—		338,685
Purchased power	216,605			42,071		21,515		—	—		280,191			229,182			48,498		22,968		—	—		300,648
Other operation and maintenance	138,239			33,074		35,301		—	—		206,614			149,785			35,113		35,354		—	—		220,252
Depreciation	65,445			19,371		11,556		—	—		96,372			68,830			20,093		11,904		—	—		100,827
Taxes, other than income taxes	72,659			15,152		14,984		—	—		102,795			79,118			16,620		15,890		—	—		111,628
Total expenses	690,763			141,400		139,338		—	—		971,501			761,420			158,243		152,377		—	—		1,072,040
Operating income	66,494			19,292		18,220		—	(21	)	103,985			71,459			19,238		15,917		—	(101	)	106,513
Allowance for equity funds used during construction	4,715			249		462		—	—		5,426			5,475			235		567		—	—		6,277
Equity in earnings of subsidiaries	16,539			—		—		—	(16,539	)	—			18,405			—		—		—	(18,405	)	—
Retirement defined benefits expense—other than service costs														(1,616		)	(208	)	(428	)	—	—		(2,252		)
Interest expense and other charges, net	(24,619		)	(6,000	)	(5,120	)	—	21		(35,718		)	(25,425		)	(5,829	)	(4,701	)	—	101		(35,854		)
Allowance for borrowed funds used during construction	1,737			100		195		—	—		2,032			2,388			141		280		—	—		2,809
Income before income taxes	64,866			13,641		13,757		—	(16,539	)	75,725			70,686			13,577		11,635		—	(18,405	)	77,493
Income taxes	17,217			5,158		5,243		—	—		27,618			11,502			3,446		2,903		—	—		17,851
Net income	47,649			8,483		8,514		—	(16,539	)	48,107			59,184			10,131		8,732		—	(18,405	)	59,642
Preferred stock dividends of subsidiaries	—			267		191		—	—		458			—			267		191		—	—		458
Net income attributable to Hawaiian Electric	47,649			8,216		8,323		—	(16,539	)	47,649			59,184			9,864		8,541		—	(18,405	)	59,184
Preferred stock dividends of Hawaiian Electric	540			—		—		—	—		540			540			—		—		—	—		540
Net income for common stock	$	47,109		8,216		8,323		—	(16,539	)	$	47,109		$	58,644		9,864		8,541		—	(18,405	)	$	58,644

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Comprehensive Income ~~(unaudited)~~

Six months ended June 30, ~~2017~~2018


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			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		$	58,644		9,864		8,541		—	(18,405	)	$	58,644
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			9,506			1,409		1,211		—	(2,620	)	9,506
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		)	(9,449		)	(1,408	)	(1,211	)	—	2,619		(9,449		)
Other comprehensive income (loss), net of taxes	499			1		—		—	(1	)	499
Other comprehensive income, net of taxes														57			1		—		—	(1	)	57
Comprehensive income attributable to common shareholder	$	47,608		8,217		8,323		—	(16,540	)	$	47,608		$	58,701		9,865		8,541		—	(18,406	)	$	58,701

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Income ~~(unaudited)~~

Six months ended June 30, ~~2016~~2017


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Revenues	$	684,185		146,835		146,464		—	(37	)	$	977,447		$	757,257		160,692		157,558		—	(21	)	$	1,075,486
Expenses
Fuel oil	136,319			26,122		43,198		—	—		205,639			197,815			31,732		55,982		—	—		285,529
Purchased power	194,979			36,157		23,781		—	—		254,917			216,605			42,071		21,515		—	—		280,191
Other operation and maintenance	137,755			31,557		34,159		—	—		203,471			135,652			33,242		34,862		—	—		203,756
Depreciation	63,044			18,898		11,599		—	—		93,541			65,445			19,371		11,556		—	—		96,372
Taxes, other than income taxes	66,098			13,796		13,973		—	—		93,867			72,659			15,152		14,984		—	—		102,795
Total expenses	598,195			126,530		126,710		—	—		851,435			688,176			141,568		138,899		—	—		968,643
Operating income	85,990			20,305		19,754		—	(37	)	126,012			69,081			19,124		18,659		—	(21	)	106,843
Allowance for equity funds used during construction	2,965			333		438		—	—		3,736			4,715			249		462		—	—		5,426
Equity in earnings of subsidiaries	18,812			—		—		—	(18,812	)	—			16,539			—		—		—	(16,539	)	—
Retirement defined benefits expense—other than service costs														(2,587		)	168		(439	)	—	—		(2,858		)
Interest expense and other charges, net	(22,210		)	(5,634	)	(4,604	)	—	37		(32,411		)	(24,619		)	(6,000	)	(5,120	)	—	21		(35,718		)
Allowance for borrowed funds used during construction	1,116			128		178		—	—		1,422			1,737			100		195		—	—		2,032
Income before income taxes	86,673			15,132		15,766		—	(18,812	)	98,759			64,866			13,641		13,757		—	(16,539	)	75,725
Income taxes	24,909			5,683		5,945		—	—		36,537			17,217			5,158		5,243		—	—		27,618
Net income	61,764			9,449		9,821		—	(18,812	)	62,222			47,649			8,483		8,514		—	(16,539	)	48,107
Preferred stock dividends of subsidiaries	—			267		191		—	—		458			—			267		191		—	—		458
Net income attributable to Hawaiian Electric	61,764			9,182		9,630		—	(18,812	)	61,764			47,649			8,216		8,323		—	(16,539	)	47,649
Preferred stock dividends of Hawaiian Electric	540			—		—		—	—		540			540			—		—		—	—		540
Net income for common stock	$	61,224		9,182		9,630		—	(18,812	)	$	61,224		$	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, ~~2016~~2017


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			Hawaiian Electric			Hawaii Electric Light		Maui Electric			Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated
Net income for common stock	$	61,224		9,182		9,630		—	(18,812	)	$	61,224		$	47,109		8,216		8,323			—	(16,539	)	$	47,109
Other comprehensive income, net of taxes:
Other comprehensive income (loss), net of taxes:
Derivatives qualifying as cash flow hedges:
Effective portion of foreign currency hedge net unrealized gain, net of taxes	257			—		—		—	—		257
Reclassification adjustment to net income, net of taxes														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	6,627			859		775		—	(1,634	)	6,627			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	(6,623		)	(860	)	(777	)	—	1,637		(6,623		)	(7,194		)	(951	)	(810	)		—	1,761		(7,194		)
Other comprehensive income, net of taxes	261			(1	)	(2	)	—	3		261			499			1		—			—	(1	)	499
Comprehensive income attributable to common shareholder	$	61,485		9,181		9,628		—	(18,809	)	$	61,485		$	47,608		8,217		8,323		��	—	(16,540	)	$	47,608

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet ~~(unaudited)~~

June 30, ~~2017~~2018


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consoli- dating adjustments		Hawaiian Electric Consolidated			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		$	44,023		5,876		3,015		—	—		$	52,914
Plant and equipment	4,318,460			1,267,529		1,125,429		—	—		6,711,418			4,363,195			1,217,147		1,072,640		—	—		6,652,982
Less accumulated depreciation	(1,423,042		)	(518,266	)	(488,789	)	—	—		(2,430,097		)	(1,491,505		)	(536,210	)	(506,713	)	—	—		(2,534,428		)
Construction in progress	232,965			16,734		22,739		—	—		272,438			127,343			10,154		28,111		—	—		165,608
Utility property, plant and equipment, net	3,172,354			772,188		662,395		—	—		4,606,937			3,043,056			696,967		597,053		—	—		4,337,076
Nonutility property, plant and equipment, less accumulated depreciation	5,763			115		1,532		—	—		7,410			5,934			115		1,532		—	—		7,581
Total property, plant and equipment, net	3,178,117			772,303		663,927		—	—		4,614,347			3,048,990			697,082		598,585		—	—		4,344,657
Investment in wholly owned subsidiaries, at equity	553,764			—		—		—	(553,764	)	—			561,764			—		—		—	(561,764	)	—
Current assets
Cash and cash equivalents	29,988			7,104		5,389		101	—		42,582			13,922			4,516		2,321		101	—		20,860
Advances to affiliates	—			4,100		1,000		—	(5,100	)	—			5,600			1,000		—		—	(6,600	)	—
Customer accounts receivable, net	88,614			18,847		18,700		—	—		126,161			109,285			24,005		23,970		—	—		157,260
Accrued unbilled revenues, net	74,640			14,166		14,790		—	—		103,596			80,239			15,243		15,357		—	—		110,839
Other accounts receivable, net	9,707			2,471		1,042		—	(9,536	)	3,684			10,657			2,561		1,124		—	(7,446	)	6,896
Fuel oil stock, at average cost	51,489			8,135		12,768		—	—		72,392			74,485			12,632		19,899		—	—		107,016
Materials and supplies, at average cost	30,716			8,852		17,531		—	—		57,099			31,077			8,600		18,264		—	—		57,941
Prepayments and other	25,695			7,294		3,602		—	(251	)	36,340			21,482			6,329		2,943		—	(1,514	)	29,240
Regulatory assets	65,891			3,981		4,295		—	—		74,167			88,581			6,353		8,632		—	—		103,566
Total current assets	376,740			74,950		79,117		101	(14,887	)	516,021			435,328			81,239		92,510		101	(15,560	)	593,618
Other long-term assets
Regulatory assets	638,480			119,108		106,522		—	—		864,110			538,925			118,000		99,919		—	—		756,844
Unamortized debt expense	497			84		109		—	—		690
Other	48,164			13,778		14,045		—	—		75,987			71,486			19,378		17,731		—	—		108,595
Total other long-term assets	687,141			132,970		120,676		—	—		940,787			610,411			137,378		117,650		—	—		865,439
Total assets	$	4,795,762		980,223		863,720		101	(568,651	)	$	6,071,155		$	4,656,493		915,699		808,745		101	(577,324	)	$	5,803,714
Capitalization and liabilities
Capitalization
Common stock equity	$	1,803,506		291,760		261,903		101	(553,764	)	$	1,803,506		$	1,852,324		288,865		272,798		101	(561,764	)	$	1,852,324
Cumulative preferred stock—not subject to mandatory redemption	22,293			7,000		5,000		—	—		34,293			22,293			7,000		5,000		—	—		34,293
Long-term debt, net	915,208			213,677		189,960		—	—		1,318,845			999,915			217,699		200,860		—	—		1,418,474
Total capitalization	2,741,007			512,437		456,863		101	(553,764	)	3,156,644			2,874,532			513,564		478,658		101	(561,764	)	3,305,091
Current liabilities
Current portion of long-term debt														29,990			10,996		8,997		—	—		49,983
Short-term borrowings from non-affiliates	43,990			—		—		—	—		43,990			91,880			—		—		—	—		91,880
Short-term borrowings from affiliate	5,100			—		—		—	(5,100	)	—			1,000			—		5,600		—	(6,600	)	—
Accounts payable	123,986			19,796		18,593		—	—		162,375			115,806			17,405		20,548		—	—		153,759
Interest and preferred dividends payable	13,584			3,806		2,113		—	(6	)	19,497			15,743			4,203		2,752		—	(14	)	22,684
Taxes accrued	98,156			23,394		20,964		—	(251	)	142,263			120,513			27,353		25,711		—	(1,514	)	172,063
Regulatory liabilities	126			713		2,044		—	—		2,883			2,751			2,499		4,537		—	—		9,787
Other	38,964			8,920		14,786		—	(9,530	)	53,140			42,449			10,223		13,963		—	(7,432	)	59,203
Total current liabilities	323,906			56,629		58,500		—	(14,887	)	424,148			420,132			72,679		82,108		—	(15,560	)	559,359
Deferred credits and other liabilities
Deferred income taxes	542,109			111,616		106,023		—	224		759,972			277,599			54,505		56,771		—	—		388,875
Regulatory liabilities	297,006			98,844		32,897		—	—		428,747			627,369			173,305		94,755		—	—		895,429
Unamortized tax credits	59,537			16,246		15,603		—	—		91,386			60,893			16,463		15,442		—	—		92,798
Defined benefit pension and other postretirement benefit plans liability	435,614			73,246		78,858		—	—		587,718			330,356			64,175		63,422		—	—		457,953
Other	49,798			13,803		15,959		—	(224	)	79,336			65,612			21,008		17,589		—	—		104,209
Total deferred credits and other liabilities	1,384,064			313,755		249,340		—	—		1,947,159			1,361,829			329,456		247,979		—	—		1,939,264
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		$	4,656,493		915,699		808,745		101	(577,324	)	$	5,803,714

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Balance Sheet ~~(unaudited)~~

December 31, ~~2016~~2017


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consoli- dating adjustments		Hawaiian Electric Consolidated			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		$	43,972		6,189		3,016		—	—		$	53,177
Plant and equipment	4,241,060			1,255,185		1,109,487		—	—		6,605,732			4,140,892			1,206,776		1,053,372		—	—		6,401,040
Less accumulated depreciation	(1,382,972		)	(507,666	)	(478,644	)	—	—		(2,369,282		)	(1,451,612		)	(528,024	)	(496,716	)	—	—		(2,476,352		)
Construction in progress	180,194			12,510		19,038		—	—		211,742			231,571			8,182		23,341		—	—		263,094
Utility property, plant and equipment, net	3,082,238			766,210		652,897		—	—		4,501,345			2,964,823			693,123		583,013		—	—		4,240,959
Nonutility property, plant and equipment, less accumulated depreciation	5,760			115		1,532		—	—		7,407			5,933			115		1,532		—	—		7,580
Total property, plant and equipment, net	3,087,998			766,325		654,429		—	—		4,508,752			2,970,756			693,238		584,545		—	—		4,248,539
Investment in wholly owned subsidiaries, at equity	550,946			—		—		—	(550,946	)	—			557,013			—		—		—	(557,013	)	—
Current assets
Cash and cash equivalents	61,388			10,749		2,048		101	—		74,286			2,059			4,025		6,332		101	—		12,517
Advances to affiliates	—			3,500		10,000		—	(13,500	)	—			—			—		12,000		—	(12,000	)	—
Customer accounts receivable, net	86,373			20,055		17,260		—	—		123,688			86,987			22,510		18,392		—	—		127,889
Accrued unbilled revenues, net	65,821			13,564		12,308		—	—		91,693			77,176			15,940		13,938		—	—		107,054
Other accounts receivable, net	7,652			2,445		1,416		—	(6,280	)	5,233			11,376			2,268		1,210		—	(7,691	)	7,163
Fuel oil stock, at average cost	47,239			8,229		10,962		—	—		66,430			64,972			8,698		13,203		—	—		86,873
Materials and supplies, at average cost	29,928			7,380		16,371		—	—		53,679			28,325			8,041		18,031		—	—		54,397
Prepayments and other	16,502			5,352		2,179		—	(933	)	23,100			17,928			4,514		2,913		—	—		25,355
Regulatory assets	60,185			3,483		2,364		—	—		66,032			76,203			5,038		7,149		—	—		88,390
Total current assets	375,088			74,757		74,908		101	(20,713	)	504,141			365,026			71,034		93,168		101	(19,691	)	509,638
Other long-term assets
Regulatory assets	662,232			120,863		108,324		—	—		891,419			557,464			122,783		100,660		—	—		780,907
Unamortized debt expense	151			23		34		—	—		208
Other	43,743			13,573		13,592		—	—		70,908			60,157			16,311		15,061		—	—		91,529
Total other long-term assets	706,126			134,459		121,950		—	—		962,535			617,621			139,094		115,721		—	—		872,436
Total assets	$	4,720,158		975,541		851,287		101	(571,659	)	$	5,975,428		$	4,510,416		903,366		793,434		101	(576,704	)	$	5,630,613
Capitalization and liabilities
Capitalization
Common stock equity	$	1,799,787		291,291		259,554		101	(550,946	)	$	1,799,787		$	1,845,283		286,647		270,265		101	(557,013	)	$	1,845,283
Cumulative preferred stock—not subject to mandatory redemption	22,293			7,000		5,000		—	—		34,293			22,293			7,000		5,000		—	—		34,293
Long-term debt, net	915,437			213,703		190,120		—	—		1,319,260			924,979			202,701		190,836		—	—		1,318,516
Total capitalization	2,737,517			511,994		454,674		101	(550,946	)	3,153,340			2,792,555			496,348		466,101		101	(557,013	)	3,198,092
Current liabilities
Short-term borrowings from affiliate	13,500			—		—		—	(13,500	)	—
Current portion of long-term debt														29,978			10,992		8,993		—	—		49,963
Short-term borrowings-non-affiliate														4,999			—		—		—	—		4,999
Short-term borrowings-affiliate														12,000			—		—		—	(12,000	)	—
Accounts payable	86,369			18,126		13,319		—	—		117,814			121,328			17,855		20,427		—	—		159,610
Interest and preferred dividends payable	15,761			4,206		2,882		—	(11	)	22,838			15,677			4,174		2,735		—	(11	)	22,575
Taxes accrued	120,176			28,100		25,387		—	(933	)	172,730			133,839			34,950		30,312		—	—		199,101
Regulatory liabilities	—			2,219		1,543		—	—		3,762			607			1,245		1,549		—	—		3,401
Other	41,352			7,637		12,501		—	(6,269	)	55,221			43,121			9,818		14,197		—	(7,680	)	59,456
Total current liabilities	277,158			60,288		55,632		—	(20,713	)	372,365			361,549			79,034		78,213		—	(19,691	)	499,105
Deferred credits and other liabilities
Deferred income taxes	524,433			108,052		100,911		—	263		733,659			281,223			56,955		55,863		—	—		394,041
Regulatory liabilities	281,112			93,974		31,845		—	—		406,931			613,329			169,139		94,901		—	—		877,369
Unamortized tax credits	57,844			15,994		15,123		—	—		88,961			59,039			16,167		15,163		—	—		90,369
Defined benefit pension and other postretirement benefit plans liability	444,458			75,005		80,263		—	—		599,726			340,983			66,447		65,518		—	—		472,948
Other	49,191			13,024		14,969		—	(263	)	76,921			61,738			19,276		17,675		—	—		98,689
Total deferred credits and other liabilities	1,357,038			306,049		243,111		—	—		1,906,198			1,356,312			327,984		249,120		—	—		1,933,416
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		$	4,510,416		903,366		793,434		101	(576,704	)	$	5,630,613

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

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

Six months ended June 30, ~~2017~~2018


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			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
Balance, December 31, 2017														$	1,845,283		286,647		270,265		101	(557,013	)	$	1,845,283
Net income for common stock	47,109			8,216		8,323		—	(16,539	)	47,109			58,644			9,864		8,541		—	(18,405	)	58,644
Other comprehensive income, net of taxes	499			1		—		—	(1	)	499			57			1		—		—	(1	)	57
Common stock dividends	(43,884		)	(7,748	)	(5,973	)	—	13,721		(43,884		)	(51,652		)	(7,644	)	(6,010	)	—	13,654		(51,652		)
Common stock issuance expenses	(5		)	—		(1	)	—	1		(5		)	(8		)	(3	)	2		—	1		(8		)
Balance, June 30, 2017	$	1,803,506		291,760		261,903		101	(553,764	)	$	1,803,506
Balance, June 30, 2018														$	1,852,324		288,865		272,798		101	(561,764	)	$	1,852,324

Hawaiian Electric Company, Inc. and Subsidiaries

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

Six months ended June 30, ~~2016~~2017


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			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
Balance, December 31, 2016														$	1,799,787		291,291		259,554		101	(550,946	)	$	1,799,787
Net income for common stock	61,224			9,182		9,630		—	(18,812	)	61,224			47,109			8,216		8,323		—	(16,539	)	47,109
Other comprehensive income (loss), net of taxes	261			(1	)	(2	)	—	3		261
Other comprehensive income, net of taxes														499			1		—		—	(1	)	499
Common stock dividends	(46,800		)	(6,604	)	(6,530	)	—	13,134		(46,800		)	(43,884		)	(7,748	)	(5,973	)	—	13,721		(43,884		)
Common stock issuance expenses	(4		)	(4	)	—		—	4		(4		)	(5		)	—		(1	)	—	1		(5		)
Balance, June 30, 2016	$	1,743,006		295,275		266,823		101	(562,199	)	$	1,743,006
Balance, June 30, 2017														$	1,803,506		291,760		261,903		101	(553,764	)	$	1,803,506

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows ~~(unaudited)~~

Six months ended June 30, ~~2017~~2018


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			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		$	59,184		10,131		8,732		—	(18,405	)	$	59,642
Adjustments to reconcile net income to net cash provided by operating activities:
Equity in earnings of subsidiaries	(16,589		)	—		—		—	16,539		(50		)	(18,455		)	—		—		—	18,405		(50		)
Common stock dividends received from subsidiaries	13,771			—		—		—	(13,721	)	50			13,679			—		—		—	(13,654	)	25
Depreciation of property, plant and equipment	65,445			19,371		11,556		—	—		96,372			68,830			20,093		11,904		—	—		100,827
Other amortization	1,875			905		1,482		—	—		4,262			9,200			2,976		845		—	—		13,021
Deferred income taxes	15,060			3,590		4,988		—	(39	)	23,599			(6,708		)	(2,429	)	794		—	—		(8,343		)
Allowance for equity funds used during construction	(4,715		)	(249	)	(462	)	—	—		(5,426		)	(5,475		)	(235	)	(567	)	—	—		(6,277		)
Other	1,089			699		(173	)	—	—		1,615			1,469			(322	)	(169	)	—	—		978
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 accounts receivable														(25,673		)	(2,387	)	(5,763	)	—	(245	)	(34,068		)
Decrease (increase) in accrued unbilled revenues														(3,063		)	697		(1,419	)	—	—		(3,785		)
Increase in fuel oil stock														(9,513		)	(3,934	)	(6,696	)	—	—		(20,143		)
Increase in materials and supplies	(788		)	(1,472	)	(1,160	)	—	—		(3,420		)	(2,752		)	(559	)	(233	)	—	—		(3,544		)
Decrease (increase) in regulatory assets	11,378			(1,575	)	(1,624	)	—	—		8,179
Increase in regulatory assets														(14,728		)	(1,974	)	(2,898	)	—	—		(19,600		)
Increase in accounts payable	39,954			3,291		8,392		—	—		51,637			13,093			3,096		2,095		—	—		18,284
Change in prepaid and accrued income taxes, tax credits and revenue taxes	(29,430		)	(6,290	)	(4,725	)	—	(465	)	(40,910		)	(15,343		)	(9,952	)	(5,165	)	—	(601	)	(31,061		)
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability	355			26		(79	)	—	—		302
Decrease in defined benefit pension and other postretirement benefit plans liability														(1,117		)	(380	)	(464	)	—	—		(1,961		)
Change in other assets and liabilities	(12,727		)	129		1,807		—	(3,256	)	(14,047		)	1,116			3,173		1,357		—	245		5,891
Net cash provided by operating activities	114,158			27,582		23,161		—	(14,225	)	150,676			63,744			17,994		2,353		—	(14,255	)	69,836
Cash flows from investing activities
Capital expenditures	(153,554		)	(24,744	)	(23,782	)	—	—		(202,080		)	(156,600		)	(26,667	)	(29,953	)	—	—		(213,220		)
Contributions in aid of construction	14,078			1,870		1,623		—	—		17,571			9,680			2,243		1,650		—	—		13,573
Other	4,820			619		307		—	504		6,250			2,241			884		575		—	601		4,301
Advances from affiliates	—			(600	)	9,000		—	(8,400	)	—
Advances (to) from affiliates														(5,600		)	(1,000	)	12,000		—	(5,400	)	—
Net cash used in investing activities	(134,656		)	(22,855	)	(12,852	)	—	(7,896	)	(178,259		)	(150,279		)	(24,540	)	(15,728	)	—	(4,799	)	(195,346		)
Cash flows from financing activities
Common stock dividends	(43,884		)	(7,748	)	(5,973	)	—	13,721		(43,884		)	(51,652		)	(7,644	)	(6,010	)	—	13,654		(51,652		)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(540		)	(267	)	(191	)	—	—		(998		)	(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		)
Proceeds from issuance of long-term debt														75,000			15,000		10,000		—	—		100,000
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			75,881			—		5,600		—	5,400		86,881
Other	(2,068		)	(357	)	(804	)	—	—		(3,229		)	(291		)	(52	)	(35	)	—	—		(378		)
Net cash used in financing activities	(10,902		)	(8,372	)	(6,968	)	—	22,121		(4,121		)
Net cash provided by financing activities														98,398			7,037		9,364		—	19,054		133,853
Net increase (decrease) in cash and cash equivalents	(31,400		)	(3,645	)	3,341		—	—		(31,704		)	11,863			491		(4,011	)	—	—		8,343
Cash and cash equivalents, beginning of period	61,388			10,749		2,048		101	—		74,286			2,059			4,025		6,332		101	—		12,517
Cash and cash equivalents, end of period	$	29,988		7,104		5,389		101	—		$	42,582		$	13,922		4,516		2,321		101	—		$	20,860

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Hawaiian Electric Company, Inc. and Subsidiaries

Condensed Consolidating Statement of Cash Flows ~~(unaudited)~~

Six months ended June 30, ~~2016~~2017


(in thousands)	Hawaiian Electric			Hawaii Electric Light		Maui Electric		Other subsidiaries	Consolidating adjustments		Hawaiian Electric Consolidated			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		$	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	(18,862		)	—		—		—	18,812		(50		)	(16,589		)	—		—		—	16,539		(50		)
Common stock dividends received from subsidiaries	13,184			—		—		—	(13,134	)	50			13,771			—		—		—	(13,721	)	50
Depreciation of property, plant and equipment	63,044			18,898		11,599		—	—		93,541			65,445			19,371		11,556		—	—		96,372
Other amortization	1,919			911		963		—	—		3,793			1,875			905		1,482		—	—		4,262
Deferred income taxes	23,954			2,538		5,623		—	3		32,118			15,060			3,590		4,988		—	(39	)	23,599
Allowance for equity funds used during construction	(2,965		)	(333	)	(438	)	—	—		(3,736		)	(4,715		)	(249	)	(462	)	—	—		(5,426		)
Other	1,383			1,611		(12	)	—	—		2,982			1,089			699		(173	)	—	—		1,615
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
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	(1,748		)	(708	)	(26	)	—	—		(2,482		)	(788		)	(1,472	)	(1,160	)	—	—		(3,420		)
Decrease (increase) in regulatory assets	(3,974		)	2,138		1,159		—	—		(677		)	11,378			(1,575	)	(1,624	)	—	—		8,179
Increase in accounts payable	17,150			208		6,069		—	—		23,427			33,121			970		5,625		—	—		39,716
Change in prepaid and accrued income taxes, tax credits and revenue taxes	(21,371		)	(192	)	(6,626	)	—	(3	)	(28,192		)	(29,430		)	(6,290	)	(4,725	)	—	(465	)	(40,910		)
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability	299			27		(89	)	—	—		237			355			26		(79	)	—	—		302
Change in other assets and liabilities	(11,803		)	11		(659	)	—	231		(12,220		)	(12,727		)	129		1,807		—	(3,256	)	(14,047		)
Net cash provided by operating activities	139,225			38,123		29,910		—	(13,134	)	194,124			107,325			25,261		20,394		—	(14,225	)	138,755
Cash flows from investing activities
Capital expenditures	(152,283		)	(27,436	)	(17,613	)	—	—		(197,332		)	(146,721		)	(22,423	)	(21,015	)	—	—		(190,159		)
Contributions in aid of construction	12,824			1,605		2,381		—	—		16,810			14,078			1,870		1,623		—	—		17,571
Other	132			169		30		—	—		331			4,820			619		307		—	504		6,250
Advances from affiliates	—			(3,000	)	(11,000	)	—	14,000		—
Advances (to) from affiliates														—			(600	)	9,000		—	(8,400	)	—
Net cash used in investing activities	(139,327		)	(28,662	)	(26,202	)	—	14,000		(180,191		)	(127,823		)	(20,534	)	(10,085	)	—	(7,896	)	(166,338		)
Cash flows from financing activities
Common stock dividends	(46,800		)	(6,604	)	(6,530	)	—	13,134		(46,800		)	(43,884		)	(7,748	)	(5,973	)	—	13,721		(43,884		)
Preferred stock dividends of Hawaiian Electric and subsidiaries	(540		)	(267	)	(191	)	—	—		(998		)	(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	50,995			—		—		—	(14,000	)	36,995			35,590			—		—		—	8,400		43,990
Other	8			(8	)	—		—	—		—			(2,068		)	(357	)	(804	)	—	—		(3,229		)
Net cash provided by (used in) financing activities	3,663			(6,879	)	(6,721	)	—	(866	)	(10,803		)
Net cash used in financing activities														(10,902		)	(8,372	)	(6,968	)	—	22,121		(4,121		)
Net increase (decrease) in cash and cash equivalents	3,561			2,582		(3,013	)	—	—		3,130			(31,400		)	(3,645	)	3,341		—	—		(31,704		)
Cash and cash equivalents, beginning of period	16,281			2,682		5,385		101	—		24,449			61,388			10,749		2,048		101	—		74,286
Cash and cash equivalents, end of period	$	19,842		5,264		2,372		101	—		$	27,579		$	29,988		7,104		5,389		101	—		$	42,582

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Note 4 · Bank segment

Selected financial information

American Savings Bank, F.S.B.

Statements of Income Data ~~(unaudited)~~


	Three months ended June 30				Six months ended June 30				Three months ended June 30				Six months ended June 30
(in thousands)	2017		2016		2017		2016		2018		2017		2018		2017
Interest and dividend income
Interest and fees on loans	$	52,317	$	49,690	$	103,059	$	98,127	$	54,633	$	52,317	$	107,433	$	103,059
Interest and dividends on investment securities	6,763		4,443		13,743		9,460		8,628		6,763		17,830		13,743
Total interest and dividend income	59,080		54,133		116,802		107,587		63,261		59,080		125,263		116,802
Interest expense
Interest on deposit liabilities	2,311		1,691		4,414		3,283		3,284		2,311		6,241		4,414
Interest on other borrowings	824		1,467		1,640		2,952		393		824		889		1,640
Total interest expense	3,135		3,158		6,054		6,235		3,677		3,135		7,130		6,054
Net interest income	55,945		50,975		110,748		101,352		59,584		55,945		118,133		110,748
Provision for loan losses	2,834		4,753		6,741		9,519		2,763		2,834		6,304		6,741
Net interest income after provision for loan losses	53,111		46,222		104,007		91,833		56,821		53,111		111,829		104,007
Noninterest income
Fees from other financial services	5,810		5,701		11,420		11,200		4,744		5,810		9,398		11,420
Fee income on deposit liabilities	5,565		5,262		10,993		10,418		5,138		5,565		10,327		10,993
Fee income on other financial products	1,971		2,207		3,837		4,412		1,675		1,971		3,329		3,837
Bank-owned life insurance	1,925		1,006		2,908		2,004		1,133		1,925		2,004		2,908
Mortgage banking income	587		1,554		1,376		2,749		617		587		1,230		1,376
Gains on sale of investment securities, net	—		598		—		598
Other income, net	391		288		849		621		536		391		972		849
Total noninterest income	16,249		16,616		31,383		32,002		13,843		16,249		27,260		31,383
Noninterest expense
Compensation and employee benefits	24,742		21,919		47,979		44,353		23,655		24,541		48,095		47,583
Occupancy	4,185		4,115		8,339		8,253		4,194		4,185		8,474		8,339
Data processing	3,207		3,277		6,487		6,449		3,540		3,207		7,004		6,487
Services	2,766		2,755		5,126		5,666		3,028		2,766		6,075		5,126
Equipment	1,771		1,771		3,519		3,434		1,874		1,771		3,602		3,519
Office supplies, printing and postage	1,527		1,583		3,062		2,948		1,491		1,527		2,998		3,062
Marketing	839		899		1,356		1,760		1,085		839		1,730		1,356
FDIC insurance	822		913		1,550		1,797		727		822		1,440		1,550
Other expense	4,705		5,382		9,016		9,357		4,556		4,906		8,657		9,412
Total noninterest expense	44,564		42,614		86,434		84,017		44,150		44,564		88,075		86,434
Income before income taxes	24,796		20,224		48,956		39,818		26,514		24,796		51,014		48,956
Income taxes	8,063		6,939		16,410		13,860		5,953		8,063		11,493		16,410
Net income	$	16,733	$	13,285	$	32,546	$	25,958	$	20,561	$	16,733	$	39,521	$	32,546

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Reconciliation to amounts per HEI Condensed Consolidated Statements of Income*:



	Three months ended June 30						Six months ended June 30
(in thousands)	2018			2017			2018			2017
Interest and dividend income	63,261			59,080			$	125,263		$	116,802
Noninterest income	13,843			16,249			27,260			31,383
*Revenues-Bank	77,104			75,329			152,523			148,185
Total interest expense	3,677			3,135			7,130			6,054
Provision for loan losses	2,763			2,834			6,304			6,741
Noninterest expense	44,150			44,564			88,075			86,434
Less: Retirement defined benefits expense—other than service costs	(403		)	(201		)	(790		)	(396		)
*Expenses-Bank	50,187			50,332			100,719			98,833
*Operating income-Bank	26,917			24,997			51,804			49,352
Add back: Retirement defined benefits expense—other than service costs	403			201			790			396
Income before income taxes	$	26,514		$	24,796		$	51,014		$	48,956

American Savings Bank, F.S.B.

Statements of Comprehensive Income Data ~~(unaudited)~~

Three months ended June 30 Six months ended June 30
(in thousands) 2017 2016 2017 2016
Net income $ 16,733
$ 13,285
$ 32,546
$ 25,958
Other comprehensive income, net of taxes:

Net unrealized gains on available-for-sale investment securities:

Net unrealized gains on available-for-sale investment securities arising during the period, net of taxes of $1,334, $1,925, $1,482 and $6,830, respectively 2,021
2,915
2,244
10,344
Reclassification adjustment for net realized gains included in net income, net of taxes of nil, $238, nil and $238, respectively —
(360 ) —
(360 )
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 of $133, $140, $537 and $277, respectively 202
211
814
419
Other comprehensive income, net of taxes 2,223
2,766
3,058
10,403
Comprehensive income $ 18,956
$ 16,051
$ 35,604
$ 36,361



	Three months ended June 30					Six months ended June 30
(in thousands)	2018			2017		2018			2017
Net income	$	20,561		$	16,733	$	39,521		$	32,546
Other comprehensive income (loss), net of taxes:
Net unrealized gains (losses) on available-for-sale investment securities:
Net unrealized gains (losses) on available-for-sale investment securities arising during the period, net of tax benefits (taxes) of $1,592, $(1,334), $6,459 and $(1,482), respectively	(4,348		)	2,021		(17,645		)	2,244
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 of $133, $133, $827 and $537, respectively	366			202		1,588			814
Other comprehensive income (loss), net of taxes	(3,982		)	2,223		(16,057		)	3,058
Comprehensive income	$	16,579		$	18,956	$	23,464		$	35,604

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

American Savings Bank, F.S.B.

Balance Sheets Data ~~(unaudited)~~


(in thousands)	June 30, 2017						December 31, 2016						June 30, 2018						December 31, 2017
Assets
Cash and due from banks				$	128,609					$	137,083					$	120,189					$	140,934
Interest-bearing deposits				37,049						52,128						109,230						93,165
Restricted cash				—						1,764
Available-for-sale investment securities, at fair value				1,302,886						1,105,182
Investment securities
Available-for-sale, at fair value																1,409,528						1,401,198
Held-to-maturity, at amortized cost (fair value of $61,444 and $44,412, respectively)																62,630						44,515
Stock in Federal Home Loan Bank, at cost				11,706						11,218						10,158						9,706
Loans receivable held for investment				4,744,634						4,738,693
Loans held for investment																4,774,744						4,670,768
Allowance for loan losses				(56,356		)				(55,533		)				(52,803		)				(53,637		)
Net loans				4,688,278						4,683,160						4,721,941						4,617,131
Loans held for sale, at lower of cost or fair value				5,261						18,817						5,248						11,250
Other				354,898						329,815						462,469						398,570
Goodwill				82,190						82,190						82,190						82,190
Total assets				$	6,610,877					$	6,421,357					$	6,983,583					$	6,798,659

Liabilities and shareholder’s equity
Deposit liabilities—noninterest-bearing				$	1,694,150					$	1,639,051					$	1,812,348					$	1,760,233
Deposit liabilities—interest-bearing				4,030,236						3,909,878						4,303,761						4,130,364
Other borrowings				188,130						192,618						126,930						190,859
Other				101,974						101,635						131,063						110,356
Total liabilities				6,014,490						5,843,182						6,374,102						6,191,812
Commitments and contingencies
Common stock				1						1						1						1
Additional paid in capital				344,062						342,704						346,188						345,018
Retained earnings				271,739						257,943						310,298						292,957
Accumulated other comprehensive loss, net of tax benefits
Net unrealized losses on securities	$	(5,687	)				$	(7,931	)				$	(32,596	)				$	(14,951	)
Retirement benefit plans	(13,728		)	(19,415		)	(14,542		)	(22,473		)	(14,410		)	(47,006		)	(16,178		)	(31,129		)
Total shareholder’s equity				596,387						578,175						609,481						606,847
Total liabilities and shareholder’s equity				$	6,610,877					$	6,421,357					$	6,983,583					$	6,798,659

Other assets
Bank-owned life insurance				$	146,122					$	143,197					$	150,797					$	148,775
Premises and equipment, net				108,158						90,570						186,620						136,270
Prepaid expenses				4,632						3,348						4,993						3,961
Accrued interest receivable				16,949						16,824						19,597						18,724
Mortgage-servicing rights				9,181						9,373						8,509						8,639
Low-income housing equity investments				48,596						47,081						63,033						59,016
Real estate acquired in settlement of loans, net				1,554						1,189						—						133
Other				19,706						18,233						28,920						23,052
				$	354,898					$	329,815					$	462,469					$	398,570
Other liabilities
Accrued expenses				$	34,451					$	36,754					$	63,734					$	39,312
Federal and state income taxes payable				6,336						4,728						1,200						3,736
Cashier’s checks				24,191						24,156						28,236						27,000
Advance payments by borrowers				10,334						10,335						10,415						10,245
Other				26,662						25,662						27,478						30,063
				$	101,974					$	101,635					$	131,063					$	110,356

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Bank-owned life insurance is life insurance purchased by ASB on the lives of certain key employees, with ASB as the beneficiary. The insurance is used to fund employee benefits through tax-free income from increases in the cash value of the policies and insurance proceeds paid to ASB upon an insured’s death.

Other borrowings consisted of securities sold under agreements to repurchase and advances from the Federal Home Loan Bank (FHLB) of $8877 million and $~~100~~50 million, respectively, as of June 30, ~~2017~~2018 and ~~$93~~$141 million and ~~$100~~$50 million, respectively, as of December 31, ~~2016~~2017.

~~Available-for-sale investment~~Investment securities. The major components of investment securities were as follows:


	Amortized cost		Gross unrealized gains			Gross unrealized losses				Estimated fair value				Gross unrealized losses																				Amortized cost				Gross unrealized gains			Gross unrealized losses				Estimated fair value			Gross unrealized losses
					Less than 12 months											12 months or longer													Less than 12 months															12 months or longer
(dollars in thousands)					Number of issues								Fair value				Amount			Number of issues			Fair value			Amount											Number of issues							Fair value				Amount			Number of issues		Fair value				Amount
June 30, 2017
June 30, 2018
Available-for-sale
U.S. Treasury and federal agency obligations																																		$	179,986			$	72		$	(4,125	)		$	175,933		19		$	98,578		$	(2,018	)		9		$	67,283		$	(2,107	)
Mortgage-related securities- FNMA, FHLMC and GNMA																																		1,218,313				350			(40,831		)		1,177,832			81		694,629			(19,345		)		83		456,218			(21,486		)
Corporate bonds																																		40,331				23			(18		)		40,336			4		23,841			(18		)		—		—			—
Mortgage revenue bond																																		15,427				—			—				15,427			—		—			—				—		—			—
																																		$	1,454,057			$	445		$	(44,974	)		$	1,409,528		104		$	817,048		$	(21,381	)		92		$	523,501		$	(23,593	)
Held-to-maturity
Mortgage-related securities- FNMA, FHLMC and GNMA																																		$	62,630			$	41		$	(1,227	)		$	61,444		3		$	41,138		$	(1,227	)		—		$	—		$	—
																																		$	62,630			$	41		$	(1,227	)		$	61,444		3		$	41,138		$	(1,227	)		—		$	—		$	—
December 31, 2017
Available-for-sale
U.S. Treasury and federal agency obligations	$	187,289	$	947			$	(1,653	)		$	186,583			16			$	104,417		$	(1,532	)		1		$	3,186			$	(121	)		$	185,891			$	438		$	(2,031	)		$	184,298		15		$	83,137		$	(825	)		8		$	62,296		$	(1,206	)
Mortgage-related securities- FNMA, FHLMC and GNMA	1,109,613		2,202				(10,939		)		1,100,876				98			759,643			(9,658		)		13		43,296				(1,281		)		1,220,304				793			(19,624		)		1,201,473			67		653,635			(6,839		)		77		459,912			(12,785		)
Mortgage revenue bond	15,427		—			—				15,427				—			—			—				—		—				—				15,427				—			—				15,427			—		—			—				—		—			—
	$	1,312,329	$	3,149		$	(12,592	)		$	1,302,886			114			$	864,060		$	(11,190	)		14		$	46,482			$	(1,402	)		$	1,421,622			$	1,231		$	(21,655	)		$	1,401,198		82		$	736,772		$	(7,664	)		85		$	522,208		$	(13,991	)
December 31, 2016
Available-for-sale
U.S. Treasury and federal agency obligations	$	193,515	$	920		$	(2,154	)		$	192,281			18			$	123,475		$	(2,010	)		1		$	3,485			$	(144	)
Held-to-maturity
Mortgage-related securities- FNMA, FHLMC and GNMA	909,408		1,742			(13,676		)		897,474				88			709,655			(12,143		)		13		47,485				(1,533		)		$	44,515			$	1		$	(104	)		$	44,412		2		$	35,744		$	(104	)		—		$	—		$	—
Mortgage revenue bond	15,427		—			—				15,427				—			—			—				—		—				—
	$	1,118,350	$	2,662		$	(15,830	)		$	1,105,182			106			$	833,130		$	(14,153	)		14		$	50,970			$	(1,677	)		$	44,515			$	1		$	(104	)		$	44,412		2		$	35,744		$	(104	)		—		$	—		$	—

ASB does not believe that the investment securities that were in an unrealized loss position at June 30, ~~2017,~~2018, represent an other-than-temporary impairment (OTTI). Total gross unrealized losses were primarily attributable to rising interest rates relative to when the investment securities were purchased and not due to the credit quality of the investment securities. The contractual cash flows of the U.S. Treasury, federal agency obligations and mortgage-related securities are backed by the full faith and credit guaranty of the United States government or an agency of the government. The corporate bonds are all investment grade and rated A- or higher. ASB does not intend to sell the securities before the recovery of its amortized cost basis and there have been no adverse changes in the timing of the contractual cash flows for the securities. ASB did not recognize OTTI for the quarters and six ~~month periods~~months ended June 30, ~~2017~~2018 and ~~2016.~~2017.

U.S. Treasury, federal agency obligations, corporate, and the mortgage revenue bond have contractual terms to maturity. Mortgage-related securities have contractual terms to maturity, but require periodic payments to reduce principal. In addition, expected maturities will differ from contractual maturities because borrowers have the right to prepay the underlying mortgages.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

The contractual maturities of ~~available-for-sale~~ investment securities were as follows:


June 30, 2017	Amortized cost		Fair value
June 30, 2018					Amortized cost		Fair value
(in thousands)
Available-for-sale
Due in one year or less	$	9,992	$	9,993	$	25,005	$	24,860
Due after one year through five years	77,151		77,307		105,425		104,020
Due after five years through ten years	85,724		85,258		77,526		75,563
Due after ten years	29,849		29,452		27,788		27,253
	202,716		202,010		235,744		231,696
Mortgage-related securities-FNMA, FHLMC and GNMA	1,109,613		1,100,876		1,218,313		1,177,832
Total available-for-sale securities	$	1,312,329	$	1,302,886	$	1,454,057	$	1,409,528
Held-to-maturity
Mortgage-related securities-FNMA, FHLMC and GNMA					$	62,630	$	61,444
Total held-to-maturity securities					$	62,630	$	61,444

Proceeds ~~and gross realized gains~~ from the sale of available-for-sale ~~investment~~ securities were ~~$16.4 million and $0.6 million, respectively,~~nil for both the three and six months ended June 30, ~~2016.~~2018 and 2017. Gross realized gains and losses ~~recognized during~~were nil for both the three and

six months ended June 30, ~~2016 were not material. No available-for-sale investment securities were sold during the three~~2018 and ~~six month periods ended June 30,~~ 2017.

~~Loans receivable.~~Loans. The components of loans ~~receivable~~ were summarized as follows:


	June 30, 2017			December 31, 2016			June 30, 2018			December 31, 2017
(in thousands)
Real estate:
Residential 1-4 family	$	2,061,549		$	2,048,051		$	2,099,950		$	2,118,047
Commercial real estate	808,900			800,395			758,835			733,106
Home equity line of credit	883,135			863,163			938,902			913,052
Residential land	16,009			18,889			16,032			15,797
Commercial construction	116,548			126,768			124,421			108,273
Residential construction	10,759			16,080			14,873			14,910
Total real estate	3,896,900			3,873,346			3,953,013			3,903,185
Commercial	649,657			692,051			593,596			544,828
Consumer	201,199			178,222			228,804			223,564
Total loans	4,747,756			4,743,619			4,775,413			4,671,577
Less: Deferred fees and discounts	(3,122		)	(4,926		)	(669		)	(809		)
Allowance for loan losses	(56,356		)	(55,533		)	(52,803		)	(53,637		)
Total loans, net	$	4,688,278		$	4,683,160		$	4,721,941		$	4,617,131

ASB's policy is to require private mortgage insurance on all real estate loans when the loan-to-value ratio of the property exceeds 80% of the lower of the appraised value or purchase price at origination. For non-owner occupied residential properties, the loan-to-value ratio may not exceed 80% of the lower of the appraised value or purchase price at origination. ASB is subject to the risk that the private mortgage insurance company cannot satisfy the bank's claim on policies.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Allowance for loan losses. The allowance for loan losses (balances and changes) and financing receivables were as follows:


(in thousands)	Residential 1-4 family			Commercial real estate		Home equity line of credit			Residential land			Commercial construction			Residential construction			Commercial loans			Consumer loans			Unallo-cated		Total				Residential 1-4 family			Commercial real estate			Home equity line of credit			Residential land			Commercial construction			Residential construction			Commercial loans			Consumer loans			Unallo-cated		Total
Three months ended June 30, 2018
Allowance for loan losses:
Beginning balance																														$	2,525		$	15,959		$	7,982		$	674		$	4,361		$	4		$	10,355		$	12,035		$	—	$	53,895
Charge-offs																														—			—			(144		)	(9		)	—			—			(540		)	(3,888		)	—		(4,581		)
Recoveries																														14			—			13			46			—			—			280			373			—		726
Provision																														400			(661		)	(517		)	(69		)	255			—			66			3,289			—		2,763
Ending balance																														$	2,939		$	15,298		$	7,334		$	642		$	4,616		$	4		$	10,161		$	11,809		$	—	$	52,803
Three months ended June 30, 2017
Allowance for loan losses:
Beginning balance	$	2,781		$	16,504	$	5,417		$	1,479		$	7,257		$	11		$	14,902		$	7,646		$	—	$	55,997			$	2,781		$	16,504		$	5,417		$	1,479		$	7,257		$	11		$	14,902		$	7,646		$	—	$	55,997
Charge-offs	—			—		—			(92		)	—			—			(752		)	(2,390		)	—		(3,234		)		—			—			—			(92		)	—			—			(752		)	(2,390		)	—		(3,234		)
Recoveries	49			—		39			15			—			—			299			357			—		759				49			—			39			15			—			—			299			357			—		759
Provision	300			2,336		71			(138		)	(2,551		)	(2		)	103			2,715			—		2,834				300			2,336			71			(138		)	(2,551		)	(2		)	103			2,715			—		2,834
Ending balance	$	3,130		$	18,840	$	5,527		$	1,264		$	4,706		$	9		$	14,552		$	8,328		$	—	$	56,356			$	3,130		$	18,840		$	5,527		$	1,264		$	4,706		$	9		$	14,552		$	8,328		$	—	$	56,356
Three months ended June 30, 2016
Six months ended June 30, 2018																													Six months ended June 30, 2018
Allowance for loan losses:
Beginning balance	$	4,593		$	11,806	$	7,172		$	1,740		$	6,164		$	12		$	16,991		$	3,848		$	—	$	52,326			$	2,902		$	15,796		$	7,522		$	896		$	4,671		$	12		$	10,851		$	10,987		$	—	$	53,637
Charge-offs	(15		)	—		—			—			—			—			(962		)	(1,528		)	—		(2,505		)		(31		)	—			(144		)	(17		)	—			—			(1,142		)	(8,120		)	—		(9,454		)
Recoveries	35			—		16			16			—			—			425			265			—		757				68			—			27			51			—			—			1,450			720			—		2,316
Provision	(229		)	1,755		648			(67		)	829			—			631			1,186			—		4,753				—			(498		)	(71		)	(288		)	(55		)	(8		)	(998		)	8,222			—		6,304
Ending balance	$	4,384		$	13,561	$	7,836		$	1,689		$	6,993		$	12		$	17,085		$	3,771		$	—	$	55,331			$	2,939		$	15,298		$	7,334		$	642		$	4,616		$	4		$	10,161		$	11,809		$	—	$	52,803
June 30, 2018
Ending balance: individually evaluated for impairment																														$	1,027		$	53		$	1,161		$	7		$	—		$	—		$	597		$	3				$	2,848
Ending balance: collectively evaluated for impairment																														$	1,912		$	15,245		$	6,173		$	635		$	4,616		$	4		$	9,564		$	11,806		$	—	$	49,955
Financing Receivables:
Ending balance																														$	2,099,950		$	758,835		$	938,902		$	16,032		$	124,421		$	14,873		$	593,596		$	228,804				$	4,775,413
Ending balance: individually evaluated for impairment																														$	17,605		$	993		$	13,849		$	1,171		$	—		$	—		$	5,874		$	91				$	39,583
Ending balance: collectively evaluated for impairment																														$	2,082,345		$	757,842		$	925,053		$	14,861		$	124,421		$	14,873		$	587,722		$	228,713				$	4,735,830
Six months ended June 30, 2017																													Six months ended June 30, 2017
Allowance for loan losses:
Beginning balance	$	2,873		$	16,004	$	5,039		$	1,738		$	6,449		$	12		$	16,618		$	6,800		$	—	$	55,533			$	2,873		$	16,004		$	5,039		$	1,738		$	6,449		$	12		$	16,618		$	6,800		$	—	$	55,533
Charge-offs	(6		)	—		(14		)	(92		)	—			—			(2,262		)	(5,200		)	—		(7,574		)		(6		)	—			(14		)	(92		)	—			—			(2,262		)	(5,200		)	—		(7,574		)
Recoveries	58			—		130			218			—			—			596			654			—		1,656				58			—			130			218			—			—			596			654			—		1,656
Provision	205			2,836		372			(600		)	(1,743		)	(3		)	(400		)	6,074			—		6,741				205			2,836			372			(600		)	(1,743		)	(3		)	(400		)	6,074			—		6,741
Ending balance	$	3,130		$	18,840	$	5,527		$	1,264		$	4,706		$	9		$	14,552		$	8,328		$	—	$	56,356			$	3,130		$	18,840		$	5,527		$	1,264		$	4,706		$	9		$	14,552		$	8,328		$	—	$	56,356
June 30, 2017
December 31, 2017
Ending balance: individually evaluated for impairment	$	1,332		$	73	$	275		$	480		$	—		$	—		$	939		$	30				$	3,129			$	1,248		$	65		$	647		$	47		$	—		$	—		$	694		$	29				$	2,730
Ending balance: collectively evaluated for impairment	$	1,798		$	18,767	$	5,252		$	784		$	4,706		$	9		$	13,613		$	8,298		$	—	$	53,227			$	1,654		$	15,731		$	6,875		$	849		$	4,671		$	12		$	10,157		$	10,958		$	—	$	50,907
Financing Receivables:
Ending balance	$	2,061,549		$	808,900	$	883,135		$	16,009		$	116,548		$	10,759		$	649,657		$	201,199				$	4,747,756			$	2,118,047		$	733,106		$	913,052		$	15,797		$	108,273		$	14,910		$	544,828		$	223,564				$	4,671,577
Ending balance: individually evaluated for impairment	$	19,188		$	1,289	$	6,684		$	2,589		$	—		$	—		$	4,283		$	68				$	34,101			$	18,284		$	1,016		$	8,188		$	1,265		$	—		$	—		$	4,574		$	66				$	33,393
Ending balance: collectively evaluated for impairment	$	2,042,361		$	807,611	$	876,451		$	13,420		$	116,548		$	10,759		$	645,374		$	201,131				$	4,713,655			$	2,099,763		$	732,090		$	904,864		$	14,532		$	108,273		$	14,910		$	540,254		$	223,498				$	4,638,184
Six months ended June 30, 2016
Allowance for loan losses:
Beginning balance	$	4,186		$	11,342	$	7,260		$	1,671		$	4,461		$	13		$	17,208		$	3,897		$	—	$	50,038
Charge-offs	(60		)	—		—			—			—			—			(2,305		)	(3,098		)	—		(5,463		)
Recoveries	52			—		31			119			—			—			560			475			—		1,237
Provision	206			2,219		545			(101		)	2,532			(1		)	1,622			2,497			—		9,519
Ending balance	$	4,384		$	13,561	$	7,836		$	1,689		$	6,993		$	12		$	17,085		$	3,771		$	—	$	55,331
December 31, 2016
Ending balance: individually evaluated for impairment	$	1,352		$	80	$	215		$	789		$	—		$	—		$	1,641		$	6				$	4,083
Ending balance: collectively evaluated for impairment	$	1,521		$	15,924	$	4,824		$	949		$	6,449		$	12		$	14,977		$	6,794		$	—	$	51,450
Financing Receivables:
Ending balance	$	2,048,051		$	800,395	$	863,163		$	18,889		$	126,768		$	16,080		$	692,051		$	178,222				$	4,743,619
Ending balance: individually evaluated for impairment	$	19,854		$	1,569	$	6,158		$	3,629		$	—		$	—		$	20,539		$	10				$	51,759
Ending balance: collectively evaluated for impairment	$	2,028,197		$	798,826	$	857,005		$	15,260		$	126,768		$	16,080		$	671,512		$	178,212				$	4,691,860

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Credit quality. ASB performs an internal loan review and grading on an ongoing basis. The review provides management with periodic information as to the quality of the loan portfolio and effectiveness of its lending policies and procedures. The objectives of the loan review and grading procedures are to identify, in a timely manner, existing or emerging credit trends so that appropriate steps can be initiated to manage risk and avoid or minimize future losses. Loans subject to grading include commercial, commercial real estate and commercial construction loans.

Each commercial and commercial real estate loan is assigned an Asset Quality Rating (AQR) reflecting the likelihood of repayment or orderly liquidation of that loan transaction pursuant to regulatory credit classifications: Pass, Special Mention, Substandard, Doubtful and Loss. The AQR is a function of the probability of default model rating, the loss given default and possible non-model factors which impact the ultimate collectability of the loan such as character of the business owner/guarantor, interim period performance, litigation, tax liens and major changes in business and economic conditions. Pass exposures generally are well protected by the current net worth and paying capacity of the obligor or by the value of the asset or underlying collateral. Special Mention loans have potential weaknesses that, if left uncorrected, could jeopardize the liquidation of the debt. Substandard loans have well-defined weaknesses that jeopardize the liquidation of the debt and are characterized by the distinct possibility that the Bank may sustain some loss. An asset classified Doubtful has the weaknesses of those classified Substandard, with the added characteristic that the weaknesses make collection or liquidation in full, on the basis of currently existing facts, conditions, and values, highly questionable and improbable. An asset classified Loss is considered uncollectible and has such little value that its continuance as a bankable asset is not warranted.

The credit risk profile by internally assigned grade for loans was as follows:


	June 30, 2017						December 31, 2016						June 30, 2018						December 31, 2017
(in thousands)	Commercial real estate		Commercial construction		Commercial		Commercial real estate		Commercial construction		Commercial		Commercial real estate		Commercial construction		Commercial		Commercial real estate		Commercial construction		Commercial
Grade:
Pass	$	660,015	$	92,069	$	602,903	$	701,657	$	102,955	$	614,139	$	671,592	$	99,632	$	539,168	$	630,877	$	83,757	$	492,942
Special mention	95,656		22,500		19,429		65,541		—		25,229		38,424		22,500		32,711		49,347		22,500		27,997
Substandard	53,229		1,979		27,325		33,197		23,813		52,683		48,819		2,289		21,717		52,882		2,016		23,421
Doubtful	—		—		—		—		—		—		—		—		—		—		—		468
Loss	—		—		—		—		—		—		—		—		—		—		—		—
Total	$	808,900	$	116,548	$	649,657	$	800,395	$	126,768	$	692,051	$	758,835	$	124,421	$	593,596	$	733,106	$	108,273	$	544,828

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

The credit risk profile based on payment activity for loans was as follows:


(in thousands)	30-59 days past due		60-89 days past due		Greater than 90 days		Total past due		Current		Total financing receivables		Recorded investment> 90 days and accruing		30-59 days past due		60-89 days past due		Greater than 90 days		Total past due		Current		Total financing receivables		Recorded investment> 90 days and accruing
June 30, 2017
June 30, 2018
Real estate:
Residential 1-4 family	$	2,308	$	2,694	$	5,411	$	10,413	$	2,051,136	$	2,061,549	$	—	$	2,975	$	1,348	$	4,360	$	8,683	$	2,091,267	$	2,099,950	$	—
Commercial real estate	—		—		—		—		808,900		808,900		—		—		725		—		725		758,110		758,835		—
Home equity line of credit	502		494		1,516		2,512		880,623		883,135		—		2,075		288		2,545		4,908		933,994		938,902		—
Residential land	—		—		305		305		15,704		16,009		—		741		111		631		1,483		14,549		16,032		—
Commercial construction	—		—		—		—		116,548		116,548		—		—		—		—		—		124,421		124,421		—
Residential construction	—		—		—		—		10,759		10,759		—		—		—		—		—		14,873		14,873		—
Commercial	1,486		614		1,096		3,196		646,461		649,657		—		1,721		491		551		2,763		590,833		593,596		—
Consumer	2,266		1,305		863		4,434		196,765		201,199		—		3,421		2,019		1,579		7,019		221,785		228,804		—
Total loans	$	6,562	$	5,107	$	9,191	$	20,860	$	4,726,896	$	4,747,756	$	—	$	10,933	$	4,982	$	9,666	$	25,581	$	4,749,832	$	4,775,413	$	—
December 31, 2016
December 31, 2017
Real estate:
Residential 1-4 family	$	5,467	$	2,338	$	3,505	$	11,310	$	2,036,741	$	2,048,051	$	—	$	1,532	$	1,715	$	5,071	$	8,318	$	2,109,729	$	2,118,047	$	—
Commercial real estate	2,416		—		—		2,416		797,979		800,395		—		—		—		—		—		733,106		733,106		—
Home equity line of credit	1,263		381		1,342		2,986		860,177		863,163		—		425		114		2,051		2,590		910,462		913,052		—
Residential land	—		—		255		255		18,634		18,889		—		23		—		625		648		15,149		15,797		—
Commercial construction	—		—		—		—		126,768		126,768		—		—		—		—		—		108,273		108,273		—
Residential construction	—		—		—		—		16,080		16,080		—		—		—		—		—		14,910		14,910		—
Commercial	413		510		1,303		2,226		689,825		692,051		—		1,825		2,025		730		4,580		540,248		544,828		—
Consumer	1,945		1,001		963		3,909		174,313		178,222		—		3,432		2,159		1,876		7,467		216,097		223,564		—
Total loans	$	11,504	$	4,230	$	7,368	$	23,102	$	4,720,517	$	4,743,619	$	—	$	7,237	$	6,013	$	10,353	$	23,603	$	4,647,974	$	4,671,577	$	—

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

The credit risk profile based on nonaccrual loans, accruing loans 90 days or more past due and ~~TDR~~troubled debt restructuring (TDR) loans was as follows:


(in thousands)	June 30, 2017		December 31, 2016		June 30, 2018		December 31, 2017
Real estate:
Residential 1-4 family	$	12,270	$	11,154	$	13,121	$	12,598
Commercial real estate	—		223		—		—
Home equity line of credit	4,306		3,080		6,051		4,466
Residential land	915		878		843		841
Commercial construction	—		—		—		—
Residential construction	—		—		—		—
Commercial	1,972		6,708		4,385		3,069
Consumer	1,501		1,282		2,820		2,617
Total nonaccrual loans	$	20,964	$	23,325	$	27,220	$	23,591
Real estate:
Residential 1-4 family	$	—	$	—	$	—	$	—
Commercial real estate	—		—		—		—
Home equity line of credit	—		—		—		—
Residential land	—		—		—		—
Commercial construction	—		—		—		—
Residential construction	—		—		—		—
Commercial	—		—		—		—
Consumer	—		—		—		—
Total accruing loans 90 days or more past due	$	—	$	—	$	—	$	—
Real estate:
Residential 1-4 family	$	13,112	$	14,450	$	10,777	$	10,982
Commercial real estate	1,289		1,346		993		1,016
Home equity line of credit	4,548		4,934		10,255		6,584
Residential land	1,674		2,751		328		425
Commercial construction	—		—		—		—
Residential construction	—		—		—		—
Commercial	2,692		14,146		1,716		1,741
Consumer	68		10		64		66
Total troubled debt restructured loans not included above	$	23,383	$	37,637	$	24,133	$	20,814

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

The total carrying amount and the total unpaid principal balance of impaired loans were as follows:


	June 30, 2017						Three months ended June 30, 2017				Six months ended June 30, 2017					June 30, 2018						Three months ended June 30, 2018				Six months ended June 30, 2018
(in thousands)	Recorded investment		Unpaid principal balance		Related Allowance		Average recorded investment		Interest income recognized*		Average recorded investment		Interest income recognized*			Recorded investment		Unpaid principal balance		Related Allowance		Average recorded investment		Interest income recognized*		Average recorded investment		Interest income recognized*
With no related allowance recorded															With no related allowance recorded
Real estate:
Residential 1-4 family	$	9,364	$	9,963	$	—	$	9,304	$	76	$	9,429	$	160		$	8,966	$	9,498	$	—	$	8,900	$	50	$	8,699	$	157
Commercial real estate	—		—		—		143		11		182		11			—		—		—		—		—		—		—
Home equity line of credit	2,287		2,707		—		2,401		51		2,203		65			2,505		2,803		—		2,374		7		2,037		12
Residential land	1,249		1,788		—		1,075		8		1,016		34			1,141		1,449		—		1,132		5		1,150		10
Commercial construction	—		—		—		—		—		—		—			—		—		—		—		—		—		—
Residential construction	—		—		—		—		—		—		—			—		—		—		—		—		—		—
Commercial	1,592		4,267		—		1,949		2		3,428		8			4,158		5,079		—		3,026		10		2,691		20
Consumer	—		—		—		1		—		—		—			33		33		—		15		—		11		—
	$	14,492	$	18,725	$	—	$	14,873	$	148	$	16,258	$	278		$	16,803	$	18,862	$	—	$	15,447	$	72	$	14,588	$	199
With an allowance recorded															With an allowance recorded
Real estate:
Residential 1-4 family	$	9,824	$	10,027	$	1,332	$	10,054	$	117	$	10,051	$	236		$	8,639	$	8,842	$	1,027	$	8,778	$	97	$	8,953	$	190
Commercial real estate	1,289		1,289		73		1,292		14		1,296		28			993		993		53		997		10		1,003		21
Home equity line of credit	4,397		4,425		275		4,372		47		4,467		96			11,344		11,414		1,161		10,420		96		9,080		177
Residential land	1,340		1,340		480		1,532		24		1,804		61			30		30		7		40		1		58		3
Commercial construction	—		—		—		—		—		—		—			—		—		—		—		—		—		—
Residential construction	—		—		—		—		—		—		—			—		—		—		—		—		—		—
Commercial	2,691		2,691		939		2,562		68		4,915		469			1,716		1,716		597		1,738		30		1,848		66
Consumer	68		68		30		68		1		49		1			58		58		3		58		1		58		2
	$	19,609	$	19,840	$	3,129	$	19,880	$	271	$	22,582	$	891		$	22,780	$	23,053	$	2,848	$	22,031	$	235	$	21,000	$	459
Total
Real estate:
Residential 1-4 family	$	19,188	$	19,990	$	1,332	$	19,358	$	193	$	19,480	$	396		$	17,605	$	18,340	$	1,027	$	17,678	$	147	$	17,652	$	347
Commercial real estate	1,289		1,289		73		1,435		25		1,478		39			993		993		53		997		10		1,003		21
Home equity line of credit	6,684		7,132		275		6,773		98		6,670		161			13,849		14,217		1,161		12,794		103		11,117		189
Residential land	2,589		3,128		480		2,607		32		2,820		95			1,171		1,479		7		1,172		6		1,208		13
Commercial construction	—		—		—		—		—		—		—			—		—		—		—		—		—		—
Residential construction	—		—		—		—		—		—		—			—		—		—		—		—		—		—
Commercial	4,283		6,958		939		4,511		70		8,343		477			5,874		6,795		597		4,764		40		4,539		86
Consumer	68		68		30		69		1		49		1			91		91		3		73		1		69		2
	$	34,101	$	38,565	$	3,129	$	34,753	$	419	$	38,840	$	1,169		$	39,583	$	41,915	$	2,848	$	37,478	$	307	$	35,588	$	658

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

December 31, 2016 Three months ended June 30, 2016 Six months ended June 30, 2016
(in thousands)
Recorded
investment

Unpaid
principal
balance

Related
allowance

Average
recorded
investment

Interest
income
recognized*

Average
recorded
investment

Interest
income
recognized*
With no related allowance recorded

Real estate:

Residential 1-4 family $ 9,571
$ 10,400
$ —
$ 10,672
$ 152
$ 10,532
$ 203
Commercial real estate 223
228
—
1,152
—
1,163
—
Home equity line of credit 1,500
1,900
—
1,038
9
943
9
Residential land 1,218
1,803
—
1,484
15
1,537
31
Commercial construction —
—
—
—
—
—
—
Residential construction —
—
—
—
—
—
—
Commercial 6,299
8,869
—
8,369
7
5,818
13
Consumer —
—
—
—
—
—
—
$ 18,811
$ 23,200
$ —
$ 22,715
$ 183
$ 19,993
$ 256
With an allowance recorded

Real estate:

Residential 1-4 family $ 10,283
$ 10,486
$ 1,352
$ 11,982
$ 115
$ 12,000
$ 237
Commercial real estate 1,346
1,346
80
2,519
—
1,686
—
Home equity line of credit 4,658
4,712
215
3,299
28
3,122
55
Residential land 2,411
2,411
789
2,977
54
3,177
121
Commercial construction —
—
—
—
—
—
—
Residential construction —
—
—
—
—
—
—
Commercial 14,240
14,240
1,641
16,821
180
16,896
210
Consumer 10
10
6
12
—
12
—
$ 32,948
$ 33,205
$ 4,083
$ 37,610
$ 377
$ 36,893
$ 623
Total

Real estate:

Residential 1-4 family $ 19,854
$ 20,886
$ 1,352
$ 22,654
$ 267
$ 22,532
$ 440
Commercial real estate 1,569
1,574
80
3,671
—
2,849
—
Home equity line of credit 6,158
6,612
215
4,337
37
4,065
64
Residential land 3,629
4,214
789
4,461
69
4,714
152
Commercial construction —
—
—
—
—
—
—
Residential construction —
—
—
—
—
—
—
Commercial 20,539
23,109
1,641
25,190
187
22,714
223
Consumer 10
10
6
12
—
12
—
$ 51,759
$ 56,405
$ 4,083
$ 60,325
$ 560
$ 56,886
$ 879



	December 31, 2017						Three months ended June 30, 2017				Six months ended June 30, 2017
(in thousands)	Recorded investment		Unpaid principal balance		Related allowance		Average recorded investment		Interest income recognized*		Average recorded investment		Interest income recognized*
With no related allowance recorded
Real estate:
Residential 1-4 family	$	9,097	$	9,644	$	—	$	9,304	$	76	$	9,429	$	160
Commercial real estate	—		—		—		143		11		182		11
Home equity line of credit	1,496		1,789		—		2,401		51		2,203		65
Residential land	1,143		1,434		—		1,075		8		1,016		34
Commercial construction	—		—		—		—		—		—		—
Residential construction	—		—		—		—		—		—		—
Commercial	2,328		3,166		—		1,949		2		3,428		8
Consumer	8		8		—		1		—		—		—
	$	14,072	$	16,041	$	—	$	14,873	$	148	$	16,258	$	278
With an allowance recorded
Real estate:
Residential 1-4 family	$	9,187	$	9,390	$	1,248	$	10,054	$	117	$	10,051	$	236
Commercial real estate	1,016		1,016		65		1,292		14		1,296		28
Home equity line of credit	6,692		6,736		647		4,372		47		4,467		96
Residential land	122		122		47		1,532		24		1,804		61
Commercial construction	—		—		—		—		—		—		—
Residential construction	—		—		—		—		—		—		—
Commercial	2,246		2,252		694		2,562		68		4,915		469
Consumer	58		58		29		68		1		49		1
	$	19,321	$	19,574	$	2,730	$	19,880	$	271	$	22,582	$	891
Total
Real estate:
Residential 1-4 family	$	18,284	$	19,034	$	1,248	$	19,358	$	193	$	19,480	$	396
Commercial real estate	1,016		1,016		65		1,435		25		1,478		39
Home equity line of credit	8,188		8,525		647		6,773		98		6,670		161
Residential land	1,265		1,556		47		2,607		32		2,820		95
Commercial construction	—		—		—		—		—		—		—
Residential construction	—		—		—		—		—		—		—
Commercial	4,574		5,418		694		4,511		70		8,343		477
Consumer	66		66		29		69		1		49		1
	$	33,393	$	35,615	$	2,730	$	34,753	$	419	$	38,840	$	1,169


*	Since loan was classified as impaired.

Troubled debt restructurings. A loan modification is deemed to be a ~~troubled debt restructuring (TDR)~~TDR when the borrower is determined to be experiencing financial difficulties and ASB grants a concession it would not otherwise ~~consider were it not for the borrower’s financial difficulty.~~consider. When a borrower experiencing financial difficulty fails to make a required payment on a loan or is in imminent default, ASB takes a number of steps to improve the ~~collectibility~~collectability of the loan and maximize the likelihood of full repayment. At times, ASB may modify or restructure a loan to help a distressed borrower improve its financial position to eventually be able to fully repay the loan, provided the borrower has demonstrated both the willingness and the ability to fulfill the modified terms. TDR loans are considered an alternative to foreclosure or liquidation with the goal of minimizing losses to ASB and maximizing recovery.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

ASB may consider various types of concessions in granting a TDR including maturity date extensions, extended amortization of principal, temporary deferral of principal payments and temporary interest rate reductions. ASB rarely grants

principal forgiveness in its TDR modifications. Residential loan modifications generally involve interest rate reduction, extending the amortization period, or capitalizing certain delinquent amounts owed not to exceed the original loan balance. Land loans at origination are typically structured as a three-year term, interest-only monthly payment with a balloon payment due at maturity. Land loan TDR modifications typically involve extending the maturity date up to five years and converting the payments from interest-only to principal and interest monthly, at the same or higher interest rate. Commercial loan modifications generally involve extensions of maturity dates, extending the amortization period and temporary deferral or reduction of principal payments. ASB generally does not reduce the interest rate on commercial loan TDR modifications. Occasionally, additional collateral and/or guaranties are obtained.

All TDR loans are classified as impaired and are segregated and reviewed separately when assessing the adequacy of the allowance for loan losses based on the appropriate method of measuring impairment: (1) present value of expected future cash flows discounted at the loan’s effective original contractual rate, (2) fair value of collateral less cost to sell or (3) observable market price. The financial impact of the calculated impairment amount is an increase to the allowance associated with the modified loan. When available information confirms that specific loans or portions thereof are uncollectible (confirmed losses), these amounts are charged off against the allowance for loan losses.

Loan modifications that occurred during the second quarters and first six months of ~~2017~~2018 and ~~2016~~2017 and the impact on the allowance for loan losses were as follows:



	Three months ended June 30, 2018							Six months ended June 30, 2018
	Number of contracts	Outstanding recorded investment¹				Net increase in allowance		Number of contracts	Outstanding recorded investment¹				Net increase in allowance
(dollars in thousands)	Number of contracts	Pre-modification		Post-modification		(as of period end)		Number of contracts	Pre-modification		Post-modification		(as of period end)
Troubled debt restructurings
Real estate:
Residential 1-4 family	—	$	—	$	—	$	—	1	$	339	$	344	$	16
Commercial real estate	—	—		—		—		—	—		—		—
Home equity line of credit	21	3,338		3,338		554		39	5,508		5,512		942
Residential land	—	—		—		—		1	109		109		—
Commercial construction	—	—		—		—		—	—		—		—
Residential construction	—	—		—		—		—	—		—		—
Commercial	2	43		43		42		7	2,294		2,294		42
Consumer	—	—		—		—		—	—		—		—
	23	$	3,381	$	3,381	$	596	48	$	8,250	$	8,259	$	1,000



	Three months ended June 30, 2017							Six months ended June 30, 2017
	Number of contracts	Outstanding recorded investment¹				Net increase in allowance		Number of contracts	Outstanding recorded investment¹				Net increase in allowance
(dollars in thousands)	Number of contracts	Pre-modification		Post-modification		(as of period end)		Number of contracts	Pre-modification		Post-modification		(as of period end)
Troubled debt restructurings
Real estate:
Residential 1-4 family	2	$	360	$	360	$	—	5	$	872	$	880	$	45
Commercial real estate	—	—		—		—		—	—		—		—
Home equity line of credit	5	298		298		59		13	524		510		93
Residential land	—	—		—		—		—	—		—		—
Commercial construction	—	—		—		—		—	—		—		—
Residential construction	—	—		—		—		—	—		—		—
Commercial	—	—		—		—		1	342		342		—
Consumer	—	—		—		—		1	59		59		27
	7	$	658	$	658	$	59	20	$	1,797	$	1,791	$	165

Three months ended June 30, 2016 Six months ended June 30, 2016
Number of contracts
Outstanding recorded
investment¹
Net increase in allowance Number of contracts
Outstanding recorded
investment¹
Net increase in allowance
(dollars in thousands) Pre-modification Post-modification (as of period end) Pre-modification Post-modification (as of period end)
Troubled debt restructurings

Real estate:

Residential 1-4 family 5
$ 891
$ 885
$ 98
9
$ 1,988
$ 2,100
$ 259
Commercial real estate —
—
—
—
—
—
—
—
Home equity line of credit 8
768
768
181
18
1,437
1,437
255
Residential land 1
120
121
—
1
120
121
—
Commercial construction —
—
—
—
—
—
—
—
Residential construction —
—
—
—
—
—
—
—
Commercial 5
457
457
145
8
16,657
16,657
670
Consumer —
—
—
—
—
—
—
—
19
$ 2,236
$ 2,231
$ 424
36
$ 20,202
$ 20,315
$ 1,184


¹	The reported balances include loans that became TDR during the period, and were fully paid-off, charged-off, or sold prior to period end.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Loans modified in TDRs that experienced a payment default of 90 days or more during the second quarters and first six months of ~~2017~~2018 and ~~2016,~~2017, and for which the payment of default occurred within one year of the modification, were as follows:


	Three months ended June 30, 2017			Six months ended June 30, 2017			Three months ended June 30, 2018			Six months ended June 30, 2018
(dollars in thousands)	Number of contracts	Recorded investment		Number of contracts	Recorded investment		Number of contracts	Recorded investment		Number of contracts	Recorded investment
Troubled debt restructurings that subsequently defaulted
Real estate:
Residential 1-4 family	1	$	222	2	$	523	—	$	—	—	$	—
Commercial real estate	—	—		—	—		—	—		—	—
Home equity line of credit	—	—		—	—		1	100		2	181
Residential land	—	—		—	—		—	—		—	—
Commercial construction	—	—		—	—		—	—		—	—
Residential construction	—	—		��	—		—	—		—	—
Commercial	—	—		—	—		1	291		1	291
Consumer	—	—		—	—		—	—		—	—
	1	$	222	2	$	523	2	$	391	3	$	472


	Three months ended June 30, 2016			Six months ended June 30, 2016			Three months ended June 30, 2017			Six months ended June 30, 2017
(dollars in thousands)	Number of contracts	Recorded investment		Number of contracts	Recorded investment		Number of contracts	Recorded investment		Number of contracts	Recorded investment
Troubled debt restructurings that subsequently defaulted
Real estate:
Residential 1-4 family	—	$	—	1	$	488	1	$	222	2	$	523
Commercial real estate	—	—		—	—		—	—		—	—
Home equity line of credit	—	—		—	—		—	—		—	—
Residential land	—	—		—	—		—	—		—	—
Commercial construction	—	—		—	—		—	—		—	—
Residential construction	—	—		—	—		—	—		—	—
Commercial	1	26		1	26		—	—		—	—
Consumer	—	—		—	—		—	—		—	—
	1	$	26	2	$	514	1	$	222	2	$	523

If loans modified in a TDR subsequently default, ASB evaluates the loan for further impairment. Based on its evaluation, adjustments may be made in the allocation of the allowance or partial charge-offs may be taken to further write-down the carrying value of the loan. Commitments to lend additional funds to borrowers whose loan terms have been modified in a TDR totaled ~~nil~~$0.01 million and ~~$2.6 million~~nil at June 30, ~~2017~~2018 and December 31, ~~2016, respectively.~~2017.

The Company had ~~$4.6~~$5.0 million and ~~$3.6~~$4.3 million of consumer mortgage loans collateralized by residential real estate property that were in the process of foreclosure at June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, respectively.

Mortgage servicing rights. In its mortgage banking business, ASB sells residential mortgage loans to government-sponsored entities and other parties, who may issue securities backed by pools of such loans. ASB retains no beneficial interests in these loans other than the servicing rights of certain loans sold.

ASB received proceeds from the sale of residential mortgages of ~~$39.3~~$44.3 million and ~~$58.1~~$39.3 million for the three months ended June 30, 2018 and 2017 and ~~2016~~$77.4 million and $79.9 ~~million and $98.5~~ million for the six months ended June 30, ~~2017~~2018 and ~~2016,~~2017, respectively, and recognized gains on such sales of $0.6 million ~~and $1.5 million~~ for both the three months ended June 30, 2018 and 2017 and ~~2016~~$1.2 million and $1.4 ~~million and $2.7~~ million for the six months ended June 30, ~~2017~~2018 and ~~2016,~~2017, respectively.

There were no repurchased mortgage loans for the three and six months ended June 30, ~~2017~~2018 and ~~2016.~~2017. The repurchase reserve was $0.1 million as of June 30, ~~2017~~2018 and ~~2016.~~2017.

Mortgage servicing fees, a component of other income, net, were $0.8 million and $0.7 million for ~~both~~ the three months ended June 30, 2018 and 2017, ~~and 2016~~respectively, and $1.5 million ~~and $1.4 million~~ for both the six months ended June 30, ~~2017~~2018 and ~~2016, respectively.~~2017.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Changes in the carrying value of mortgage servicing rights were as follows:



(in thousands)	Gross carrying amount¹		Accumulated amortization¹			Valuation allowance		Net carrying amount
June 30, 2018	$	18,238	$	(9,729	)	$	—	$	8,509
December 31, 2017	17,511		(8,872		)	—		8,639

(in thousands)
Gross
carrying amount¹

Accumulated amortization¹
Valuation allowance Net
carrying amount
June 30, 2017 $ 18,069
$ (8,888 ) $ —
$ 9,181
December 31, 2016 17,271
(7,898 ) —
9,373

¹ Reflects the impact of loans paid in full.

Changes related to mortgage servicing rights were as follows:


	Three months ended June 30						Six months ended June 30						Three months ended June 30						Six months ended June 30
(in thousands)	2017			2016			2017			2016			2018			2017			2018			2017
Mortgage servicing rights
Beginning balance	$	9,294		$	8,857		$	9,373		$	8,884		$	8,541		$	9,294		$	8,639		$	9,373
Amount capitalized	362			665			798			1,120			392			362			727			798
Amortization	(475		)	(506		)	(990		)	(988		)	(424		)	(475		)	(857		)	(990		)
Other-than-temporary impairment	—			—			—			—			—			—			—			—
Carrying amount before valuation allowance	9,181			9,016			9,181			9,016			8,509			9,181			8,509			9,181
Valuation allowance for mortgage servicing rights
Beginning balance	—			—			—			—			—			—			—			—
Provision (recovery)	—			—			—			—			—			—			—			—
Other-than-temporary impairment	—			—			—			—			—			—			—			—
Ending balance	—			—			—			—			—			—			—			—
Net carrying value of mortgage servicing rights	$	9,181		$	9,016		$	9,181		$	9,016		$	8,509		$	9,181		$	8,509		$	9,181

ASB capitalizes mortgage servicing rights (MSRs) acquired ~~through either the purchase or~~ upon the sale of mortgage loans with servicing rights retained. On a monthly basis, ASB compares the net carrying value of the mortgage servicing rights to its fair value to determine if there are any changes to the valuation allowance and/or other-than-temporary impairment for the mortgage servicing rights. ASB’s MSRs are stratified based on predominant risk characteristics of the underlying loans including loan type such as fixed-rate 15 and 30 year mortgages and note rate in bands of 50 to 100 basis points. For each stratum, fair value is calculated by discounting expected net income streams using discount rates that reflect industry pricing for similar assets. Changes in mortgage interest rates impact the value of ASB’s mortgage servicing rights. Rising interest rates typically result in slower prepayment speeds in the loans being serviced for others, which increases the value of mortgage servicing rights, whereas declining interest rates typically result in faster prepayment speeds which decrease the value of mortgage servicing rights and increase the amortization of the mortgage servicing rights. Expected net income streams are estimated based on industry assumptions regarding prepayment expectations and income and expenses associated with servicing residential mortgage loans for others.

ASB uses a present value cash flow model using techniques described above to estimate the fair value of MSRs. Impairment is recognized through a valuation allowance for each stratum when the carrying amount exceeds fair value, with any associated provision recorded as a component of loan servicing fees included in “Revenues - bank” in the consolidated statements of income. A direct write-down is recorded when the recoverability of the valuation allowance is deemed to be unrecoverable.

Key assumptions used in estimating the fair value of ASB’s mortgage servicing rights used in the impairment analysis were as follows:


(dollars in thousands)	June 30, 2017			December 31, 2016			June 30, 2018			December 31, 2017
Unpaid principal balance	$	1,208,404		$	1,188,380		$	1,192,901		$	1,195,454
Weighted average note rate	3.95		%	3.96		%	3.96		%	3.94		%
Weighted average discount rate	10.0		%	9.4		%	10.0		%	10.0		%
Weighted average prepayment speed	8.8		%	8.5		%	6.8		%	9.0		%

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

The sensitivity analysis of fair value of MSRs to hypothetical adverse changes of 25 and 50 basis points in certain key assumptions was as follows:


(dollars in thousands)	June 30, 2017			December 31, 2016			June 30, 2018			December 31, 2017
Prepayment rate:
25 basis points adverse rate change	$	(939	)	$	(567	)	$	(344	)	$	(869	)
50 basis points adverse rate change	(2,048		)	(1,154		)	(797		)	(1,828		)
Discount rate:
25 basis points adverse rate change	(115		)	(128		)	(135		)	(111		)
50 basis points adverse rate change	(227		)	(254		)	(268		)	(220		)

The effect of a variation in certain assumptions on fair value is calculated without changing any other assumptions. This analysis typically cannot be extrapolated because the relationship of a change in one key assumption to the changes in the fair value of MSRs typically is not linear.

Other borrowings. Securities sold under agreements to repurchase are accounted for as financing transactions and the obligations to repurchase these securities are recorded as liabilities in the condensed consolidated balance ~~sheet.~~sheets. ASB pledges investment securities as collateral for securities sold under agreements to repurchase. All such agreements are subject to master netting arrangements, which provide for a conditional right of set-off in case of default by either party; however, ASB presents securities sold under agreements to repurchase on a gross basis in the balance sheet. The following tables present information about the securities sold under agreements to repurchase, including the related collateral received from or pledged to counterparties:


(in millions)	Gross amount of recognized liabilities	Gross amount offset in the Balance Sheet	Net amount of liabilities presented in the Balance Sheet	Gross amount of recognized liabilities		Gross amount offset in the Balance Sheet		Net amount of liabilities presented in the Balance Sheet
Repurchase agreements
June 30, 2017	$88	$—	$88
December 31, 2016	93	—	93
June 30, 2018				$	77	$	—	$	77
December 31, 2017				141		—		141

Gross amount not offset in the Balance Sheet
(in millions)
Net amount of liabilities presented
in the Balance Sheet

Financial
instruments

Cash
collateral
pledged
June 30, 2017

Financial institution $ —
$ —
$ —
Government entities —
—
—
Commercial account holders 88
120
—
Total $ 88
$ 120
$ —
December 31, 2016

Financial institution $ —
$ —
$ —
Government entities 14
15
—
Commercial account holders 79
101
—
Total $ 93
$ 116
$ —



	Gross amount not offset in the Balance Sheet
(in millions)	Net amount of liabilities presented in the Balance Sheet		Financial instruments		Cash collateral pledged
June 30, 2018
Commercial account holders	$	77	$	193	$	—
Total	$	77	$	193	$	—
December 31, 2017
Commercial account holders	$	141	$	165	$	—
Total	$	141	$	165	$	—

The securities underlying the agreements to repurchase are book-entry securities and were delivered by appropriate entry into the counterparties’ accounts or into segregated tri-party custodial accounts at the FHLB. Securities sold under agreements to repurchase are accounted for as financing transactions and the obligations to repurchase these securities are recorded as liabilities in the consolidated balance sheets. The securities underlying the agreements to repurchase continue to be reflected in ASB’s asset accounts.

Derivative financial instruments. ASB enters into interest rate lock commitments (IRLCs) with borrowers, and forward commitments to sell loans or to-be-announced mortgage-backed securities to investors to hedge against the inherent interest rate and pricing risks associated with selling loans.

ASB enters into IRLCs for residential mortgage loans, which commit ASB to lend funds to a potential borrower at a specific interest rate and within a specified period of time. IRLCs that relate to the origination of mortgage loans that will be held for sale are considered derivative financial instruments under applicable accounting guidance. Outstanding IRLCs expose

ASB to the risk that the price of the mortgage loans underlying the commitments may decline due to increases in mortgage interest rates from inception of the rate lock to the funding of the loan. The IRLCs are free-standing derivatives which are carried at fair value with changes recorded in mortgage banking income.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

ASB enters into forward commitments to hedge the interest rate risk for rate locked mortgage applications in process and closed mortgage loans held for sale. These commitments are primarily forward sales of to-be-announced mortgage backed securities. Generally, when mortgage loans are closed, the forward commitment is liquidated and replaced with a mandatory delivery forward sale of the mortgage to a secondary market investor. In some cases, a best-efforts forward sale agreement is utilized as the forward commitment. These commitments are free-standing derivatives which are carried at fair value with changes recorded in mortgage banking income.

Changes in the fair value of IRLCs and forward commitments subsequent to inception are based on changes in the fair value of the underlying loan resulting from the fulfillment of the commitment and changes in the probability that the loan will fund within the terms of the commitment, which is affected primarily by changes in interest rates and the passage of time.

The notional amount and fair value of ASB’s derivative financial instruments were as follows:


	June 30, 2017				December 31, 2016					June 30, 2018					December 31, 2017
(in thousands)	Notional amount		Fair value		Notional amount		Fair value			Notional amount		Fair value			Notional amount		Fair value
Interest rate lock commitments	$	22,737	$	126	$	25,883	$	421		$	21,954	$	248		$	13,669	$	131
Forward commitments	22,925		88		30,813		(177		)	24,911		(62		)	14,465		(24		)

ASB’s derivative financial instruments, their fair values and balance sheet location were as follows:


Derivative Financial Instruments Not Designated as Hedging Instruments ¹	June 30, 2017				December 31, 2016				June 30, 2018				December 31, 2017
(in thousands)	Asset derivatives		Liability derivatives		Asset derivatives		Liability derivatives		Asset derivatives		Liability derivatives		Asset derivatives		Liability derivatives
Interest rate lock commitments	$	142	$	16	$	445	$	24	$	248	$	—	$	133	$	2
Forward commitments	88		—		8		185		2		64		4		28
	$	230	$	16	$	453	$	209	$	250	$	64	$	137	$	30

¹ Asset derivatives are included in other assets and liability derivatives are included in other liabilities in the balance sheets.

The following table presents ASB’s derivative financial instruments and the amount and location of the net gains or losses recognized in ASB’s statements of income:


Derivative Financial Instruments Not Designated as Hedging Instruments	Location of net gains (losses) recognized in the Statement of Income		Three months ended June 30								Six months ended June 30							Location of net gains (losses) recognized in the Statement of Income		Three months ended June 30								Six months ended June 30
(in thousands)		2017				2016				2017				2016					2018				2017				2018				2017
Interest rate lock commitments		Mortgage banking income		$	(191	)		$	140			$	(295	)		$	411		Mortgage banking income		$	(7	)		$	(191	)		$	117			$	(295	)
Forward commitments	Mortgage banking income		192				(74		)		265				(237		)	Mortgage banking income		(2		)		192				(38		)		265
			$	1			$	66			$	(30	)		$	174				$	(9	)		$	1			$	79			$	(30	)

Low-Income Housing Tax Credit (LIHTC). ASB’s unfunded commitments to fund its LIHTC investment partnerships were ~~$14.3~~$20.6 million and ~~$14.0~~$15.8 million at June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, respectively. These unfunded commitments were unconditional and legally binding and are recorded in other liabilities with a corresponding increase in other assets. As of June 30, ~~2017,~~2018, ASB did not have any impairment losses resulting from forfeiture or ineligibility of tax credits or other circumstances related to its LIHTC investment partnerships.

Contingencies. ASB is subject in the normal course of business to pending and threatened legal proceedings. Management does not anticipate that the aggregate ultimate liability arising out of these pending or threatened legal proceedings will be material to its financial position. However, ASB cannot rule out the possibility that such outcomes could have a material adverse effect on the results of operations or liquidity for a particular reporting period in the future.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Note 5 · Credit agreements and long-term debt

Credit agreements. HEI and Hawaiian Electric each entered into a separate agreement with a syndicate of eight financial institutions (the HEI Facility and Hawaiian Electric Facility, respectively, and together, the Facilities), effective July 3, 2017, to

amend and restate their respective previously existing revolving unsecured credit agreements. The $150 million HEI Facility extended the term of the facility to June 30, 2022. ~~The~~In March 2018, the PUC approved Hawaiian Electric’s request to extend the term of the $200 million Hawaiian Electric Facility ~~has an initial term that expires on June 29, 2018, but its term will extend~~ to June 30, ~~2022, if and when approved by the PUC during the initial term.~~2022. As of June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, no amounts were outstanding under the ~~previously existing facilities.~~Facilities.

The Facilities will be maintained to support each company’s respective short-term commercial paper program, but may be drawn on to meet each company’s respective working capital needs and general corporate purposes.

Changes in long-term debt. On ~~June 29, 2017, the Department of Budget and Finance of the State of Hawaii (Department) for the benefit of~~May 30, 2018, the Utilities issued, ~~at par:~~through a private placement pursuant to separate Note Purchase Agreements (the Note Purchase Agreements), the following unsecured notes bearing taxable interest (the Notes):


	Refunding Series 2017A Special Purpose Revenue Bonds	Refunding Series 2017B Special Purpose Revenue Bonds	Series 2018A	Series 2018B	Series 2018C
Aggregate principal amount	$125 million	$140 million	$67.5 million	$17.5 million	$15 million
Fixed coupon interest rate	3.10%	4.00%	4.38%	4.53%	4.72%
Maturity date	May 1, 2026	March 1, 2037	May 30, 2028	March 30, 2033	May 30, 2048
Department loaned the proceeds to:
Principal amount by company:
Hawaiian Electric	$62 million	$100 million	$52 million	$12.5 million	$10.5 million
Hawaii Electric Light	$8 million	$20 million	$9 million	$3 million
Maui Electric	$55 million	$20 million	$6.5 million	$2 million	$1.5 million

~~Proceeds from~~The Notes include substantially the ~~sale~~same financial covenants and customary conditions as Hawaiian Electric’s credit agreement. Hawaiian Electric is also a party as guarantor under the Note Purchase Agreements entered into by Hawaii Electric Light and Maui Electric. All the proceeds of the Notes were ~~applied~~used by Hawaiian Electric, Hawaii Electric Light and Maui Electric to ~~redeem at par bonds previously issued by the Department~~finance their capital expenditures and/or to reimburse funds used for the ~~benefit~~payment of capital expenditures. The Notes may be prepaid in whole or in part at any time at the prepayment price of the ~~Utilities:~~principal amount plus a “Make-Whole Amount,” as defined in the Note Purchase Agreements.

Refunding Series 2007B Special Purpose Revenue Bonds Series 2007A Special Purpose Revenue Bonds
Aggregate principal amount $125 million $140 million
Fixed coupon interest rate 4.60% 4.65%
Maturity date May 1, 2026 March 1, 2037
In June 2018, Mauo, LLC, an indirect subsidiary of Pacific Current, LLC, entered into an unsecured $50.5 million construction loan facility in connection with the construction of the solar-plus-storage PPA project. The loan bears interest at LIBOR plus 1.375% and matures in March 2021. As of June 30, 2018, no amounts were outstanding under the facility. The loan is guaranteed by HEI.

Note 6 · Shareholders’ equity

Accumulated other comprehensive income/(loss). Changes in the balances of each component of accumulated other comprehensive income/(loss) (AOCI) were as follows:


	HEI Consolidated												Hawaiian Electric Consolidated								HEI Consolidated												Hawaiian Electric Consolidated
(in thousands)	Net unrealized gains (losses) on securities			Unrealized gains (losses) on derivatives			Retirement benefit plans			AOCI			Unrealized gains (losses) on derivatives			Retirement benefit plans		AOCI			Net unrealized gains (losses) on securities			Unrealized gains (losses) on derivatives			Retirement benefit plans			AOCI			Unrealized gains (losses) on derivatives			Retirement benefit plans			AOCI
Balance, December 31, 2017																					$	(14,951	)	$	—		$	(26,990	)	$	(41,941	)	$	—		$	(1,219	)	$	(1,219	)
Current period other comprehensive income (loss)																					(17,645		)	—			1,047			(16,598		)	—			57			57
Balance, June 30, 2018																					$	(32,596	)	$	—		$	(25,943	)	$	(58,539	)	$	—		$	(1,162	)	$	(1,162	)
Balance, December 31, 2016	$	(7,931	)	$	(454	)	$	(24,744	)	$	(33,129	)	$	(454	)	$	132	$	(322	)	$	(7,931	)	$	(454	)	$	(24,744	)	$	(33,129	)	$	(454	)	$	132		$	(322	)
Current period other comprehensive income	2,244			454			657			3,355			454			45		499			2,244			454			657			3,355			454			45			499
Balance, June 30, 2017	$	(5,687	)	$	—		$	(24,087	)	$	(29,774	)	$	—		$	177	$	177		$	(5,687	)	$	—		$	(24,087	)	$	(29,774	)	$	—		$	177		$	177
Balance, December 31, 2015	$	(1,872	)	$	(54	)	$	(24,336	)	$	(26,262	)	$	—		$	925	$	925
Current period other comprehensive income	9,984			311			613			10,908			257			4		261
Balance, June 30, 2016	$	8,112		$	257		$	(23,723	)	$	(15,354	)	$	257		$	929	$	1,186

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Reclassifications out of AOCI were as follows:


	Amount reclassified from AOCI						Amount reclassified from AOCI							Amount reclassified from AOCI
	Three months ended June 30						Six months ended June 30						Affected line item in the	Three months ended June 30						Six months ended June 30						Affected line item in the
(in thousands)	2017			2016			2017			2016			Statements of Income / Balance Sheets	2018			2017			2018			2017			Statements of Income / Balance Sheets
HEI consolidated
Net realized gains on securities included in net income	$	—		$	(360	)	$	—		$	(360	)	Revenues-bank (net gains on sales of securities)
Derivatives qualifying as cash flow hedges:
Window forward contracts	—			—			454			—			Construction in progress-electric utilities (losses on window forward contracts - see Note 3 for additional details)	$	—		$	—		$	—		$	454		Property, plant and equipment-electric utilities
Interest rate contracts (settled in 2011)	—			—			—			54			Interest expense
Retirement benefit plans:
Amortization of prior service credit and net losses recognized during the period in net periodic benefit cost	3,930			3,698			7,851			7,236			See Note 7 for additional details	5,350			3,930			10,496			7,851			See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets	(3,581		)	(3,401		)	(7,194		)	(6,623		)	See Note 7 for additional details	(4,827		)	(3,581		)	(9,449		)	(7,194		)	See Note 8 for additional details
Total reclassifications	$	349		$	(63	)	$	1,111		$	307			$	523		$	349		$	1,047		$	1,111
Hawaiian Electric consolidated
Derivatives qualifying as cash flow hedges:
Window forward contracts	$	—		$	—		$	454		$	—		Construction in progress (losses on window forward contracts - see Note 3 for additional details)	$	—		$	—		$	—		$	454		Property, plant and equipment
Retirement benefit plans:
Amortization of prior service credit and net losses recognized during the period in net periodic benefit cost	3,621			3,391			7,239			6,627			See Note 7 for additional details	4,853			3,621			9,506			7,239			See Note 8 for additional details
Impact of D&Os of the PUC included in regulatory assets	(3,581		)	(3,401		)	(7,194		)	(6,623		)	See Note 7 for additional details	(4,827		)	(3,581		)	(9,449		)	(7,194		)	See Note 8 for additional details
Total reclassifications	$	40		$	(10	)	$	499		$	4			$	26		$	40		$	57		$	499

Note 7 · Revenues

Adoption of ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” In the first quarter of 2018, the Company and Hawaiian Electric adopted ASU No. 2014-09, “Revenue from Contracts with Customers (Topic 606),” using the modified retrospective method. Results for reporting periods beginning after January 1, 2018 are presented under Topic 606, while prior period amounts are not adjusted and continue to be reported in accordance with accounting standards in effect for those periods. The adoption of Topic 606 had no significant impact on the timing or pattern of revenue recognition for the Company or Hawaiian Electric. No practical expedients were used by the Company or Hawaiian Electric in the adoption of ASU No. 2014-09.

Revenue from contracts with customers. The revenues subject to Topic 606 include the Utilities’ electric energy sales revenue and the Utilities’ and ASB’s transaction fees, as further described below.

Electric Utilities.

Electric energy sales and fees under tariff.Electric energy sales represent revenues from the generation and transmission of electricity to customers and utility fees include transaction-based fees associated with the delivery of electricity provided by the Utilities under tariffs approved by the PUC.

Electric energy sales under tariff- Transaction pricing for electricity is determined and approved by the PUC for each rate class and includes revenues from the base electric charges, which are composed of (1) the customer, demand, energy, and minimum charges, and (2) the power factor, service voltage, and other adjustments as provided in each rate and rate rider schedule. The Utilities satisfy performance obligations over time, i.e., the Utilities generate and transfer control of the electricity over time as the customer simultaneously receives and consumes the benefits provided by the Utilities' performance. Payments from customers are generally due within 30 days from the end of the billing period.

Utility fees - Pricing for transaction fees associated with electric service are set and approved by the PUC. Adjustments to the fee schedules are either requested by the Utilities during ratemaking years or during off cycle periods as needed. Such transaction fees include connection fees, late payment fees and other one-time transaction fees. These transaction-

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

based fees are recognized at the point in time when the transaction has occurred and the performance obligation satisfied (e.g., connection fees are recognized when an electric connection is completed).

Bank.

Bankfees. Bank fees are primarily transaction-based and are recognized when the transaction has occurred and the performance obligation satisfied. From time to time, customers will request a fee waiver and ASB may grant reversals of fees. Revenues are not recorded for the estimated amount of fee reversals for each period. Under the new standard, certain fees paid to third parties that were previously recognized as a component of noninterest expense are now netted with fee income. The change in presentation will have no effect on the reported amount of operating income.

Fees from other financial services - These fees primarily include debit card interchange income and fees, automated teller machine fees, credit card interchange income and fees, check ordering fees, wire fees, safe deposit rental fees, corporate/business fees, merchant income, online banking fees and international banking fees. Amounts paid to third parties for payment network expenses are included in this financial statement caption in ASB’s Statements of Income Data (in Revenues—Bank financial statement caption of HEI’s Consolidated Statements of Income). Previously, these expenses were recorded in the other expense financial statement caption of ASB’s Statements of Income Data (in Expenses—Bank financial statement caption of HEI’s Consolidated Statements of Income).

Fee income on deposit liabilities - These fees primarily include “not sufficient funds” fees, monthly deposit account service charge fees, commercial account analysis fees and other deposit fees.

Fee income on other financial products - These fees primarily include commission income from the sales of annuity, mutual fund, and life insurance products. In 2017, ASB began offering a fee-based, managed account product in which income is based on a percentage of assets under management. ASB satisfies its performance obligations under the managed account arrangement over time, and consequently, fees for assets under management are recognized over time as the customer simultaneously receives and consumes the benefit of asset management services. Fees recognized to date from the managed account product were minimal.

Revenues from other sources. Revenues from other sources not subject to Topic 606 are accounted for as follows:

Electric Utilities.

Regulatory revenues. Regulatory revenues primarily consist of revenues from decoupling mechanism, cost recovery surcharges and the Tax Act adjustments.

Decoupling mechanism - Under the decoupling mechanism, the Utilities are allowed to recover or refund the difference between actual revenue and the target revenue as determined by the PUC. These adjustments will be reflected in tariffs in future periods.

Cost recovery surcharges- For the timely recovery of additional costs incurred, and reconciliation of costs and expenses included in tariffed rates, the Utilities recognize revenues under surcharge mechanisms approved by the PUC. These will be reflected in tariffs in future periods (e.g., ECAC and PPAC).

Tax Act adjustments - These represent adjustments to revenues for the amounts included in tariffed revenues that will be returned to customers as a result of the Tax Act.

Since revenue adjustments discussed above resulted from either agreements with the PUC or change in tax law, rather than contracts with customers, they are not subject to the scope of Topic 606. See Notes 1, 3 and 10 to the audited consolidated financial statements in the Company’s Form 10-K for the year ended December 31, 2017.

Bank.

Interest and dividend income. Interest and fees on loans are recognized in accordance with ASC Topic 310, Receivables, including the related allowance for loan losses. Interest and dividends on investment securities are recognized in accordance with ASC Topic 320, Investments-Debt and Equity Securities. See Notes 1 and 4 to the audited consolidated financial statements in the Company’s Form 10-K for the year ended December 31, 2017.

Other bank noninterest income. Other bank noninterest income primarily consists of mortgage banking income and bank-owned life insurance income.

Mortgage banking income - Mortgage banking income consists primarily of realized and unrealized gains on sale of loans accounted for pursuant to ASC Topic 860, Transfers and Servicing. Interest rate lock commitments and forward loan sales are considered derivatives and are accounted pursuant to ASC Topic 815, Derivatives and Hedging.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

7Bank-Owned Life Insurance (BOLI) - The recognition of BOLI cash surrender value does not represent a contract with a customer and is accounted for in accordance with Emerging Issues Task Force Issue 06-05, Accounting for Purchases of Life Insurance-Determining the Amount that Could be Realized in Accordance with FASB Technical Bulletin No. 85-4, Accounting for Purchases of Life Insurance.

Revenue disaggregation. The following tables disaggregates revenues by major source, timing of revenue recognition, and segment:



	Three months ended June 30, 2018										Six months ended June 30, 2018
	Electric utility			Bank		Other		Total			Electric utility		Bank		Other		Total
(in thousands)
Revenues from contracts with customers
Electric energy sales - residential	$	185,217		$	—	$	—	$	185,217		$	363,806	$	—	$	—	$	363,806
Electric energy sales - commercial	206,169			—		—		206,169			395,167		—		—		395,167
Electric energy sales - large light and power	214,676			—		—		214,676			406,997		—		—		406,997
Electric energy sales - other	3,217			—		—		3,217			6,480		—		—		6,480
Utility fees	751			—		—		751			1,548		—		—		1,548
Bank fees	—			11,557		—		11,557			—		23,054		—		23,054
Total revenues from contracts with customers	610,030			11,557		—		621,587			1,173,998		23,054		—		1,197,052
Revenues from other sources
Regulatory revenue	(4,643		)	—		—		(4,643		)	107		—		—		107
Bank interest and dividend income	—			63,261		—		63,261			—		125,263		—		125,263
Other bank noninterest income	—			2,286		—		2,286			—		4,206		—		4,206
Other	2,739			—		47		2,786			4,448		—		75		4,523
Total revenues from other sources	(1,904		)	65,547		47		63,690			4,555		129,469		75		134,099
Total revenues	$	608,126		$	77,104	$	47	$	685,277		$	1,178,553	$	152,523	$	75	$	1,331,151
Timing of revenue recognition
Services/goods transferred at a point in time	$	751		$	11,557	$	—	$	12,308		$	1,548	$	23,054	$	—	$	24,602
Services/goods transferred over time	609,279			—		—		609,279			1,172,450		—		—		1,172,450
Total revenues from contracts with customers	$	610,030		$	11,557	$	—	$	621,587		$	1,173,998	$	23,054	$	—	$	1,197,052

There are no material contract assets or liabilities associated with revenues from contracts with customers existing at the beginning or at the end of the six months ended June 30, 2018. Accounts receivable and unbilled revenues related to contracts with customers represent an unconditional right to consideration since all performance obligations have been satisfied. These amounts are disclosed as accounts receivable and unbilled revenues, net on HEI’s condensed consolidated balance sheets and customer accounts receivable, net and accrued unbilled revenues, net on Hawaiian Electric’s condensed consolidated balance sheets.

As of June 30, 2018, the Company had no material remaining performance obligations due to the nature of the Company’s contracts with its customers. For the Utilities, performance obligations are fulfilled as electricity is delivered to customers. For the bank, fees are recognized when a transaction is completed.

Note 8 · Retirement benefits

Defined benefit pension and other postretirement benefit plans information. For the first six months of ~~2017~~2018, the Company contributed $3332 million ~~(nearly all~~($32 million by the Utilities) to its pension and other postretirement benefit plans, compared to $33 million ($3233 million by the Utilities) in the first six months of ~~2016.~~2017. The Company’s current estimate of contributions to its pension and other postretirement benefit plans in ~~2017~~2018 is ~~$67~~$42 million ($6641 million by the Utilities, $1 million by HEI and nil by ASB), compared to $6567 million ($6466 million by the Utilities, $1 million by HEI and nil by ASB) in ~~2016~~2017. In addition, the Company expects to pay directly $2 million ($1 million by the Utilities) of benefits in ~~2017~~2018, compared to $2$1 million ($10.5 million by the Utilities) paid in ~~2016~~2017.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

The components of NPPC and NPBC for HEI consolidated and Hawaiian Electric consolidated were as follows:


	Three months ended June 30												Six months ended June 30												Three months ended June 30												Six months ended June 30
	Pension benefits						Other benefits						Pension benefits						Other benefits						Pension benefits						Other benefits						Pension benefits						Other benefits
(in thousands)	2017			2016			2017			2016			2017			2016			2017			2016			2018			2017			2018			2017			2018			2017			2018			2017
HEI consolidated
Service cost	$	15,870		$	14,913		$	847		$	832		$	32,364		$	30,304		$	1,687		$	1,668		$	17,428		$	15,870		$	692		$	847		$	34,541		$	32,364		$	1,361		$	1,687
Interest cost	20,361			20,481			2,315			2,363			40,577			40,758			4,726			4,837			19,459			20,361			2,030			2,315			38,693			40,577			3,961			4,726
Expected return on plan assets	(25,646		)	(24,616		)	(3,104		)	(3,091		)	(51,367		)	(49,280		)	(6,170		)	(6,143		)	(27,224		)	(25,646		)	(3,267		)	(3,104		)	(54,478		)	(51,367		)	(6,459		)	(6,170		)
Amortization of net prior service gain	(13		)	(14		)	(448		)	(448		)	(27		)	(28		)	(897		)	(896		)	(11		)	(13		)	(451		)	(448		)	(21		)	(27		)	(903		)	(897		)
Amortization of net actuarial loss	6,707			6,408			199			116			13,220			12,377			565			403			7,634			6,707			48			199			15,029			13,220			46			565
Net periodic pension/benefit cost	17,279			17,172			(191		)	(228		)	34,767			34,131			(89		)	(131		)
Net periodic pension/benefit cost (return)																									17,286			17,279			(948		)	(191		)	33,764			34,767			(1,994		)	(89		)
Impact of PUC D&Os	(4,867		)	(4,765		)	527			483			(10,023		)	(8,811		)	673			672			7,179			(4,867		)	1,024			527			9,836			(10,023		)	2,095			673
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)	$	12,412		$	12,407		$	336		$	255		$	24,744		$	25,320		$	584		$	541		$	24,465		$	12,412		$	76		$	336		$	43,600		$	24,744		$	101		$	584
Hawaiian Electric consolidated
Service cost	$	15,436		$	14,465		$	841		$	820		$	31,530		$	29,398		$	1,676		$	1,642		$	17,007		$	15,436		$	688		$	841		$	33,680		$	31,530		$	1,352		$	1,676
Interest cost	18,726			18,801			2,231			2,280			37,315			37,404			4,558			4,669			17,937			18,726			1,955			2,231			35,647			37,315			3,814			4,558
Expected return on plan assets	(23,935		)	(22,885		)	(3,056		)	(3,046		)	(47,946		)	(45,817		)	(6,073		)	(6,049		)	(25,577		)	(23,935		)	(3,216		)	(3,056		)	(51,184		)	(47,946		)	(6,356		)	(6,073		)
Amortization of net prior service loss (gain)	2			3			(451		)	(451		)	4			7			(902		)	(902		)	2			2			(451		)	(451		)	4			4			(902		)	(902		)
Amortization of net actuarial loss	6,190			5,885			192			113			12,196			11,346			551			397			6,941			6,190			49			192			13,651			12,196			49			551
Net periodic pension/benefit cost	16,419			16,269			(243		)	(284		)	33,099			32,338			(190		)	(243		)
Net periodic pension/benefit cost (return)																									16,310			16,419			(975		)	(243		)	31,798			33,099			(2,043		)	(190		)
Impact of PUC D&Os	(4,867		)	(4,765		)	527			483			(10,023		)	(8,811		)	673			672			7,179			(4,867		)	1,024			527			9,836			(10,023		)	2,095			673
Net periodic pension/benefit cost (adjusted for impact of PUC D&Os)	$	11,552		$	11,504		$	284		$	199		$	23,076		$	23,527		$	483		$	429		$	23,489		$	11,552		$	49		$	284		$	41,634		$	23,076		$	52		$	483

HEI consolidated recorded retirement benefits expense of $1727 million ($1525 million by the Utilities) and $1817 million ($1615 million by the Utilities) in the first six months of ~~2017~~2018 and ~~2016,~~2017, respectively, and charged the remaining net periodic benefit cost primarily to electric utility plant.

The Utilities have implemented pension and OPEB tracking mechanisms under which all of their retirement benefit expenses (except for executive life and nonqualified pension plan expenses) determined in accordance with GAAP are recovered over time. Under the tracking mechanisms, these retirement benefit costs that are over/under amounts allowed in rates are charged/credited to a regulatory asset/liability. The regulatory asset/liability for each utility will be amortized over 5 years beginning with the issuance of the PUC’s D&O in the respective utility’s next rate case.

Defined contribution plans information. For the first six months of ~~2017~~2018 and ~~2016,~~2017, the Company’s expenses for its defined contribution pension plans under the Hawaiian Electric Industries Retirement Savings Plan (HEIRSP) and the ASB 401(k) Plan were $~~3.3~~3.2 million and $~~2.8~~3.3 million, respectively, and cash contributions were $~~4.0~~4.8 million and $~~3.7~~4.0 million, respectively. For the first six months of ~~2017~~2018 and ~~2016,~~2017, the Utilities’ expenses for its defined contribution pension plan under the HEIRSP were ~~$1.0~~$1.1 million and ~~$0.8~~$1.0 million, respectively, and cash contributions were ~~$1.0~~$1.1 million and ~~$0.8~~$1.0 million, respectively.

8Note 9 · Share-based compensation

Under the 2010 Equity and Incentive Plan, as amended, HEI can issue shares of common stock as incentive compensation to selected employees in the form of stock options, stock appreciation rights, restricted shares, restricted stock units, performance shares and other share-based and cash-based awards. The 2010 Equity and Incentive Plan (original EIP) was amended and restated effective March 1, 2014 (EIP) and an additional 1.5 million shares ~~was~~were added to the shares available for issuance under these programs.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

As of June 30, ~~2017~~,2018, approximately ~~3.3~~3.2 million shares remained available for future issuance under the terms of the EIP, assuming recycling of shares withheld to satisfy minimum statutory tax liabilities relating to EIP awards, including an estimated ~~0.4~~0.6 million shares that could be issued upon the vesting of outstanding restricted stock units and the achievement of performance goals for awards outstanding under long-term incentive plans (assuming that such performance goals are achieved at maximum levels).

Under the 2011 Nonemployee Director Stock Plan (2011 Director Plan), HEI can issue shares of common stock as compensation to nonemployee directors of HEI, Hawaiian Electric and ASB. As of June 30, ~~2017~~,2018, there were ~~85,428~~46,607 shares remaining available for future issuance under the 2011 Director Plan.

Share-based compensation expense and the related income tax benefit were as follows:


	Three months ended June 30				Six months ended June 30				Three months ended June 30				Six months ended June 30
(in millions)	2017		2016		2017		2016		2018		2017		2018		2017
HEI consolidated
Share-based compensation expense ¹	$	2.2	$	1.0	$	3.3	$	2.0	$	2.8	$	2.2	$	4.4	$	3.3
Income tax benefit	0.8		0.4		1.2		0.7		0.5		0.8		0.7		1.2
Hawaiian Electric consolidated
Share-based compensation expense ¹	0.7		0.3		1.1		0.6		0.9		0.7		1.5		1.1
Income tax benefit	0.3		0.1		0.4		0.2		0.2		0.3		0.3		0.4


¹	For the three ~~months~~ and six months ended June 30, ~~2017~~2018 and ~~2016,~~2017, the Company has not capitalized any share-based compensation.

Stock awards. ~~No nonemployee director stock grants were awarded from January 1 to June 30, 2016. Nonemployee director awards totaling $0.2 million were paid in cash in July 2016.~~ HEI granted HEI common stock to nonemployee directors of HEI, Hawaiian Electric and ASB under the 2011 Director Plan as follows:


	Three months ended June 30				Six months ended June 30				Three months ended June 30				Six months ended June 30
($ in millions)	2017		2016		2017		2016
(dollars in millions)									2018		2017		2018		2017
Shares granted	35,000		—		35,770		—		37,747		35,000		38,821		35,770
Fair value	$	1.1	$	—	$	1.2	$	—	$	1.3	$	1.1	$	1.3	$	1.2
Income tax benefit	0.4		—		0.5		—		0.3		0.4		0.3		0.5

The number of shares issued to each nonemployee ~~directors~~director of HEI, Hawaiian Electric and ASB is determined based on the closing price of HEI Common Stock on the grant date.

Restricted stock units. Information about HEI’s grants of restricted stock units was as follows:


	Three months ended June 30										Six months ended June 30										Three months ended June 30										Six months ended June 30
	2017					2016					2017					2016					2018					2017					2018					2017
	Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)
Outstanding, beginning of period	236,036			$	31.42	226,537			$	29.59	220,683			$	29.57	210,634			$	28.82	208,088			$	32.97	236,036			$	31.42	197,047			$	31.53	220,683			$	29.57
Granted	896			33.06		—			—		97,873			33.47		94,282			29.90		3,159			33.78		896			33.06		92,064			34.09		97,873			33.47
Vested	(7,370		)	29.17		(785		)	27.88		(88,994		)	28.88		(79,164		)	27.91		(448		)	31.94		(7,370		)	29.17		(75,683		)	30.56		(88,994		)	28.88
Forfeited	(23,079		)	31.50		—			—		(23,079		)	31.50		—			—		(9,943		)	32.05		(23,079		)	31.50		(12,572		)	32.27		(23,079		)	31.50
Outstanding, end of period	206,483			$	31.50	225,752			$	29.59	206,483			$	31.50	225,752			$	29.59	200,856			$	33.03	206,483			$	31.50	200,856			$	33.03	206,483			$	31.50
Total weighted-average grant-date fair value of shares granted ($ millions)	$	—				$	—				$	3.3				$	2.8
Total weighted-average grant-date fair value of shares granted (in millions)																					$	0.1				$	—				$	3.1				$	3.3


(1)	Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

For the first six months of ~~2017~~2018 and ~~2016,~~2017, total restricted stock units ~~that vested~~ and related dividends that vested had a fair value of $~~3.3~~2.7 million and $~~2.6~~3.3 million, respectively, and the related tax benefits were $~~1.2~~0.4 million and $~~0.9~~1.2 million, respectively.

As of June 30, ~~2017,~~2018, there was $5.4 million of total unrecognized compensation cost related to the nonvested restricted stock units. The cost is expected to be recognized over a weighted-average period of 2.8 years.

Long-term incentive plan payable in stock. The 2017-2019 and 2018-2020 long-term incentive ~~plan~~plans (LTIP) ~~provides~~provide for performance awards under the EIP of shares of HEI common stock based on the satisfaction of performance goals, including a market condition goal. The number of shares of HEI common stock that may be awarded is fixed on the date the grants are

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

made, subject to the achievement of specified performance levels and calculated dividend equivalents. The potential payout varies from 0% to 200% of the number of target shares depending on the achievement of the goals. The market condition goal is based on HEI’s total shareholder return (TSR) compared to the Edison Electric Institute Index over the three-year period. The other performance condition goals relate to EPS growth, return on average common equity (ROACE) and ASB’s efficiency ratio. The ~~2015-2017 and~~ 2016-2018 ~~LTIPs provide~~LTIP provides for performance awards payable in cash, and thus ~~are~~is not included in the tables below.

LTIP linked to TSR. Information about HEI’s LTIP grants linked to TSR was as follows:


	Three months ended June 30									Six months ended June 30										Three months ended June 30										Six months ended June 30
	2017					2016				2017					2016					2018					2017					2018					2017
	Shares			(1)		Shares		(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)
Outstanding, beginning of period	36,971			$	39.51	83,947		$	22.95	83,106			$	22.95	162,500			$	27.66	66,791			$	38.84	36,971			$	39.51	32,904			$	39.51	83,106			$	22.95
Granted (target level)	233			39.51		—		—		37,204			39.51		—			—
Granted																				1,315			38.20		233			39.51		36,941			38.21		37,204			39.51
Vested (issued or unissued and cancelled)	—			—		—		—		(83,106		)	22.95		(78,553		)	32.69		—			—		—			—		—			—		(83,106		)	22.95
Forfeited	(3,434		)	39.51		—		—		(3,434		)	39.51		—			—		(1,929		)	38.85		(3,434		)	39.51		(3,668		)	38.84		(3,434		)	39.51
Outstanding, end of period	33,770			$	39.51	83,947		$	22.95	33,770			$	39.51	83,947			$	22.95	66,177			$	38.82	33,770			$	39.51	66,177			$	38.82	33,770			$	39.51
Total weighted-average grant-date fair value of shares granted ($ millions)	$	—				$	—			$	1.5				$	—
Total weighted-average grant-date fair value of shares granted (in millions)																				$	0.1				$	—				$	1.4				$	1.5


(1)	Weighted-average grant-date fair value per share determined using a Monte Carlo simulation model.

The grant date fair values of the shares were determined using a Monte Carlo simulation model utilizing actual information for the common shares of HEI and its peers for the period from the beginning of the performance period to the grant date and estimated future stock volatility and dividends of HEI and its peers over the remaining three-year performance period. The expected stock volatility assumptions for HEI and its peer group were based on the three-year historic stock volatility, and the annual dividend yield assumptions were based on dividend yields calculated on the basis of daily stock prices over the same three-year historical period.

The following table summarizes the assumptions used to determine the fair value of the LTIP awards linked to TSR and the resulting fair value of LTIP awards granted:



	~~2017~~
~~Risk-free interest rate~~	~~1.46~~	%
~~Expected life in years~~	3
~~Expected volatility~~	~~20.1~~	%
~~Range of expected volatility for Peer Group~~	~~15.4% to 26.0%~~
~~Grant date fair value (per share)~~	~~$39.51~~



	2018		2017
Risk-free interest rate	2.29	%	1.46	%
Expected life in years	3		3
Expected volatility	17.0	%	20.1	%
Range of expected volatility for Peer Group	15.1% to 26.2%		15.4% to 26.0%
Grant date fair value (per share)	$38.20		$39.51

For the six months ended June 30, 2017, total vested LTIP awards linked to TSR and related dividends had a fair value of $1.9 million and the related tax benefits were $0.7 million. ~~For the six months ended June 30, 2016, all vested shares in the table above were unissued and cancelled (i.e., lapsed) because the TSR goal was not met.~~

As of June 30, ~~2017,~~2018, there was ~~$1.1~~$1.7 million of total unrecognized compensation cost related to the nonvested performance awards payable in shares linked to TSR. The cost is expected to be recognized over a weighted-average period of ~~2.5~~2.0 years.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

LTIP awards linked to other performance conditions. Information about HEI’s LTIP awards payable in shares linked to other performance conditions was as follows:


	Three months ended June 30									Six months ended June 30										Three months ended June 30										Six months ended June 30
	2017					2016				2017					2016					2018					2017					2018					2017
	Shares			(1)		Shares		(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)		Shares			(1)
Outstanding, beginning of period	147,888			$	33.48	113,550		$	25.18	109,816			$	25.18	222,647			$	26.02	267,167			$	33.80	147,888			$	33.48	131,616			$	33.47	109,816			$	25.18
Granted (target level)	930			32.58		—		—		148,818			33.47		—			—
Vested (issued)	—			—		—		—		(109,816		)	25.18		(109,097		)	26.89
Granted																				5,257			33.52		930			32.58		147,766			34.08		148,818			33.47
Vested																				—			—		—			—		—			—		(109,816		)	25.18
Forfeited	(13,740		)	33.48		—		—		(13,740		)	33.48		—			—		(7,717		)	33.80		(13,740		)	33.48		(14,675		)	33.80		(13,740		)	33.48
Outstanding, end of period	135,078			$	33.47	113,550		$	25.18	135,078			$	33.47	113,550			$	25.18	264,707			$	33.79	135,078			$	33.47	264,707			$	33.79	135,078			$	33.47
Total weighted-average grant-date fair value of shares granted (at target performance levels) ($ millions)	$	—				$	—			$	5.0				$	—
Total weighted-average grant-date fair value of shares granted (at target performance levels) (in millions)																				$	0.2				$	—				$	5.0				$	5.0


(1)	Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

For the six months ended June 30, 2017, ~~and 2016,~~ total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $4.2 million and ~~$3.6 million and~~ the related tax benefits were $1.6 ~~million and $1.4 million, respectively.~~million.

As of June 30, ~~2017,~~2018, there was ~~$3.8~~$6.0 million of total unrecognized compensation cost related to the nonvested shares linked to performance conditions other than TSR. The cost is expected to be recognized over a weighted-average period of ~~2.5~~2.0 years.

9Note 10 · Income taxes

~~The Company’s ETRs (combined federal and state~~Staff Accounting Bulletin No. 118 (SAB No. 118). On December 22, 2017, the SEC staff issued SAB No. 118 to address the application of GAAP in situations when a registrant does not have the necessary information available, prepared, or analyzed (including computations) in reasonable detail to complete the accounting for certain income tax ~~rates) for~~effects of the second quarters of 2017 and 2016 were 34% and 37%, respectively, and for the first six months of 2017 and 2016 were 34% and 37%, respectively. The ETR was lower for the three months and six months ended June 30, 2017 compared to the same periods in 2016 due in part to 2016 nondeductible merger- and spin-off-related expenses. Also, in the first quarter ofTax Act. In 2017, the Company ~~recognized excess tax benefits on share-based compensation after the adoption of ASU No. 2016-09.~~

Hawaiian Electric’s ETRs for the second quarters of 2017 and 2016 were 36% and 38%, respectively, and for the first six months of 2017 and 2016 were 36% and 37%, respectively. The lower ETR was due in partcalculated its best estimate, primarily related to the ~~recognition of excess tax benefits on share-based compensation after the adoption of ASU No. 2016-09.~~

~~Recent tax developments.~~ ~~The extension of~~ bonus depreciation ~~under~~rule changes, in accordance with its understanding of the ~~“Protecting Americans from Tax Hikes (PATH) Act~~law and available guidance. As of ~~2015” continues~~June 30, 2018, there were no adjustments made to ~~be the most significant recent~~provisional tax change. The PATH Act provides 50% bonus depreciation through 2017, phases down the percentage to 40% in 2018 and 30% in 2019 and then terminates bonus depreciation thereafter. Tax depreciation is expected to increase by approximately $120 million in 2017 due to bonus depreciation, which has the effect of increasing accumulated deferred tax liabilities. However, the rate of growth of accumulated deferred tax liabilities is decreasing over time as book depreciation “catches up” with the tax depreciation takenimpacts previously recognized in the ~~past.~~Company’s and Utilities financial statements. The provisional impacts will be updated as additional information is received as a result of changes in the Company and Utilities interpretations and assumptions, the issuance of Internal Revenue Service and Joint Committee on Taxation guidance, and actions the Company and Utilities may take as a result of the Tax Act. The provisional tax impacts will be finalized by the end of 2018.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

10Note 11 · Cash flows


Six months ended June 30	2017			2016			2018		2017
(in millions)
Supplemental disclosures of cash flow information
HEI consolidated
Interest paid to non-affiliates	$	46		$	43		$	45	$	46
Income taxes paid (including refundable credits)	21			14			36		21
Income taxes refunded (including refundable credits)	—			45
Hawaiian Electric consolidated
Interest paid to non-affiliates	36			31			32		36
Income taxes paid (including refundable credits)	8			—			35		8
Income taxes refunded (including refundable credits)	—			20
Supplemental disclosures of noncash activities
HEI consolidated
Common stock dividends reinvested in HEI common stock (financing)¹	—			11
Property, plant and equipment
Estimated fair value of noncash contributions in aid of construction (investing)							5		2
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)							42		38
Loans transferred from held for investment to held for sale (investing)	9			—			1		9
Common stock issued (gross) for director and executive/management compensation (financing)²	11			6
HEI consolidated and Hawaiian Electric consolidated
Common stock issued (gross) for director and executive/management compensation (financing)¹							4		11
Obligations to fund low income housing investments (investing)							6		—
Transfer of retail repurchase agreements to deposit liabilities (financing)							102		—
Unsettled trades to purchase investment securities (investing)							10		—
Hawaiian Electric consolidated
Electric utility property, plant and equipment
Estimated fair value of noncash contributions in aid of construction (investing)	2			8			5		2
Change in unpaid invoices and accruals for capital expenditures (investing)	(7		)	(32		)
Unpaid invoices and accruals for capital expenditures, balance, end of period (investing)							28		36

¹~~The amounts shown represent common stock dividends reinvested in HEI common stock under the HEI Dividend Reinvestment and Stock Purchase Plan (DRIP) in noncash transactions.~~

² The amounts shown represent the market value of common stock issued for director and executive/management compensation and withheld to satisfy statutory tax liabilities.

11NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Note 12 · Fair value measurements

Fair value estimates are estimates of the price that would be received to sell an asset or paid upon the transfer of a liability in an orderly transaction between market participants at the measurement date. The fair value estimates are generally determined based on assumptions that market participants would use in pricing the asset or liability and are based on market data obtained from independent sources. However, in certain cases, the Company and the Utilities use their own assumptions based on the best information available in the circumstances. These valuations are estimates at a specific point in time, based on relevant market information, information about the financial instrument and judgments regarding future expected loss experience, economic conditions, risk characteristics of various financial instruments and other factors. These estimates do not reflect any premium or discount that could result if the Company or the Utilities were to sell its entire holdings of a particular financial instrument at one time. Because no active trading market exists for a portion of the Company’s and the Utilities’ financial instruments, fair value estimates cannot be determined with precision. Changes in the underlying assumptions used, including discount rates and estimates of future cash flows, could significantly affect the estimates. In addition, the tax ramifications related to the realization of the unrealized gains and losses could have a significant effect on fair value estimates but have not been considered in making such estimates.

~~The Company and the Utilities group their financial assets measured at fair value in three levels outlined as follows:~~

~~Level 1:~~Inputs to the valuation methodology are quoted prices, unadjusted, for identical assets or liabilities in active markets. A quoted price in an active market provides the most reliable evidence of fair value and is used to measure fair value whenever available.

~~Level 2:~~Inputs to the valuation methodology include quoted prices for similar assets or liabilities in active markets; inputs to the valuation methodology include quoted prices for identical or similar assets or liabilities in markets that are not active; or inputs to the valuation methodology that are derived principally from or can be corroborated by observable market data by correlation or other means.

~~Level 3:~~Inputs to the valuation methodology are unobservable and significant to the fair value measurement. Level 3 assets and liabilities include financial instruments whose value is determined using discounted cash flow

~~methodologies, as well as instruments for which the determination of fair value requires significant management judgment or estimation.~~

Classification in the hierarchy is based upon the lowest level input that is significant to the fair value measurement of the asset or liability. For instruments classified in Level 1 and 2 where inputs are primarily based upon observable market data, there is less judgment applied in arriving at the fair value. For instruments classified in Level 3, management judgment is more significant due to the lack of observable market data.

Fair value is also used on a nonrecurring basis to evaluate certain assets for impairment or for disclosure purposes. Examples of nonrecurring uses of fair value include mortgage servicing rights accounted for by the amortization method, loan impairments for certain loans and goodwill.

Fair value measurement and disclosure valuation methodology. The following are descriptions of the valuation methodologies used for assets and liabilities recorded at fair value and for estimating fair value for financial instruments not carried at fair value:

Short-term borrowings—other than bank. The carrying amount of short-term borrowings approximated fair value because of the short maturity of these instruments.

Investment securities. The fair value of ASB’s investment securities is determined quarterly through pricing obtained from independent third-party pricing services or from brokers not affiliated with the trade. Non-binding broker quotes are infrequent and generally occur for new securities that are settled close to the month-end pricing date. The third-party pricing vendors ASB uses for pricing its securities are reputable firms that provide pricing services on a global basis and have processes in place to ensure quality and control. The third-party pricing services use a variety of methods to determine the fair value of securities that fall under Level 2 of ~~the~~ ASB’s fair value measurement hierarchy. Among the considerations are quoted prices for similar securities in an active market, yield spreads for similar trades, adjustments for liquidity, size, collateral characteristics, historic and generic prepayment speeds, and other observable market factors.

To enhance the robustness of the pricing process, ASB will on a quarterly basis compare its standard third-party vendor’s price with that of another third-party vendor. If the prices are within an acceptable tolerance range, the price of the standard vendor will be accepted. If the variance is beyond the tolerance range, an evaluation will be conducted by ASB and a challenge to the price may be made. Fair value in such cases will be based on the value that best reflects the data and observable characteristics of the security. In all cases, the fair value used will have been independently determined by a third-party pricing vendor or non-affiliated ~~broker and not by ASB.~~broker.

The fair value of the mortgage revenue bond is estimated using a discounted cash flow model to calculate the present value of future principal and interest payments and, therefore is classified within Level 3 of the valuation hierarchy.

Loans held for sale. ~~Loans~~Residential and commercial loans are carried at the lower of cost or market and are valued using market observable pricing inputs, which are derived from third party loan sales and, ~~securitizations and,~~ therefore, are classified within Level 2 of the valuation hierarchy. ASB transferred $6.1 million of loans receivable out of Level 3 into Level 2 due to changes in the observability of significant inputs during the six months ended June 30, 2017. The related gain from the fair value adjustment of loans sold was not material in the three and six months ended June 30, 2017.

Loans held for investment. Fair value of loans held for investment is derived using a discounted cash flow approach which includes an evaluation of the underlying loan characteristics. The valuation model uses loan characteristics which includes product type, maturity dates and the underlying interest rate of the portfolio. This information is input into the valuation models along with various forecast valuation assumptions including prepayment forecasts, to determine the discount rate. These assumptions are derived from internal and third party sources. ~~Noting~~Since the valuation is derived from model-based techniques, ASB includes loans held for investment within Level 3 of the valuation hierarchy.

Impaired loans. At the time a loan is considered impaired, it is valued at the lower of cost or fair value. Fair value is determined primarily by using an income, cost or market approach and is normally provided through appraisals. Impaired loans carried at fair value generally receive specific allocations within the allowance for loan losses. For collateral-dependent loans, fair value is commonly based on recent real estate appraisals. These appraisals may utilize a single valuation approach or a combination of approaches including comparable sales and the income approach. Adjustments are routinely made in the appraisal process by the independent appraisers to adjust for differences between the comparable sales and income data available. Such adjustments typically result in a Level 3 classification of the inputs for determining fair value. Non-real estate collateral may be valued using an appraisal, net book value per the borrower’s financial statements, or aging reports, adjusted or discounted based on management’s historical knowledge, changes in market conditions from the time of the valuation and management’s expertise and knowledge of the client and client’s business, resulting in a Level 3 fair value classification. Generally, impaired loans are evaluated quarterly for additional impairment and adjusted accordingly.

Real estate acquired in settlement of loans. Foreclosed assets are carried at fair value (less estimated costs to sell) and are generally based upon appraisals or independent market prices that are periodically updated subsequent to classification as real estate owned. Such adjustments typically result in a Level 3 classification of the inputs for determining fair value. ASB estimates the fair value of collateral-dependent loans and real estate owned using the sales comparison approach.

Mortgage servicing rights. Mortgage servicing rights (MSRs) are capitalized at fair value based on market data at the time of sale and accounted for in subsequent periods at the lower of amortized cost or fair value. Mortgage servicing rights are evaluated for impairment at each reporting date. ASB's MSRs are stratified based on predominant risk characteristics of the underlying loans including loan type and note rate. For each stratum, fair value is calculated by discounting expected net

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

income streams using discount rates that reflect industry pricing for similar assets. Expected net income streams are estimated based on industry assumptions regarding prepayment expectations and income and expenses associated with servicing residential mortgage loans for others. Impairment is recognized through a valuation allowance for each stratum when the carrying amount exceeds fair value, with any associated provision recorded as a component of loan servicing fees included in "Revenues - bank" in the consolidated statements of income. A direct write-down is recorded when the recoverability of the valuation allowance is deemed to be unrecoverable. ASB compares the fair value of MSRs to an estimated value calculated by an independent third-party. The third-party relies on both published and unpublished sources of market related assumptions and their own experience and expertise to arrive at a value. ASB uses the third-party value only to assess the reasonableness of its own estimate.

~~Time deposits~~Deposit liabilities. Includes only fixed-maturity certificates of deposit beginning in 2018. The fair value of fixed-maturity certificates of deposit was estimated by discounting the future cash flows using the rates currently offered for deposits of similar remaining maturities.

Other borrowings. For fixed-rate advances and repurchase agreements, fair value is estimated using quantitative discounted cash flow models that require the use of interest rate inputs that are currently offered for advances and repurchase agreements of similar remaining maturities. The majority of market inputs are actively quoted and can be validated through external sources, including broker market transactions and third party pricing services.

Long-term debt—other than bank. Fair value of long-term debt of HEI and the Utilities was obtained from third-party financial services providers based on the current rates offered for debt of the same or similar remaining maturities and from discounting the future cash flows using the current rates offered for debt of the same or similar risks, terms, and remaining maturities.

Interest rate lock commitments (IRLCs). The estimated fair value of commitments to originate residential mortgage loans for sale is based on quoted prices for similar loans in active markets. IRLCs are classified as Level 2 measurements.

Forward sales commitments. To be announced (TBA) mortgage-backed securities forward commitments are classified as Level 1, and consist of publicly-traded debt securities for which identical fair values can be obtained through quoted market prices in active exchange markets. The fair values of ASB’s best efforts and mandatory delivery loan sale commitments are determined using quoted prices in the market place that are observable and are classified as Level 2 measurements.

Window forward contracts. The estimated fair value of the Utilities’ window forward contracts was obtained from a third-party financial services provider based on the effective exchange rate offered for the foreign currency denominated transaction. Window forward contracts are classified as Level 2 measurements.

The following table presents the carrying or notional amount, fair value and placement in the fair value hierarchy of the Company’s financial instruments. For stock in Federal Home Loan Bank, the carrying amount is a reasonable estimate of fair value because it can only be redeemed at par. ~~For bank-owned life insurance, the carrying amount is the cash surrender value of the insurance policies, which is a reasonable estimate of fair value.~~For financial liabilities such as noninterest-bearing demand, interest-bearing demand, and savings and money market deposits, the carrying amount is a reasonable estimate of fair value as these liabilities have no stated maturity.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)


				Estimated fair value														Estimated fair value
	Carrying or notional amount			Quoted prices in active markets for identical assets			Significant other observable inputs			Significant unobservable inputs					Carrying or notional amount			Quoted prices in active markets for identical assets			Significant other observable inputs			Significant unobservable inputs
(in thousands)			(Level 1)			(Level 2)			(Level 3)			Total					(Level 1)			(Level 2)			(Level 3)			Total
June 30, 2017
June 30, 2018
Financial assets
HEI consolidated
Available-for-sale investment securities	$	1,302,886		$	—		$	1,287,459		$	15,427		$	1,302,886	$	1,409,528		$	—		$	1,394,101		$	15,427		$	1,409,528
Held-to-maturity investment securities															62,630			—			61,444			—			61,444
Stock in Federal Home Loan Bank	11,706			—			11,706			—			11,706		10,158			—			10,158			—			10,158
Loans receivable, net	4,693,539			—			5,261			4,836,804			4,842,065
Loans, net															4,727,189			—			5,250			4,774,079			4,779,329
Mortgage servicing rights	9,181			—			—			12,270			12,270		8,509			—			—			13,423			13,423
Bank-owned life insurance	146,122			—			146,122			—			146,122
Derivative assets	58,120			47			798			—			845		24,537			—			250			—			250
Hawaiian Electric consolidated
Derivative assets-window forward contracts	15,995			—			615			—			615
Financial liabilities
HEI consolidated
Deposit liabilities	5,724,386			—			5,721,882			—			5,721,882
Deposit liabilities¹															757,265			—			745,295			—			745,295
Short-term borrowings—other than bank	49,789			—			49,789			—			49,789		202,857			—			202,857			—			202,857
Other bank borrowings	188,130			—			188,513			—			188,513		126,930			—			126,904			—			126,904
Long-term debt, net—other than bank	1,618,647			—			1,740,479			—			1,740,479		1,783,009			—			1,816,310			—			1,816,310
Derivative liabilities	8,263			—			246			—			246		25,445			56			114			—			170
Hawaiian Electric consolidated
Short-term borrowings	43,990			—			43,990			—			43,990		91,880			—			91,880			—			91,880
Long-term debt, net	1,318,845			—			1,434,528			—			1,434,528		1,468,457			—			1,511,103			—			1,511,103
Derivative liabilities-window forward contracts	4,726			—			230			—			230		3,117			—			106			—			106
December 31, 2016
December 31, 2017
Financial assets
HEI consolidated
Money market funds	$	13,085		$	—		$	13,085		$	—		$	13,085
Available-for-sale investment securities	1,105,182			—			1,089,755			15,427			1,105,182		1,401,198			—			1,385,771			15,427			1,401,198
Held-to-maturity investment securities															44,515			—			44,412			—			44,412
Stock in Federal Home Loan Bank	11,218			—			11,218			—			11,218		9,706			—			9,706			—			9,706
Loans receivable, net	4,701,977			—			13,333			4,839,493			4,852,826
Loans, net															4,628,381			—			11,254			4,770,497			4,781,751
Mortgage servicing rights	9,373			—			—			13,216			13,216		8,639			—			—			12,052			12,052
Bank-owned life insurance	143,197			—			143,197			—			143,197
Derivative assets	23,578			—			453			—			453		17,812			—			393			—			393
Hawaiian Electric consolidated
Derivative assets-window forward contracts															3,240			—			256			—			256
Financial liabilities
HEI consolidated
Deposit liabilities	5,548,929			—			5,546,644			—			5,546,644
Deposit liabilities¹															5,890,597			—			5,884,071			—			5,884,071
Short-term borrowings—other than bank	—			—			—			—			—		117,945			—			117,945			—			117,945
Other bank borrowings	192,618			—			193,991			—			193,991		190,859			—			190,829			—			190,829
Long-term debt, net—other than bank	1,619,019			—			1,704,717			—			1,704,717		1,683,797			—			1,813,295			—			1,813,295
Derivative liabilities	53,852			129			823			—			952		13,562			20			10			—			30
Hawaiian Electric consolidated
Short-term borrowings															4,999			—			4,999			—			4,999
Long-term debt, net	1,319,260			—			1,399,490			—			1,399,490		1,368,479			—			1,497,079			—			1,497,079
Derivative liabilities-window forward contracts	20,734			—			743			—			743

¹ Deposit liabilities as of December 31, 2017 include noninterest-bearing demand, interest-bearing demand, and savings and money market deposits, for which the carrying amount represents a reasonable estimate of fair value, as such liabilities have no stated maturity. The fair value of such financial liabilities are not included as of June 30, 2018 as a result of the Company’s adoption of ASU No. 2016-01.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Fair value measurements on a recurring basis. Assets and liabilities measured at fair value on a recurring basis were as follows:


	June 30, 2017						December 31, 2016						June 30, 2018						December 31, 2017
	Fair value measurements using						Fair value measurements using						Fair value measurements using						Fair value measurements using
(in thousands)	Level 1		Level 2		Level 3		Level 1		Level 2		Level 3		Level 1		Level 2		Level 3		Level 1		Level 2		Level 3
Money market funds (“other” segment)	$	—	$	—	$	—	$	—	$	13,085	$	—
Available-for-sale investment securities (bank segment)
Mortgage-related securities-FNMA, FHLMC and GNMA	$	—	$	1,100,876	$	—	$	—	$	897,474	$	—	$	—	$	1,177,832	$	—	$	—	$	1,201,473	$	—
U.S. Treasury and federal agency obligations	—		186,583		—		—		192,281		—		—		175,933		—		—		184,298		—
Corporate bonds													—		40,336		—		—		—		—
Mortgage revenue bond	—		—		15,427		—		—		15,427		—		—		15,427		—		—		15,427
	$	—	$	1,287,459	$	15,427	$	—	$	1,089,755	$	15,427	$	—	$	1,394,101	$	15,427	$	—	$	1,385,771	$	15,427
Derivative assets
Interest rate lock commitments (bank segment)¹	$	—	$	142	$	—	$	—	$	445	$	—	$	—	$	248	$	—	$	—	$	133	$	—
Forward commitments (bank segment)¹	47		41		—		—		8		—		—		2		—		—		4		—
Window forward contract (electric utility segment)²	—		615		—		—		—		—
Window forward contracts (electric utility segment)²													—		—		—		—		256		—
	$	47	$	798	$	—	$	—	$	453	$	—	$	—	$	250	$	—	$	—	$	393	$	—
Derivative liabilities
Interest rate lock commitments (bank segment) ¹	$	—	$	16	$	—	$	—	$	24	$	—	$	—	$	—	$	—	$	—	$	2	$	—
Forward commitments (bank segment) ¹	—		—		—		129		56		—		56		8		—		20		8		—
Window forward contracts (electric utility segment)²	—		230		—		—		743		—		—		106		—		—		—		—
	$	—	$	246	$	—	$	129	$	823	$	—	$	56	$	114	$	—	$	20	$	10	$	—

¹ Derivatives are carried at fair value with changes in value reflected in the balance sheet in other assets or other liabilities and included in mortgage banking income.

² Derivatives are included in ~~noncurrent~~ regulatory assets and/or liabilities in the balance sheets.

There were no transfers of financial assets and liabilities between Level 1 and Level 2 of the fair value hierarchy during the six months ended June 30, ~~2017.~~2018.

The changes in Level 3 assets and liabilities measured at fair value on a recurring basis were as follows:


	Three months ended June 30				Six months ended June 30				Three months ended June 30				Six months ended June 30
Mortgage revenue bond	2017		2016		2017		2016		2018		2017		2018		2017
(in thousands)
Beginning balance	$	15,427	$	—	$	15,427	$	—	$	15,427	$	15,427	$	15,427	$	15,427
Principal payments received	—		—		—		—		—		—		—		—
Purchases	—		—		—		—		—		—		—		—
Unrealized gain (loss) included in other comprehensive income	—		—		—		—		—		—		—		—
Ending balance	$	15,427	$	—	$	15,427	$	—	$	15,427	$	15,427	$	15,427	$	15,427

ASB holds one mortgage revenue bond issued by the Department of Budget and Finance of the State of Hawaii. The Company estimates the fair value by using a discounted cash flow model to calculate the present value of estimated future principal and interest payments. The unobservable input used in the fair value measurement is the weighted average discount rate. As of June 30, ~~2017,~~2018, the weighted average discount rate was ~~2.820%~~3.40% which was derived by incorporating a credit spread over the one month LIBOR rate. Significant increases (decreases) in the weighted average discount rate could result in a significantly lower (higher) fair value measurement.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS - continued(Unaudited)

Fair value measurements on a nonrecurring basis. Certain assets and liabilities are measured at fair value on a nonrecurring basis and therefore are not included in the tables above. These measurements primarily result from assets carried at the lower of cost or fair value or from impairment of individual assets. The carrying value of assets measured at fair value on a nonrecurring basis were as follows:


			Fair value measurements								Fair value measurements
(in thousands)	Balance		Level 1		Level 2		Level 3		Balance		Level 1		Level 2		Level 3
June 30, 2017
June 30, 2018
Loans	$	1,258	$	—	$	—	$	1,258	$	232	$	—	$	—	$	232
December 31, 2016
December 31, 2017
Loans	2,767		—		—		2,767		2,621		—		—		2,621
Real estate acquired in settlement of loans	1,189		—		—		1,189

For six months ended June 30, ~~2017~~2018 and ~~2016,~~2017, there were no adjustments to fair value for ASB’s loans held for sale.

The following table presents quantitative information about Level 3 fair value measurements for financial instruments measured at fair value on a nonrecurring basis:

Significant unobservable
input value ⁽¹⁾
($ in thousands) Fair value Valuation technique Significant unobservable input Range
Weighted
Average
June 30, 2017
Residential loan $ 448
Fair value of collateral Appraised value less 7% selling cost N/A (2)
Commercial loan 810
Sales price Sales price N/A (2)
Total loans $ 1,258

December 31, 2016
Residential loans $ 2,468
Sales price Sales price 95-100% 97%
Residential loans 287
Fair value of property or collateral Appraised value less 7% selling cost 42-65% 61%
Home equity lines of credit 12
Fair value of property or collateral Appraised value less 7% selling cost N/A (2)
Total loans $ 2,767

Real estate acquired in settlement of loans $ 1,189
Fair value of property or collateral Appraised value less 7% selling cost 100% 100%



					Significant unobservable input value ⁽¹⁾
($ in thousands)	Fair value		Valuation technique	Significant unobservable input	Range	Weighted Average
June 30, 2018
Residential loans	$	232	Fair value of collateral	Appraised value less 7% selling cost	62-69%	68%
Total loans	$	232

December 31, 2017
Residential loans	$	613	Fair value of collateral	Appraised value less 7% selling cost	71-92%	84%
Commercial loans	2,008		Fair value of collateral	Appraised value	71-76%	75%
Total loans	$	2,621

(1) Represent percent of outstanding principal balance.

~~(2) N/A - Not applicable. There is one loan in each fair value measurement type.~~

Significant increases (decreases) in any of those inputs in isolation would result in significantly higher (lower) fair value measurements.

~~12 · Termination of proposed merger and other matters~~

On December 3, 2014, HEI, NextEra Energy, Inc. (NEE) and two subsidiaries of NEE entered into an Agreement and Plan of Merger (the Merger Agreement), under which Hawaiian Electric was to become a subsidiary of NEE. The Merger Agreement contemplated that, prior to the Merger, HEI would distribute to its shareholders all of the common stock of ASB Hawaii, Inc. (ASB Hawaii), the parent company of ASB (such distribution referred to as the Spin-Off).

The closing of the Merger was subject to various conditions, including receipt of regulatory approval from the PUC. In July 2016: (1) the PUC dismissed NEE and Hawaiian Electric’s application requesting approval of the proposed Merger, (2) NEE terminated the Merger Agreement and (3) pursuant to the terms of the Merger Agreement, NEE paid HEI a $90 million termination fee and $5 million for the reimbursement of expenses associated with the transaction. In 2016, the Company recognized $60 million of net income ($2 million of net loss in each of the first and second quarters and $64 million of net income in the third quarter), comprised of the termination fee ($55 million), reimbursements of expenses from NEE and insurance ($3 million), and additional tax benefits on the previously non-tax-deductible merger- and Spin-Off-related expenses incurred through June 30, 2016 ($8 million), less merger- and Spin-Off-related expenses incurred in 2016 ($6 million) (all net of tax impacts). The Spin-Off of ASB Hawaii was cancelled as it was cross-conditioned on the merger consummation.

In May 2016, the Utilities had filed an application for approval of an liquefied natural gas (LNG) supply and transport agreement and LNG-related capital equipment, which application was conditioned on the PUC’s approval of the proposed Merger. Subsequently, the Utilities terminated the LNG agreement and withdrew the application. In 2016, Hawaiian Electric

~~recognized expenses related to the terminated LNG agreement of $1 million, net of tax benefits, in each of the first and second quarters.~~

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion updates “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in HEI’s and Hawaiian Electric’s ~~2016~~2017 Form 10-K and should be read in conjunction with such discussion and the ~~2016~~2017 annual consolidated financial statements of HEI and Hawaiian Electric and notes thereto included in HEI’s and Hawaiian Electric’s ~~2016~~2017 Form 10-K, as well as the quarterly (as of and for the three and six months ended June 30, ~~2017)~~2018) condensed consolidated financial statements and notes thereto included in this Form 10-Q.

HEI consolidated

RESULTS OF OPERATIONS

(in thousands, except per Three months ended June 30 %
share amounts) 2017 2016 change Primary reason(s)*
Revenues $ 632,281
$ 566,244
12
Increases for the electric utility and bank segments
Operating income 75,896
85,455
(11 ) Decrease for the electric utility segment, partly offset by an increase at the bank segment and lower losses for the “other” segment
Net income for common stock 38,661
44,128
(12 ) Lower net income for the electric utility segment, partly offset by higher net income at the bank segment and lower net loss for the “other” segment
Basic earnings per common share $ 0.36
$ 0.41
(12 ) Lower net income and the impact of higher weighted average shares outstanding
Weighted-average number of common shares outstanding 108,750
107,962
1
Issuances of shares under the HEI Dividend Reinvestment and Stock Purchase Plan and other plans


(in thousands, except per	Six months ended June 30				%			Three months ended June 30				%
share amounts)	2017		2016		change		Primary reason(s)*	2018		2017		change	Primary reason(s)*
Revenues	$	1,223,843	$	1,117,204	10		Increases for the electric utility and bank segments	$	685,277	$	632,281	8	Increases for the electric utility and bank segments
Operating income	143,758		154,306		(7	)	Decrease for the electric utility segment, partly offset by an increase at the bank segment and lower losses for the “other” segment	78,799		77,802		1	Increase for the bank segment and lower operating losses for the “other” segment, partly offset by slight decrease for the electric utility segment
Net income for common stock	72,854		76,480		(5	)	Lower net income for the electric utility segment, partly offset by higher net income at the bank segment and lower net loss for the “other” segment	46,054		38,661		19	Higher net income at the electric utility and bank segments, partly offset by higher net losses at the “other” segment. See below for effective tax rate explanation.
Basic earnings per common share	$	0.67	$	0.71	(6	)	Lower net income and the impact of higher weighted average shares outstanding	$	0.42	$	0.36	17	Higher net income
Weighted-average number of common shares outstanding	108,712		107,791		1		Issuances of shares under the HEI Dividend Reinvestment and Stock Purchase Plan and other plans	108,842		108,750		—	Issuances of shares under compensation and director stock plans.



(in thousands, except per	Six months ended June 30				%
share amounts)	2018		2017		change	Primary reason(s)*
Revenues	$	1,331,151	$	1,223,843	9	Increases for the electric utility and bank segments
Operating income	150,688		147,540		2	Increase for the bank segment and lower operating losses for the “other” segment, partly offset by slight decrease for the electric utility segment
Net income for common stock	86,301		72,854		18	Higher net income at the electric utility and bank segments, partly offset by higher net losses at the “other” segment. See below for effective tax rate explanation.
Basic earnings per common share	$	0.79	$	0.67	18	Higher net income
Weighted-average number of common shares outstanding	108,830		108,712		—	Issuances of shares under compensation and director stock plans.


*	Also, see segment discussions which follow.

The Company’s effective tax rates (combined federal and state income tax rates) for the second quarters of 2018 and 2017 were 22% and 34%, respectively. The Company’s effective tax rates for the first six months of 2018 and 2017 were 23% and 34%, respectively. The effective tax rates were lower for the three and six months ended June 30, 2018 compared to the same periods in 2017 due primarily to the provision in the Tax Act that lowered the federal income tax rate from 35% to 21%. The lower tax rate was partially offset by lower excess tax benefits associated with share-based awards in the first six months of 2018 as compared to the same period of 2017 and other Tax Act changes (the non-deductibility of excess executive compensation and various fringe benefit costs and loss of the domestic production activities deduction). Note that although the Utilities’ effective income tax rate decreased, the net benefits of the Tax Act, including the lower effective tax rate, are being returned to customers through rates.

HEI’s consolidated ROACE was 8.6% for the twelve months ended June 30, 2018 and 12.1% for the twelve months ended June 30, ~~2017 and 8.8% for the twelve months ended June 30, 2016.~~2017. The ~~higher~~lower ROACE for the twelve months ended June 30, 2018 compared to the twelve months ended June 30,

2017 was ~~largely~~primarily due to the merger termination fee received in July ~~2016.~~2016 when HEI’s planned merger with NextEra Energy was terminated.

Dividends. The payout ratios for the first six months of ~~2017~~2018 and full year ~~2016~~2017 were ~~93%~~78% and ~~54%~~82%, respectively. HEI currently expects to maintain its dividend at its present level; however, the HEI Board of Directors evaluates the dividend quarterly and considers many factors in the evaluation including, but not limited to, the Company’s results of operations, the long-term prospects for the Company and current and expected future economic conditions.

Economic conditions.

Note: The statistical data in this section is from public third-party sources that management believes to be reliable (e.g., Department of Business, Economic Development and Tourism (DBEDT), University of Hawaii Economic Research Organization, U.S. Bureau of Labor Statistics, Department of Labor and Industrial Relations (DLIR), Hawaii Tourism Authority (HTA), Honolulu Board of REALTORS® and national and local newspapers).

Through the first half of 2018, Hawaii’s tourism industry, a significant driver of Hawaii’s economy, ~~ended the first half of 2017 with~~ continued ~~strong growth.~~to grow in both visitor spending and arrivals. Visitor expenditures increased ~~8.7%~~10.8% and arrivals increased ~~4.3%~~8.2% compared to the same ~~time~~ period in ~~2016.~~2017. Looking ahead, the Hawaii Tourism Authority expects scheduled nonstop seats to Hawaii ~~for the third quarter of 2017~~ to increase ~~by 3.7% over~~as the ~~third quarter of 2016~~year progresses, driven primarily by an increase in seats from ~~the~~West Coast, East Coast and ~~Japan.~~Asia.

Hawaii’s unemployment rate remained ~~relatively stable~~steady at ~~2.7% in~~2.1% for June ~~2017,~~2018, which was lower than the ~~state’s 3.1%~~2.4% rate ~~in June 2016~~for the same period a year ago and lower than the ~~June 2017~~ national unemployment rate of ~~4.4%~~4.0%. It is also the lowest unemployment rate in the nation.

Hawaii real estate activity, as indicated by the home resale market, experienced a decline in median sales prices for single family homes and growth in median sales prices for condominiums so far in ~~2017.~~2018. Median sales prices for single family residential homes ~~and condominiums~~ on Oahu through June ~~2017~~2018 were higher by ~~3.2%~~3.9% and ~~3.6%~~for condominiums were higher by 6.5%, ~~respectively,~~ over the same time period in ~~2016.~~2017. The number of closed sales for ~~both~~ single family residential homes was down by 1.6% and for condominiums was up 1.3% through June of ~~2017 were also up~~2018 compared to same time period of ~~2016 by 4.4% and 6.0%, respectively.~~2017.

Hawaii’s petroleum product prices reflect supply and demand in the Asia-Pacific region and the price of crude oil in international markets. ~~Following steady price increases through 2016,~~Although the price of crude oil fluctuates month to month, the general trend has ~~remained relatively stable through~~been an increasing one over the ~~first five months of 2017.~~last 2.5 years.

At its June ~~2017~~2018 meeting, the Federal Open Market Committee (FOMC) ~~again increased~~decided to raise the target range for the federal funds rate ~~target.~~from “1.75% to 2%” in view of realized and expected labor market conditions and inflation. The FOMC ~~raised~~will continue to assess economic conditions relative to its objectives of maximum employment and 2% inflation in determining the size and timing of future adjustments to the target ~~range of “0.75% to 1%” to “1.0% to 1.25%”.~~range.

Hawaii’s economic expansion continues with strong visitor arrivals and spending. The ~~FOMC has indicated a slipping~~construction industry is more volatile, with expected slowing as major projects in the ~~inflation rate~~resort, retail and multifamily residential sectors are scheduled for completion in the next few years. Record low unemployment rates are likely to ~~1.4% is temporary~~support stronger gains in income. Potential risks include infrastructure constraints, tight labor markets and ~~is expected~~high housing costs creating inflationary pressures, uncertainty in the national economic outlook due to ~~rebound to the FOMC target of 2%.~~

~~Overall, Hawaii’s economy is expected to be buoyed by a strong tourism industry. Risks remain stemming from geopolitical uncertainty~~potential trade wars and ~~its impact on tourism and from the impact of the financial markets on real estate development and sales.~~natural disasters.

“Other” segment.


	Three months ended June 30						Six months ended June 30							Three months ended June 30						Six months ended June 30
(in thousands)	2017			2016			2017			2016			Primary reason(s)	2018			2017			2018			2017			Primary reason(s)
Revenues	$	77		$	100		$	172		$	168			$	47		$	77		$	75		$	172
Operating loss	(3,947		)	(5,455		)	(9,183		)	(11,524		)	Second quarter and first six months of 2016 merger and spin-off-related expenses (see below), partly offset by higher other administrative and general expenses in the second quarter and first six months of 2017	(3,262		)	(3,677		)	(7,629		)	(8,655		)	Second quarter and first six months of 2018 includes $1.3 million and $2.3 million, respectively, of operating income from Pacific Current, LLC¹. Second quarter and first six months of 2018 corporate expense was slightly higher than same periods in 2017.
Net loss	(3,716		)	(5,014		)	(6,801		)	(10,702		)	Lower operating loss, lower interest expense (first six months) and higher tax benefits (first six months) (due to non-deductibility of certain merger- and spin-off-related expenses in the first six months of 2016 and the recognition of excess tax benefits on share-based compensation after the adoption of ASU No. 2016-09 on January 1, 2017)	(5,676		)	(3,716		)	(11,864		)	(6,801		)	Second quarter and first six months of 2018 includes higher interest expense (due to higher interest rates and balances at corporate and new debt at Pacific Current, LLC related to Hamakua Energy’s acquisition of a power plant) and lower tax benefits on expenses as a result of tax reform in second quarter and first six months of 2018 as compared to the same periods in 2017.

Hamakua Energy’s sales to Hawaii Electric Light (a regulated affiliate) are eliminated in consolidation, but Hamakua Energy's profit on electricity sales to Hawaii Electric Light is not required to be eliminated because the PPA was approved by the PUC and it is probable that, through the ratemaking process, future revenue from Hawaii Electric Light’s sale of the electricity will approximate its purchase price from Hamakua Energy under the PPA.

The “other” business segment (loss)/income includes results of the stand-alone corporate operations of HEI and ASB Hawaii, Inc. (ASBH), ~~both holding companies;~~as well as the results of Pacific Current, LLC, a newly created direct subsidiary of HEI focused on investing in clean energy and sustainability projects; Pacific Current’s indirect subsidiary, Hamakua Energy, LLC, which owns a 60-MW combined cycle power plant, formerly owned by Hamakua Energy Partners, L.P.; Pacific Current’s indirect subsidiary, Mauo, LLC (Mauo), which is currently constructing a solar-plus-storage project; HEI Properties, Inc., a company which held passive, venture capital investments (all of which have been sold or abandoned prior to its dissolution in December 2015 and final winding up in June 2017); and The Old Oahu Tug Service, Inc., a maritime freight transportation company that ceased operations in 1999, but has remaining employee benefit ~~payments;~~payments obligations; as well as eliminations of intercompany transactions. ~~Expenses recorded at HEI related~~

Acquisition of a Solar + Storage Power Purchase Agreement (PPA). On February 2, 2018, Mauo executed definitive agreements to acquire a solar-plus-storage PPA for a multi-site, commercial-scale project that will provide 8.6 MW of solar capacity and 42.3 MWH of storage capacity on the ~~previously proposed merger~~islands of Maui and Oahu. The PPA has a 15-year term with ~~NEE and spin-off of ASBH amounted to $2.0 million and $3.5 million~~an option for the ~~second quarter~~customer to extend for an additional five years. The system will be constructed by a third-party contractor under an Engineering, Procurement and ~~six months ended June 30, 2016, respectively. See Note 12, “Termination~~Construction (EPC) contract that was contemporaneously negotiated and executed by Mauo. The EPC contract provides a fixed price for the construction of ~~proposed merger~~the system, a project completion schedule and ~~other matters.”~~performance obligations designed to match the requirements of the PPA. Mauo plans to fund the construction of the project with a construction loan facility that will be repaid at the commercial operation date (ultimately with cash from investment tax credits, state renewable tax credits and non-recourse project debt). The facilities are expected to be operational in 2019.

~~FINANCIAL CONDITION~~RESULTS OF OPERATIONS

~~Liquidity~~



(in thousands, except per	Three months ended June 30				%
share amounts)	2018		2017		change	Primary reason(s)*
Revenues	$	685,277	$	632,281	8	Increases for the electric utility and bank segments
Operating income	78,799		77,802		1	Increase for the bank segment and lower operating losses for the “other” segment, partly offset by slight decrease for the electric utility segment
Net income for common stock	46,054		38,661		19	Higher net income at the electric utility and bank segments, partly offset by higher net losses at the “other” segment. See below for effective tax rate explanation.
Basic earnings per common share	$	0.42	$	0.36	17	Higher net income
Weighted-average number of common shares outstanding	108,842		108,750		—	Issuances of shares under compensation and director stock plans.



(in thousands, except per	Six months ended June 30				%
share amounts)	2018		2017		change	Primary reason(s)*
Revenues	$	1,331,151	$	1,223,843	9	Increases for the electric utility and bank segments
Operating income	150,688		147,540		2	Increase for the bank segment and lower operating losses for the “other” segment, partly offset by slight decrease for the electric utility segment
Net income for common stock	86,301		72,854		18	Higher net income at the electric utility and bank segments, partly offset by higher net losses at the “other” segment. See below for effective tax rate explanation.
Basic earnings per common share	$	0.79	$	0.67	18	Higher net income
Weighted-average number of common shares outstanding	108,830		108,712		—	Issuances of shares under compensation and director stock plans.


*	Also, see segment discussions which follow.

The Company’s effective tax rates (combined federal and ~~capital resources.~~ The Company believes that its ability to generate cash, both internally from electric utility and banking operations and externally from issuances of equity and debt securities, commercial paper and bank borrowings, is adequate to maintain sufficient liquidity to fund its contractual obligations and commercial commitments, its forecasted capital expenditures and investments, its expected retirement benefit plan contributions and other cash requirementsstate income tax rates) for the ~~foreseeable future.~~

second quarters of 2018 and 2017 were 22% and 34%, respectively. The ~~consolidated capital structure of HEI (excluding deposit liabilities and other bank borrowings) was as follows:~~

(dollars in millions) June 30, 2017 December 31, 2016
Short-term borrowings—other than bank $ 50
1 % $ —
— %
Long-term debt, net—other than bank 1,619
43
1,619
43
Preferred stock of subsidiaries 34
1
34
1
Common stock equity 2,075
55
2,067
56
$ 3,778
100 % $ 3,720
100 %

~~HEI’s short-term borrowings and HEI’s line of credit facility were as follows:~~

Average balance Balance
(in millions) Six months ended June 30, 2017 June 30, 2017 December 31, 2016
Short-term borrowings ¹

Commercial paper $ 1
$ 6
$ —
Line of credit draws —
—
—
Undrawn capacity under HEI’s line of credit facility 150
150

¹ This table does not include Hawaiian Electric’s separate commercial paper issuances and line of credit facilities and draws, which are disclosed below under “Electric utility—Financial Condition—Liquidity and capital resources.” The maximum amount of HEI’s external short-term borrowings duringCompany’s effective tax rates for the first six months of 2018 and 2017 were 23% and 34%, respectively. The effective tax rates were lower for the three and six months ended June 30, 2018 compared to the same periods in 2017 due primarily to the provision in the Tax Act that lowered the federal income tax rate from 35% to 21%. The lower tax rate was ~~$6.0 million. As of July 27, 2017, HEI had $7.3 million of outstanding commercial paper, and its line of credit facility was undrawn.~~

~~HEI has a $150 million line of credit facility. See Note 5 of the Condensed Consolidated Financial Statements.~~

From December 7, 2016 to date, HEI satisfied the share purchase requirements of the HEI Dividend Reinvestment and Stock Purchase Plan (DRIP), HEIRSP and ASB 401(k) Plan through open market purchases of its common stock rather than through new issuances.

~~In December 2014, HEI filed an omnibus registration statement to register an indeterminate amount of debt and equity securities.~~

~~For~~partially offset by lower excess tax benefits associated with share-based awards in the first six months of ~~2017, net cash provided by operating activities of HEI consolidated was $186 million. Net cash used by investing activities for~~2018 as compared to the same period of 2017 and other Tax Act changes (the non-deductibility of excess executive compensation and various fringe benefit costs and loss of the domestic production activities deduction). Note that although the Utilities’ effective income tax rate decreased, the net benefits of the Tax Act, including the lower effective tax rate, are being returned to customers through rates.

HEI’s consolidated ROACE was ~~$399 million,~~8.6% for the twelve months ended June 30, 2018 and 12.1% for the twelve months ended June 30, 2017. The lower ROACE for the twelve months ended June 30, 2018 compared to the twelve months ended June 30,

2017 was primarily due to ~~Hawaiian Electric’s consolidated capital expenditures and ASB’s purchases of investment securities and net increase~~the merger termination fee received in ~~loans held~~July 2016 when HEI’s planned merger with NextEra Energy was terminated.

Dividends. The payout ratios for investment, partly offset by ASB’s receipt of repayments from investment securities, proceeds from the sale of commercial loans and Hawaiian Electric’s contributions in aid of construction. Net cash provided by financing activities during this period was $145 million as a result of several factors, including increases in short-term borrowings and ASB’s deposit liabilities, proceeds from other bank borrowings and net increases in ASB’s retail purchase agreements, partly offset by the payment of common stock dividends and repayments of other bank borrowings. Also included in cash provided by financing activities were proceeds from the issuance of special purpose revenue bonds (SPRBs), which were offset by the transfer of funds to a trustee for the redemption of previously issued SPRBs. Other than capital contributions from their parent company, intercompany services (and related intercompany payables and receivables), Hawaiian Electric’s periodic short-term borrowings from HEI (and related interest) and the payment of dividends to HEI, the electric utility and bank segments are largely autonomous in their operating, investing and financing activities. (See the electric utility and bank segments’ discussions of their cash flows in their respective “Financial condition—Liquidity and capital resources” sections below.) During the first six months of 2018 and full year 2017 ~~Hawaiian Electric~~were 78% and ~~ASB (through ASB Hawaii) paid cash dividends~~82%, respectively. HEI currently expects to maintain its dividend at its present level; however, the HEI Board of ~~$44 million~~Directors evaluates the dividend quarterly and ~~$19 million, respectively.~~

~~CERTAIN FACTORS THAT MAY AFFECT FUTURE RESULTS AND FINANCIAL CONDITION~~

~~The Company’s results of operations and financial condition can be affected by numerous~~considers many factors ~~many of which are beyond~~in the ~~Company’s control and could cause future results of operations~~evaluation including, but not limited to, differ materially from historical results. For information about certain of these factors, see pages 47, 62 to 64, and 73 to 75 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2016 Form 10-K.

~~Additional factors that may affect future results and financial condition are described on pages iv and v under “Cautionary Note Regarding Forward-Looking Statements.”~~

~~MATERIAL ESTIMATES AND CRITICAL ACCOUNTING POLICIES~~

In preparing financial statements, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent assets and liabilities and the reported amounts of revenues and expenses. Actual results could differ significantly from those estimates.

In accordance with SEC Release No. 33-8040, “Cautionary Advice Regarding Disclosure About Critical Accounting Policies,” management has identified the accounting policies it believes to be the most critical to the Company’s financial statements—that is, management believes that these policies are both the most important to the portrayal of the Company’s results of operations, the long-term prospects for the Company and ~~financial condition,~~current and ~~currently require management’s most difficult, subjective or complex judgments.~~expected future economic conditions.

~~For information about these material estimates~~Economic conditions.

Note: The statistical data in this section is from public third-party sources that management believes to be reliable (e.g., Department of Business, Economic Development and ~~critical accounting policies, see pages 48~~Tourism (DBEDT), University of Hawaii Economic Research Organization, U.S. Bureau of Labor Statistics, Department of Labor and Industrial Relations (DLIR), Hawaii Tourism Authority (HTA), Honolulu Board of REALTORS® and national and local newspapers).

Through the first half of 2018, Hawaii’s tourism industry, a significant driver of Hawaii’s economy, continued to ~~49, 64~~grow in both visitor spending and arrivals. Visitor expenditures increased 10.8% and arrivals increased 8.2% compared to ~~65,~~the same period in 2017. Looking ahead, the Hawaii Tourism Authority expects scheduled nonstop seats to Hawaii to increase as the year progresses, driven primarily by an increase in seats from West Coast, East Coast and 75Asia.

Hawaii’s unemployment rate remained steady at 2.1% for June 2018, which was lower than the 2.4% rate for the same period a year ago and lower than the national unemployment rate of 4.0%. It is also the lowest unemployment rate in the nation.

Hawaii real estate activity, as indicated by the home resale market, experienced a decline in median sales prices for single family homes and growth in median sales prices for condominiums so far in 2018. Median sales prices for single family residential homes on Oahu through June 2018 were higher by 3.9% and for condominiums were higher by 6.5%, over the same time period in 2017. The number of closed sales for single family residential homes was down by 1.6% and for condominiums was up 1.3% through June of 2018 compared to 78same time period of ~~HEI’s MD&A included~~2017.

Hawaii’s petroleum product prices reflect supply and demand in ~~Part II, Item 7~~the Asia-Pacific region and the price of ~~HEI’s 2016 Form 10-K.~~crude oil in international markets. Although the price of crude oil fluctuates month to month, the general trend has been an increasing one over the last 2.5 years.

At its June 2018 meeting, the Federal Open Market Committee (FOMC) decided to raise the target range for the federal funds rate from “1.75% to 2%” in view of realized and expected labor market conditions and inflation. The FOMC will continue to assess economic conditions relative to its objectives of maximum employment and 2% inflation in determining the size and timing of future adjustments to the target range.

Hawaii’s economic expansion continues with strong visitor arrivals and spending. The construction industry is more volatile, with expected slowing as major projects in the resort, retail and multifamily residential sectors are scheduled for completion in the next few years. Record low unemployment rates are likely to support stronger gains in income. Potential risks include infrastructure constraints, tight labor markets and high housing costs creating inflationary pressures, uncertainty in the national economic outlook due to potential trade wars and natural disasters.

“Other” segment.



	Three months ended June 30						Six months ended June 30
(in thousands)	2018			2017			2018			2017			Primary reason(s)
Revenues	$	47		$	77		$	75		$	172
Operating loss	(3,262		)	(3,677		)	(7,629		)	(8,655		)	Second quarter and first six months of 2018 includes $1.3 million and $2.3 million, respectively, of operating income from Pacific Current, LLC¹. Second quarter and first six months of 2018 corporate expense was slightly higher than same periods in 2017.
Net loss	(5,676		)	(3,716		)	(11,864		)	(6,801		)	Second quarter and first six months of 2018 includes higher interest expense (due to higher interest rates and balances at corporate and new debt at Pacific Current, LLC related to Hamakua Energy’s acquisition of a power plant) and lower tax benefits on expenses as a result of tax reform in second quarter and first six months of 2018 as compared to the same periods in 2017.

~~Following are discussions~~

The “other” business segment (loss)/income includes results of the stand-alone corporate operations of HEI and ASB Hawaii, Inc. (ASBH), as well as the results of Pacific Current, LLC, a newly created direct subsidiary of HEI focused on investing in clean energy and sustainability projects; Pacific Current’s indirect subsidiary, Hamakua Energy, LLC, which owns a 60-MW combined cycle power plant, formerly owned by Hamakua Energy Partners, L.P.; Pacific Current’s indirect subsidiary, Mauo, LLC (Mauo), which is currently constructing a solar-plus-storage project; HEI Properties, Inc., a company which held passive, venture capital investments (all of which have been sold or abandoned prior to its dissolution in December 2015 and final winding up in June 2017); and The Old Oahu Tug Service, Inc., a maritime freight transportation company that ceased operations ~~liquidity~~in 1999, but has remaining employee benefit payments obligations; as well as eliminations of intercompany transactions.

Acquisition of a Solar + Storage Power Purchase Agreement (PPA). On February 2, 2018, Mauo executed definitive agreements to acquire a solar-plus-storage PPA for a multi-site, commercial-scale project that will provide 8.6 MW of solar capacity and ~~capital resources~~42.3 MWH of storage capacity on the islands of Maui and Oahu. The PPA has a 15-year term with an option for the customer to extend for an additional five years. The system will be constructed by a third-party contractor under an Engineering, Procurement and Construction (EPC) contract that was contemporaneously negotiated and executed by Mauo. The EPC contract provides a fixed price for the construction of the ~~electric utility~~system, a project completion schedule and ~~bank segments.~~performance obligations designed to match the requirements of the PPA. Mauo plans to fund the construction of the project with a construction loan facility that will be repaid at the commercial operation date (ultimately with cash from investment tax credits, state renewable tax credits and non-recourse project debt). The facilities are expected to be operational in 2019.

~~Electric utility~~

RESULTS OF OPERATIONS

~~Results.~~

Three months ended June 30 Increase
2017 2016 (decrease) (dollars in millions, except per barrel amounts)
$ 557
$ 495
$ 62

Revenues. Net increase largely due to:
$ 55

higher fuel oil prices¹
11

higher purchased power energy costs²
(8 ) lower RAM revenues due to expiration of 2013 settlement agreement that allowed the accrual of RAM revenues on January 1 (vs. June 1) for years 2014 to 2016 at Hawaiian Electric
3
higher PPAC revenues
2
higher RAM revenues
(3 ) lower KWH generated
141
92
49

Fuel oil expense. Increase due to higher fuel oil prices
153
139
14

Purchased power expense. Increase due to higher fuel oil prices
106
100
6

Operation and maintenance expenses. Net increase due to:
1
higher overhaul costs due to timing
1
ERP project costs commencing in 2017
1
higher maintenance costs
1
Grid modernization consultant costs
1
write off of portion of deferred Geothermal RFP costs
1
Property damage reserve for customer claim in 2017
(1 ) LNG consulting costs incurred in 2016 to negotiate an LNG contract that was subsequently terminated following HEI/NextEra merger termination
101
94
7

Other expenses. Increase due to higher revenue taxes from higher revenue, coupled with higher depreciation expense for plant investments in 2016
55
71
(16 )
Operating income. Decrease due to lower RAM revenues and higher O&M and depreciation expenses
26
36
(10 )
Net income for common stock. Decrease due to lower operating income, partially offset by resulting lower income taxes.

2,150
2,156
(6 )
Kilowatthour sales (millions)⁴
1,278
1,257
21
Cooling degree days (Oahu)
$ 69.86
$ 44.98
$ 24.88

Average fuel oil cost per barrel¹

Six months ended June 30 Increase
2017 2016 (decrease) (dollars in millions, except per barrel amounts)
$ 1,075
$ 977
$ 98

Revenues. Net increase largely due to:
$ 90

higher fuel oil prices¹
33

higher purchased power energy costs²
(20 ) lower RAM revenues due to expiration of 2013 settlement agreement that allowed the accrual of RAM revenues on January 1 (vs. June 1) for years 2014 to 2016 at Hawaiian Electric
3
higher RAM revenues
(2 ) lower PPAC revenues
(3 ) lower KWH purchased
(2 ) lower KWH generated
286
206
80

Fuel oil expense. Increase due to higher fuel oil prices
280
255
25

Purchased power expense. Increase due to higher fuel oil prices
207
203
4

Operation and maintenance expenses. Net increase due to:
2
higher overhaul costs due to timing
2
ERP project costs commencing in 2017
2

higher maintenance costs

1

Grid modernization consultant costs

1

write off of portion of deferred Geothermal RFP costs

1

Property damage reserve for customer claim in 2017

1

additional reserves for environmental costs in 2017³
(4 ) PSIP consulting costs incurred in 2016, in order to complete the PSIP update in April 2016
(3 ) LNG consulting costs incurred in 2016 to negotiate an LNG contract that was subsequently terminated following HEI/NextEra merger termination
199
187
12

Other expenses. Increase due to higher revenue taxes from higher revenue, coupled with higher depreciation expense for plant investments in 2016
104
126
(22 )
Operating income. Decrease due to lower RAM revenues and higher O&M and depreciation expenses
47
61
(14 )
Net income for common stock. Decrease due to lower operating income, partially offset by resulting lower income taxes.

4,188
4,241
(53 )
Kilowatthour sales (millions)⁴
2,162
2,141
21
Cooling degree days (Oahu)
$ 67.78
$ 49.05
$ 18.73

Average fuel oil cost per barrel¹
460,858
458,893
1,965
Customer accounts (end of period)



(in thousands, except per	Three months ended June 30				%
share amounts)	2018		2017		change	Primary reason(s)*
Revenues	$	685,277	$	632,281	8	Increases for the electric utility and bank segments
Operating income	78,799		77,802		1	Increase for the bank segment and lower operating losses for the “other” segment, partly offset by slight decrease for the electric utility segment
Net income for common stock	46,054		38,661		19	Higher net income at the electric utility and bank segments, partly offset by higher net losses at the “other” segment. See below for effective tax rate explanation.
Basic earnings per common share	$	0.42	$	0.36	17	Higher net income
Weighted-average number of common shares outstanding	108,842		108,750		—	Issuances of shares under compensation and director stock plans.



(in thousands, except per	Six months ended June 30				%
share amounts)	2018		2017		change	Primary reason(s)*
Revenues	$	1,331,151	$	1,223,843	9	Increases for the electric utility and bank segments
Operating income	150,688		147,540		2	Increase for the bank segment and lower operating losses for the “other” segment, partly offset by slight decrease for the electric utility segment
Net income for common stock	86,301		72,854		18	Higher net income at the electric utility and bank segments, partly offset by higher net losses at the “other” segment. See below for effective tax rate explanation.
Basic earnings per common share	$	0.79	$	0.67	18	Higher net income
Weighted-average number of common shares outstanding	108,830		108,712		—	Issuances of shares under compensation and director stock plans.


1*	~~The rate schedules of the electric utilities currently contain energy cost adjustment clauses (ECACs) through~~Also, see segment discussions which ~~changes in fuel oil prices and certain components of purchased energy costs are passed on to customers.~~


2	The rate schedules of the electric utilities currently contain purchase power adjustment clauses (PPAC) through which changes in purchase power expenses (except purchased energy costs) are passed on to customers.


3	~~Increase reserve for additional costs for investigation of PCB contamination onshore and offshore of Waiau Power Plant~~


4	KWH sales were lower when compared to the same quarter in the prior year due largely to continued energy efficiency and conservation efforts by customers and increasing levels of private customer-sited renewable generation.follow.

~~Hawaiian Electric’s~~The Company’s effective tax rates (combined federal and state income tax rates) for the second quarters of 2018 and 2017 were 22% and 34%, respectively. The Company’s effective tax rates for the first six months of 2018 and 2017 were 23% and 34%, respectively. The effective tax rates were lower for the three and six months ended June 30, 2018 compared to the same periods in 2017 due primarily to the provision in the Tax Act that lowered the federal income tax rate from 35% to 21%. The lower tax rate was partially offset by lower excess tax benefits associated with share-based awards in the first six months of 2018 as compared to the same period of 2017 and other Tax Act changes (the non-deductibility of excess executive compensation and various fringe benefit costs and loss of the domestic production activities deduction). Note that although the Utilities’ effective income tax rate decreased, the net benefits of the Tax Act, including the lower effective tax rate, are being returned to customers through rates.

HEI’s consolidated ROACE was ~~7.2%~~8.6% for the twelve months ended June 30, ~~2017,~~2018 and ~~8.0%~~12.1% for the twelve months ended June 30, ~~2016.~~2017. The lower ROACE for the twelve months ended June 30, 2018 compared to the twelve months ended June 30,

2017 was primarily due to the merger termination fee received in July 2016 when HEI’s planned merger with NextEra Energy was terminated.

Dividends.The ~~Utilities’ consolidated KWH sales have declined each year since 2007. Based on expectations~~payout ratios for the first six months of ~~additional customer renewable self-generation~~2018 and ~~energy-efficiency installations, the Utilities’~~ full year 2017 ~~KWH sales are~~were 78% and 82%, respectively. HEI currently expects to maintain its dividend at its present level; however, the HEI Board of Directors evaluates the dividend quarterly and considers many factors in the evaluation including, but not limited to, the Company’s results of operations, the long-term prospects for the Company and current and expected future economic conditions.

Economic conditions.

Note: The statistical data in this section is from public third-party sources that management believes to be ~~below~~reliable (e.g., Department of Business, Economic Development and Tourism (DBEDT), University of Hawaii Economic Research Organization, U.S. Bureau of Labor Statistics, Department of Labor and Industrial Relations (DLIR), Hawaii Tourism Authority (HTA), Honolulu Board of REALTORS® and national and local newspapers).

Through the ~~2016 level.~~first half of 2018, Hawaii’s tourism industry, a significant driver of Hawaii’s economy, continued to grow in both visitor spending and arrivals. Visitor expenditures increased 10.8% and arrivals increased 8.2% compared to the same period in 2017. Looking ahead, the Hawaii Tourism Authority expects scheduled nonstop seats to Hawaii to increase as the year progresses, driven primarily by an increase in seats from West Coast, East Coast and Asia.

Hawaii real estate activity, as indicated by the home resale market, experienced a decline in median sales prices for single family homes and growth in median sales prices for condominiums so far in 2018. Median sales prices for single family residential homes on Oahu through June 2018 were higher by 3.9% and for condominiums were higher by 6.5%, over the same time period in 2017. The number of closed sales for single family residential homes was down by 1.6% and for condominiums was up 1.3% through June of 2018 compared to same time period of 2017.

Hawaii’s petroleum product prices reflect supply and demand in the Asia-Pacific region and the price of crude oil in international markets. Although the price of crude oil fluctuates month to month, the general trend has been an increasing one over the last 2.5 years.

“Other” segment.



	Three months ended June 30						Six months ended June 30
(in thousands)	2018			2017			2018			2017			Primary reason(s)
Revenues	$	47		$	77		$	75		$	172
Operating loss	(3,262		)	(3,677		)	(7,629		)	(8,655		)	Second quarter and first six months of 2018 includes $1.3 million and $2.3 million, respectively, of operating income from Pacific Current, LLC¹. Second quarter and first six months of 2018 corporate expense was slightly higher than same periods in 2017.
Net loss	(5,676		)	(3,716		)	(11,864		)	(6,801		)	Second quarter and first six months of 2018 includes higher interest expense (due to higher interest rates and balances at corporate and new debt at Pacific Current, LLC related to Hamakua Energy’s acquisition of a power plant) and lower tax benefits on expenses as a result of tax reform in second quarter and first six months of 2018 as compared to the same periods in 2017.

The ~~net book value (cost less accumulated depreciation)~~“other” business segment (loss)/income includes results of ~~utility property,~~the stand-alone corporate operations of HEI and ASB Hawaii, Inc. (ASBH), as well as the results of Pacific Current, LLC, a newly created direct subsidiary of HEI focused on investing in clean energy and sustainability projects; Pacific Current’s indirect subsidiary, Hamakua Energy, LLC, which owns a 60-MW combined cycle power plant, ~~and equipment (PPE) as of June 30, 2017 amounted to $4 billion,~~formerly owned by Hamakua Energy Partners, L.P.; Pacific Current’s indirect subsidiary, Mauo, LLC (Mauo), which is currently constructing a solar-plus-storage project; HEI Properties, Inc., a company which held passive, venture capital investments (all of which ~~approximately 25% related~~have been sold or abandoned prior to ~~production PPE, 66% related~~its dissolution in December 2015 and final winding up in June 2017); and The Old Oahu Tug Service, Inc., a maritime freight transportation company that ceased operations in 1999, but has remaining employee benefit payments obligations; as well as eliminations of intercompany transactions.

Acquisition of a Solar + Storage Power Purchase Agreement (PPA). On February 2, 2018, Mauo executed definitive agreements to ~~transmission~~acquire a solar-plus-storage PPA for a multi-site, commercial-scale project that will provide 8.6 MW of solar capacity and ~~distribution PPE,~~42.3 MWH of storage capacity on the islands of Maui and ~~9% related~~Oahu. The PPA has a 15-year term with an option for the customer to ~~other PPE. Approximately 11%~~extend for an additional five years. The system will be constructed by a third-party contractor under an Engineering, Procurement and Construction (EPC) contract that was contemporaneously negotiated and executed by Mauo. The EPC contract provides a fixed price for the construction of the ~~total net book value relates~~system, a project completion schedule and performance obligations designed to ~~generation PPE~~match the requirements of the PPA. Mauo plans to fund the construction of the project with a construction loan facility that ~~has been deactivated or that~~will be repaid at the ~~Utilities plan to deactivate or decommission. See “Adequacy of supply” below.~~

~~See “Economic conditions” in the “HEI Consolidated” section above.~~

~~Executive overview~~commercial operation date (ultimately with cash from investment tax credits, state renewable tax credits and ~~strategy.~~ The Utilities provide electricity on all the principal islands in the state other than Kauai and operate five separate grids. The Utilities’ mission is to provide innovative energy leadership for Hawaii, to meet the needs and expectations of customers and communities, and to empower them with affordable, reliable and clean energy. The goal is to create a modern, flexible and dynamic electric grid that enables an optimal mix of distributed energy resources (such as private rooftop solar), demand response and grid-scale resources to achieve the statutory goal of 100% renewable energy by 2045.

~~Transition to renewable energy.~~ The Utilities are committed to assisting the State of Hawaii in achieving its Renewable Portfolio Standard goal of 100% renewable energy by 2045. Hawaii’s Renewable Portfolio Standards (RPS) law was revised in the 2015 Legislature and requires electric utilities to meet an RPS of 15%, 30%, 40%, 70% and 100% by December 31, 2015, 2020, 2030, 2040 and 2045, respectively. Energy savings resulting from demand-side management (DSM) energy efficiency programs and solar water heating do not count toward these RPS. The Utilities have been successful in adding significant amounts of renewable energy resources to their electric systems and exceeded the 2015 RPS goal. The Utilities' RPS for 2016 was about 26% and on its way to achieving the 2020 RPS goal of 30%non-recourse project debt). The ~~Utilities led the nation in 2016 and 2015 in the percentage of its customers who have installed PV systems. (See "Developments in renewable energy efforts” below).~~

In 2014, Hawaiian Electric, Hawaii Electric Light and Maui Electric filed proposed Power Supply Improvement Plans (PSIPs) with the PUC, as required by PUC orders issued in April 2014. Updated PSIPs were filed in April 2016 providing plans to achieve 100% renewable energy using a diverse mix of energy resources by 2045. Under these plans, the Utilities will 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. The Utilities already have the highest percentage of customers using private rooftop solar of any utility in the U.S. and customer-sited resources are seen as a key contributor to the growth of the renewable portfolio on every island. In addition, the plans forecast the addition of 360 MW of grid-scale solar and 157 MW of grid-scale wind, with 32 MW derived from community-based renewable energy (CBRE). The plans also include 115 MW from Demand Response (DR) programs, which can shift customer use of electricity to times when more renewable energy is available, potentially making room to add even more renewable resources. Unlike the April 2016 updated PSIPs, the December 2016 update does not include the use of LNG to generate power in the near-term or the Kahe 3x1 Combined Cycle Plant. While LNG remains a potential lower-cost bridge fuel to be evaluated, the Utilities’ priority is to continue replacing fossil fuel generation with renewables over the next five years as federal tax incentives for renewables begin to phase out. An interisland cable is not in the near-term plan, which states that its costs and benefits should continue to be evaluated. In July 2017, the PUC accepted the Utilities’ PSIP December 2016 Update Report and closed the proceeding. See “April 2014 regulatory orders” in Note 3 of the Condensed Consolidated Financial Statements.

On October 1, 2015, Hawaiian Electric, Hawaii Electric Light and Maui Electric filed a proposed CBRE program and tariff with the PUC that would allow customers who cannot, or chose not to, take advantage of private rooftop solar to receive the benefits of renewable energy to help offset their monthly electric bills and support clean energy for Hawaii. In November 2015, the PUC suspended the tariff submittal and opened an investigatory docket. In February 2017, the PUC issued a proposed CBRE Program Framework and a Proposed Model Tariff Language, which significantly increased the scope of the program. Under the proposed CBRE Program Framework, the CBRE program will utilize a phased approach. The Program Framework proposes a Phase 1 with an 80 MW capacity statewide with 73 MW allocated to the Utilities' service territories. During Tranche A of the CBRE Phase 1 Program, the Utilities' primary role is to serve as the program administrator. In Tranche B, the Utilities are allowed to develop 9 MW in the service territories, 75% of the capacity is reserved for low-to-moderate income subscribers. In March 2017, the Utilities submitted comments to the Program Framework, which identified certain concerns should the proposed CBRE Program Framework be adopted and requested a technical conference before a decision is issued. In June 2017, a technical conference with the PUC was completed with the Utilities, the Consumer Advocate and industry stakeholders. The Utilities are awaiting the PUC’s decision on the CBRE program.

After launching a smart grid customer engagement plan during the second quarter of 2014, Hawaiian Electric replaced approximately 5,200 residential and commercial meters with smart meters, 160 direct load control switches, fault circuit

indicators and remote controlled switches in selected areas across Oahu as part of the Smart Grid Initial Phase implementation. Also under the Initial Phase a grid efficiency measure called Volt/Var Optimization (or Conservation Voltage Reduction) was enabled, customer energy portals were launched and are available for customer use and a PrePay Application was launched. The Initial Phase implementation was completed in 2015. The smart grid provides benefits such as customer tools to manage their electric bills, potentially shortening outages and enabling the Utilities to integrate more low-cost renewable energy, like wind and solar, which will reduce Hawaii’s dependence on imported oil.

In March 2016, the Utilities sought PUC approval to commit funds for an expansion of the smart grid project. The proposed smart grid project was estimated to cost $340 million and to be implemented over 5 years. On January 4, 2017, the PUC issued an order dismissing the application without prejudice and directing the Utilities to submit a Grid Modernization Strategy.

~~Decoupling.~~ ~~See "Decoupling" in Note 3 of the Condensed Consolidated Financial Statements for a discussion of changes to the RAM component of decoupling.~~

As part of decoupling, the Utilities also track their rate-making ROACEs as calculated under the earnings sharing mechanism, which includes only items considered in establishing rates. At year-end, each utility's rate-making ROACE is compared against its ROACE allowed by the PUC to determine whether earnings sharing has been triggered. Annual earnings of a utility over and above the ROACE allowed by the PUC are shared between the utility and its ratepayers on a tiered basis. Results for 2016 and 2015 did not trigger the earnings sharing mechanism for the Utilities. For 2014, the earnings sharing mechanism was triggered for Maui Electric, and Maui Electric credited $0.5 million to its customers for their portion of the earnings sharing during the period between June 2015 to May 2016. Earnings sharing credits are included in the annual decoupling filing for the following year.

~~Regulated Returns.Actual and PUC-allowed (as of June 30, 2017) returns were as follows:~~

% Return on rate base (RORB)* ROACE** Rate-making ROACE***
Twelve months ended June 30, 2017 Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric
Utility returns 6.77
6.71
6.83
7.25
6.91
7.50
7.99
7.54
7.96
PUC-allowed returns 8.11
8.31
7.34
10.00
10.00
9.00
10.00
10.00
9.00
Difference (1.34 ) (1.60 ) (0.51 ) (2.75 ) (3.09 ) (1.50 ) (2.01 ) (2.46 ) (1.04 )

* Based on recorded operating income and average rate base, both adjusted for items not included in determining electric rates.

** Recorded net income divided by average common equity.

*** ROACE adjusted to remove items not included by the PUC in establishing rates, such as incentive compensation.

The gap between PUC-allowed ROACEs and the ROACEs actually achieved is primarily due to: the consistent exclusion of certain expenses from rates, the recognition of annual RAM revenues on June 1 annually rather than on January 1, the low RBA interest rate (currently a short-term debt rate rather than the actual cost of capital), O&M increases and return on capital additions since the last rate case in excess of indexed escalations, and the portion of the pension regulatory asset not earning a return due to pension contributions and pension costs in excess of the pension amount in rates.

The PUC approved a two-year special medical needs pilot program, which will provide residential customers who depend on life support a discounted non-fuel energy charge. The program will be effective from April 1, 2017 to March 31, 2019, with a maximum savings of $20 per month per participant and limited to 2,000 participants. The discount will not be reflected as part of the target adjusted revenues in the RBA Provision.

~~Most recent rate proceedings.~~ Unless otherwise agreed or ordered, each electric utility is currently required by PUC order to initiate a rate proceeding every third year (on a staggered basis) to allow the PUC and the Consumer Advocate to regularly evaluate decoupling and to allow the utility to request electric rate increases to cover rising operating costs and the cost of plant and equipment, including the cost of new capital projects to maintain and improve service reliability. The PUC may grant an interim increase within 10 to 11 months following the filing of an application, but there is no guarantee of such an interim increase and interim amounts collected are refundable, with interest, to the extent they exceed the amount approved in the

PUC’s final D&O. The timing and amount of any final increase is determined at the discretion of the PUC. The adoption of revenue, expense, rate base and cost of capital amounts (including the ROACE and RORB) for purposes of an interim rate increase does not commit the PUC to accept any such amounts in its final D&O.

Test year
(dollars in millions)

Date
(filed/
implemented)
Amount
% over
rates in
effect

ROACE
(%)

RORB
(%)

Rate
base

Common
equity
%

Stipulated
agreement
reached with
Consumer
Advocate
Hawaiian Electric

2011 (1)

Request 7/30/10 $ 113.5
6.6
10.75
8.54
$ 1,569
56.29
Yes
Interim increase 7/26/11 53.2
3.1
10.00
8.11
1,354
56.29

Interim increase (adjusted) 4/2/12 58.2
3.4
10.00
8.11
1,385
56.29

Interim increase (adjusted) 5/21/12 58.8
3.4
10.00
8.11
1,386
56.29

Final increase 9/1/12 58.1
3.4
10.00
8.11
1,386
56.29

2014 (2)

Request 6/27/14
2017 (3)

Request 12/16/16 $ 106.4
6.9
10.60
8.28
$ 2,002
57.36

Hawaii Electric Light

2010 (4)

Request 12/9/09 $ 20.9
6.0
10.75
8.73
$ 487
55.91
Yes
Interim increase 1/14/11 6.0
1.7
10.50
8.59
465
55.91

Interim increase (adjusted) 1/1/12 5.2
1.5
10.50
8.59
465
55.91

Final increase 4/9/12 4.5
1.3
10.00
8.31
465
55.91

2013 (5)

Request 8/16/12 $ 19.8
4.2
10.25
8.30
$ 455
57.05

Closed 3/27/13

2016 (6)

Request 9/19/16 $ 19.3
6.5
10.60
8.44
$ 479
57.12
Yes
Statements of Probable Entitlement (which will be superceded by any PUC interim D&O)

Hawaii Electric Light 7/21/17 11.1
3.8
9.75
7.94
482
56.69

Consumer Advocate 7/21/17 9.9
3.4
9.5
7.8
482
56.69

Maui Electric

2012 (7)

Request 7/22/11 $ 27.5
6.7
11.00
8.72
$ 393
56.85
Yes
Interim increase 6/1/12 13.1
3.2
10.00
7.91
393
56.86

Final increase 8/1/13 5.3
1.3
9.00
7.34
393
56.86

2015 (8)

Request 12/30/14
2018 (9)

Note: The “Request Date” reflects the application filing date for the rate proceeding. All other line items reflect the effective dates of the revised schedules and tariffs as a result of PUC-approved increases.

(1) Hawaiian Electric filed a request with the PUC for a general rate increase of $113.5 million, based on depreciation rates and methodology as proposed by Hawaiian Electric in a separate depreciation proceeding. Hawaiian Electric’s request was primarily to pay for major capital projects and higher O&M costs to maintain and improve service reliability and to recover the costs for several proposed programs to help reduce Hawaii’s dependence on imported oil, and to further increase reliability and fuel security.

The $53.2 million, $58.2 million and $58.8 million interim increases, and the $58.1 million final increase, include the $15 million in annual revenues that were being recovered through the decoupling RAM prior to the first interim increase.

~~(2) See “Hawaiian Electric 2014 test year rate case” below.~~

~~(3) See “Hawaiian Electric 2017 test year rate case” below.~~

~~(4)~~

Hawaii Electric Light’s request was primarily to cover investments for system upgrade projects, two major transmission line upgrades and increasing O&M expenses. On February 8, 2012, the PUC issued a final D&O, which reflected the approval of decoupling and cost-recovery mechanisms, and on February 21, 2012, Hawaii Electric Light filed its revised tariffs to reflect the increase in rates. On April 4, 2012, the PUC issued an order approving the revised tariffs, which became effective April 9, 2012. Hawaii Electric Light implemented the decoupling mechanism and began tracking the target revenues and actual recorded revenues via a revenue balancing account. Hawaii Electric Light also reset the heat rates and implemented heat rate deadbands and the PPAC, which provides a surcharge mechanism that more closely aligns cost recovery with costs incurred. The revised tariffs reflect a lower increase in annual revenue requirement compared to the interim increase due to factors that became effective concurrently with the revised tariffs (lower depreciation rates and lower ROACE) and, therefore, no refund to customers was required.

(5) Hawaii Electric Light’s request was to pay for O&M expenses and additional investments in plant and equipment required to maintain and improve system reliability and to cover the increased costs to support the integration of more renewable energy generation. As a result of a 2013 agreement with the Consumer Advocate, which was approved by the PUC in March 2013, the rate case was withdrawn and the docket was closed.

~~(6)~~

Parties settled on all issues except whether the stipulated ROACE of 9.75% should be reduced by up to 25 basis points for the impact of decoupling. Hawaii Electric Light’s position is that the ROACE that should be used to calculate the interim increase is 9.75% and the Consumer Advocate’s position is that the ROACE that should be used to calculate the interim should be 9.50%. Parties filed separate statement of probable entitlement. The table shows each party’s proposed interim revenue increase based on their respective proposed ROACE. See also “Hawaii Electric Light 2016 test year rate case” below.

(7) Maui Electric’s request was to pay for O&M expenses and additional investments in plant and equipment required to maintain and improve system reliability and to cover the increased costs to support the integration of more renewable energy generation. The final D&O approved an increase in annual revenue of $5.3 million, which was $7.8 million less than the interim increase in annual revenues that had been in effect since June 1, 2012. Maui Electric refunded to customers approximately $9.7 million (which included interest accrued) between September 2013 and early November 2013.


~~(8)~~	~~See “Maui Electric 2015 test year rate case” below.~~


~~(9)~~	~~See “Maui Electric 2018 test year rate case” below.~~

~~Hawaiian Electric 2014 test year rate case~~. On June 27, 2014, Hawaiian Electric submitted an abbreviated rate case filing (abbreviated filing), stating that it intends to forgo the opportunity to seek a general rate increase in base rates and, if approved, this filing would result in no change in base rates. Hawaiian Electric stated that it is foregoing a rate increase request in recognition that its customers are already in a challenging high electricity bill environment, and further explained its view that the abbreviated filing satisfies the obligation to file a general rate case under the three-year cycle established by the PUC in the decoupling final D&O.

~~On December 27, 2016, the PUC issued an order consolidating the filings for this rate case with the Hawaiian Electric 2017 test year rate case and closed the docket.~~

~~See “Hawaiian Electric consolidated 2014 test year abbreviated and 2017 test year cases” in Note 3 of the Condensed Consolidated Financial Statements.~~

~~Maui Electric 2015 test year rate case~~. On December 30, 2014, Maui Electric filed its abbreviated 2015 test year rate case filing. In recognition that its customers have been enduring a high bill environment, Maui Electric proposed no change to its base rates, thereby forgoing the opportunity to seek a general rate increase. Maui Electric stated that, if it were to seek an increase in base rates, its requested increase in revenue, based on its revenue requirement for a normalized 2015 test year, would have been $11.6 million, or 2.8%, over revenues at current effective rates with estimated 2015 RAM revenues. The indicated normalized 2015 test year revenue requirement is based on an estimated cost of common equity of 10.75%.

Management cannot predict whether the PUC will accept this abbreviated filing to satisfy Maui Electric’s obligation to file a rate case in 2015, whether additional material will be required to be submitted, whether Maui Electric will be required to proceed with a traditional rate proceeding or whether the rate case will be consolidated into the 2018 rate case filing.

~~Hawaii Electric Light 2016 test year rate case~~. On September 19, 2016, Hawaii Electric Light filed an application with the PUC for a general rate increase of $19.3 million over revenues at current effective rates (for a 6.5% increase in revenues), based on an 8.44% rate of return (which incorporates a return on equity of 10.60%). The last rate increase in base rates for Hawaii Electric Light was in January 2011. The $19.3 million requested is to cover higher operating costs (including expanded vegetation management focusing on albizia tree removal and increased pension costs) and system upgrades to increase reliability, improve customer service and integrate more renewable energy. As part of this case, Hawaii Electric Light is also taking steps towards innovative ratemaking by proposing implementation of performance based regulation (PBR) mechanisms to measure and link certain revenues to its performance in areas of customer service, reliability and communication relating to the private rooftop solar interconnection process. Hawaii Electric Light proposed an expansion of the range of fuel usage efficiencies under which fuel costs would be fully passed through to customers, and an additional trigger that would allow a re-establishment of fuel usage efficiency targets under certain conditions. In addition, Hawaii Electric Light proposed an equal sharing of fuel expenses outside the fuel usage efficiency target range.

The PUC held public hearings for this rate case in December 2016. On April 13, 2017, the PUC issued an order allowing the County of Hawaii to participate in the proceeding and denying the motions to intervene of two other parties.

On April 28, 2017, the Consumer Advocate filed its testimony in the proceeding, recommending an increase of $2.7 million over revenues at current effective rates (for a 0.9% increase in revenues), based on a 7.29% rate of return (which incorporates a return on equity of 8.75%). On May 25, 2017, the County of Hawaii filed its testimony in the proceeding, recommending reforms in rate design in an effort to support both renewable resources and the financial viability of the transmission and distribution infrastructure that is needed to support those resources.

On June 23, 2017, Hawaii Electric Light filed its rebuttal testimonies, proposing an increase of $16.0 million over revenues at current effective rates based on a rate of return of 8.42% and a return on equity of 10.6%.

On July 11, 2017, Hawaii Electric Light and the Consumer Advocate filed a Stipulated Settlement Letter, which documented agreements reached with the Consumer Advocate on all of the issues in the proceeding, except for the narrowed rate of ROACE issue of whether the stipulated ROACE should be reduced from 9.75% (by up to 25 basis points) based solely on the impact of decoupling, considering current circumstances and relevant precedents. The Parties agree that this narrowed issue is to be addressed through the submission of opening and closing briefs, without the need for an evidentiary hearing on the ROACE issue. On July 14, 2017, the PUC issued a letter canceling previously scheduled evidentiary hearings. On July 21, 2017, the Parties filed separate statements of probable entitlement, proposing the amount of interim revenue increase according to their respective proposed ROACE. See table above. According to State law, an interim D&O should be issued by August 21, 2017.

~~Hawaiian Electric 2017 test year rate case~~. On December 16, 2016, Hawaiian Electric filed an application with the PUC for a general rate increase of $106.4 million over revenues at current effective rates (for a 6.9% increase in revenues), for a 2017 test year. The request is based on an 8.28% rate of return (which incorporates a return on equity of 10.6% and a capital structure that includes a 57.4% common equity capitalization) on a $2.0 billion rate base. The $106.4 million request is primarily to pay for operating costs and for system upgrades to increase reliability, improve customer service and integrate more renewable energy. The application is also proposing a step adjustment to increase base rates by an additional $20.6 million when the Schofield Generation Station is placed in service, which is expected in the second quarter of 2018. As in Hawaii Electric Light’s rate increase application filed in September 2016, Hawaiian Electric’s application is taking steps toward innovative ratemaking by proposing implementation of PBR mechanisms related to its performance in areas of customer service, reliability and communication relating to the private rooftop solar interconnection process. Hawaiian Electric proposed an expansion of the range of fuel usage efficiencies under which fuel costs would be fully passed through to customers, and an additional trigger that would allow a re-establishment of fuel usage efficiency targets under certain conditions. On February 22, 2017, the PUC held public hearings for this rate case. On June 28, 2017, the PUC issued an order denying motions to intervene but allowing limited participant status to six organizations. The procedural schedule for this rate case includes an interim D&O tentatively scheduled for December 15, 2017 and an evidentiary hearing in early March 2018.

~~See “Hawaiian Electric consolidated 2014 test year abbreviated and 2017 test year cases” in Note 3 of the Condensed Consolidated Financial Statements.~~

~~Maui Electric 2018 test year rate case~~. On June 9, 2017, Maui Electric filed a notice of intent with the PUC to file a general rate case application by December 30, 2017 for a 2018 test year. The rate case filing is required to satisfy the obligation to file a general rate case under the three-year rate case cycle established by the PUC in the final D&O in the decoupling proceeding.

~~Performance-based regulation~~. In the Hawaii Electric Light 2016 test year rate case, and the Hawaiian Electric 2017 test year rate case, the Utilities recommended that a separate investigatory docket be opened to evaluate PBR on a broader scale that can be implemented across the Utilities, and to fully develop a comprehensive PBR Framework. PBR refers to different ways in which regulators have modified their regulatory approach in an attempt to strengthen financial incentives for Utilities to achieve desired outcomes. In the its April 27, 2017 order in the Decoupling Investigative proceeding, the PUC stated that it would initiate a separate investigative docket to examine a full range of Performance Incentive Mechanism and PBR options.

~~Depreciation docket~~. In December 2016, the Utilities filed an application with the PUC for approval of changes in the depreciation and amortization rates and amortization period for contributions in aid of construction (CIAC). The application requests that the effective date of implementation of the change in depreciation and amortization rates and revised CIAC amortization period, as recommended by the 2015 Book Depreciation Study, coincide with the effective date of interim base rates (that include the increased expenses resulting from the new depreciation and amortization rates and change in CIAC amortization period) to be established in each of the Utilities’ next general rate cases or the effective date of the decoupling RBA Rate Adjustment that incorporates the new depreciation and amortization rates fo~~r each utility, whichever is sooner.~~

~~Developments in renewable energy efforts~~. Developments in the Utilities’ efforts to further their renewable energy strategy include renewable energy projects discussed in Note 3 of the Condensed Consolidated Financial Statements and the following:

In December 2013, Hawaiian Electric requested PUC approval for a waiver of the Na Pua Makani Power Partners, LLC’s (NPM) proposed 24-MW wind farm located in the Kahuku area on Oahu from the competitive bidding process and the PPA for Renewable As-Available Energy dated October 3, 2013 between Hawaiian Electric and NPM for the proposed 24-MW wind farm. In December 2014, the PUC approved both the waiver request and the PPA. On September 15, 2016, Hawaiian Electric filed the Amended and Restated PPA, dated August 12, 2016, which reflects the completion of the interconnection requirements study, including, among other things, amendments related to the final design of the facility, scope of work, cost, schedule and reporting milestones. The PUC conducted a public hearing on February 2, 2017, regarding the request for PUC approval to construct an overhead 46 sub-transmission line to accommodate the interconnection of the NPM wind farm. This project is expected to be placed into service by August 31, 2019.

In July 2015, the PUC approved the PPA for the 27.6 MW Waianae Solar project that is being developed by Eurus Energy America. The project achieved commercial operations in January 2017 and is now the largest solar project in Hawaii.

In July 2015, Maui Electric signed two PPAs, with Kuia Solar and South Maui Renewable Resources (which subsequently assigned its PPA to SSA Solar of HI 2, LLC and SSA Solar of HI 3, LLC, respectively), each for a 2.87-MW solar facility. In February 2016, the PUC approved both PPAs, subject to certain conditions and modifications. The guaranteed commercial operations date for the facilities ~~was December 31, 2016, however both projects are experiencing delays and~~ are expected to be ~~completed by the end of the fourth quarter~~operational in ~~2017.~~

In September 2015, the PUC approved Hawaiian Electric’s 2-year biodiesel supply contract with Pacific Biodiesel Technologies, LLC (PBT) to supply 2 million to 3 million gallons of biodiesel at Campbell Industrial Park combustion turbine No. 1 (CIP CT-1) and the Honolulu International Airport Emergency Power Facility beginning in November 2015. The PBT contract is set to expire on November 2, 2018. PBT also has a spot buy contract with Hawaiian Electric to purchase additional quantities of biodiesel at or below the price of diesel. Some purchases of “at parity” biodiesel have been made under the spot purchase contract, which was recently extended through June 2018. REG Marketing & Logistics Group, LLC has a contingency supply contract with Hawaiian Electric to also supply biodiesel to CIP CT-1 in the event PBT is not able to supply necessary quantities. This contingency contract has been extended to November 2018, and will continue with no volume purchase requirements.

On April 28, 2017 Hawaiian Electric issued a Biofuel Supply Request for Proposal for 3.1 million gallons of biofuel per year for three years, to commence as early as November 2018 to be used as fuel for power generation at Hawaiian Electric’s Schofield Generating Station, the Honolulu International Airport Emergency Power Facility and any other generating unit on Oahu, as necessary.

On May 5, 2016, Maui Electric filed a request for the PUC to open a docket and assign an Independent Observer to oversee the Maui Electric Dispatchable Firm Generation Request for Proposals. The solicitation intends to seek approximately 20 MW of new renewable generation capacity and approximately 20 MW of fuel flexible firm generation resources on the island of Maui by 2022.

On June 6, 2016, Hawaiian Electric filed a request for the PUC to open a docket and assign an Independent Observer to oversee the Hawaiian Electric Renewable Energy Request for Proposals. The solicitation intends to seek new renewable energy generation on the island of Oahu to be placed into service by the end of 2020, consistent with the Five-Year Action Plan proposed in the PSIP Update Report.

The Utilities began accepting energy from feed-in tariff projects in 2011. As of June 30, 2017, there were 30 MW, 3 MW and 4 MW of installed feed-in tariff capacity from renewable energy technologies at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.

As of June 30, 2017, there were approximately 325 MW, 75 MW and 86 MW of installed distributed renewable energy technologies (mainly PV) at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively, for tariff-based private customer generation programs, namely NEM, Customer Grid Supply and Customer Self Supply. As of June 30, 2017, an estimated 27% of single family homes on the islands the Utilities serve have installed private rooftop solar systems, and an estimated 29% of single family homes have installed, or have been approved to install, private rooftop solar systems. As of June 30, 2017, approximately 16% of the Utilities' total customers have solar systems.

On January 5, 2017, Hawaiian Electric issued an Onshore Wind Expression of Interest requesting expressions of interest from independent power producers that are capable of developing utility scale onshore wind projects that are eligible to capture the federal Investment Tax Credit for Large Wind on the island of Oahu. Responses have been accepted and are being evaluated.2019.

On January 6, 2017, Hawaii Electric Light and Maui Electric requested the PUC to open dockets to allow them to seek proposals for new renewable energy generation on the islands of Hawaii, Maui, Molokai, and Lanai.

On December 12, 2016, the Utilities issued a request for information asking interested landowners to provide information about properties on Oahu, Hawaii Island, Maui, Molokai and Lanai available for utility-scale renewable energy projects or for growing biofuel feedstock. Responses have been accepted and are being evaluated.

Hawaiian Electric had PPAs to purchase solar energy with three affiliates of SunEdison. In February 2016, as a result of the project entities missing contract milestones, Hawaiian Electric terminated the original PPAs for the three projects. SunEdison filed Chapter 11 bankruptcy proceedings and during those proceedings, the three SunEdison affiliates were acquired by an affiliate of NRG Energy, Inc. (NRG). Hawaiian Electric then negotiated with NRG and its newly acquired affiliates and has entered into amended and restated PPAs for solar energy on Oahu with Waipio PV, LLC for 45.9 MW, Lanikuhana Solar, LLC for 14.7 MW and Kawailoa Solar, LLC for 49.0 MW. On July 27, 2017, the PUC approved the three NRG PPAs, subject to modifications and conditions. The three projects are expected to be in service by the end of 2019.

~~Adequacy of supply.~~

~~Hawaiian Electric~~. In January 2017, Hawaiian Electric filed its 2017 Adequacy of Supply (AOS) letter, which indicated that based on its October 2016 sales and peak forecast for the 2017 - 2021 time period, Hawaiian Electric's generation capacity will be sufficient to meet reasonably expected demands for service and provide reasonable reserves for emergencies through 2018, but may have shortfalls in meeting the Utilities’ generating system reliability guideline. The calculated reliability guideline shortfalls are relatively small and Hawaiian Electric can implement mitigation measures.

In accordance to its planning criteria, Hawaiian Electric deactivated two fossil fuel generating units from active service at its Honolulu Power Plant in January 2014 and anticipates deactivating two additional fossil fuel units at its Waiau Power Plant in the 2022 timeframe. Hawaiian Electric acquired new firm capacity with the commissioning of the State of Hawaii Department of Transportation’s emergency power facility in June 2017. Hawaiian Electric is proceeding with a future firm capacity addition with the U.S. Department of the Army for a utility owned and operated renewable, dispatchable, including black start capabilities, generation security project on federal lands, which is expected to be in service in the second quarter of 2018. Hawaiian Electric is continuing negotiations with firm capacity IPPs on Oahu. 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 with AES Hawaii is scheduled to expire in 2022.

~~Hawaii Electric Light~~. In January 2017, Hawaii Electric Light filed its 2017 AOS letter, which indicated that Hawaii Electric Light’s generation capacity through 2019 is sufficient to meet reasonably expected demands for service and provide for reasonable reserves for emergencies. Additional generation from other renewable resources could be added in the 2018-2025 timeframe.

~~Maui Electric~~. In January 2017, Maui Electric filed its 2017 AOS letter, which indicated that Maui Electric’s generation capacity for the islands of Lanai and Molokai for the next three years is sufficiently large to meet all reasonably expected demands for service and provide reasonable reserves for emergencies. The 2017 AOS letter also indicated that without the peak reduction benefits of demand response but with the equivalent firm capacity value of wind generation, Maui Electric expects to have a small reserve capacity shortfall from 2017 to 2022 on the island of Maui. Maui Electric is evaluating several measures to mitigate the anticipated reserve capacity shortfall. Maui Electric anticipates needing a significant amount of additional firm capacity on Maui in the 2022 timeframe after the planned retirement of the Kahului Power Plant.

In February 2014, Maui Electric deactivated two fossil fuel generating units, with a combined rating of 11.4 MW-net, at its Kahului Power Plant. Due to various system conditions including lack of wind generation, approaching storms and scheduled and unscheduled outages of generating units, transmission lines and independent power producers, the two deactivated units at Kahului Power Plant were reactivated for several days in 2015 and 2016. Due to the frequency of reactivations of Kahului Units 1 and 2 to meet system requirements, these units were removed from deactivated status and designated as reactivated in September 2016. Considering the time needed to acquire replacement firm generating capacity, Maui Electric now anticipates the retirement of all generating units at the Kahului Power Plant, which have a combined rating of 32.3 MW, in the 2022 timeframe. A capacity planning analysis is in progress to better define generating needs and timing. Maui Electric plans to issue one or more RFPs for energy storage, demand response and firm generating capacity, and to make system improvements needed to ensure reliability and voltage support in this timeframe. In May 2016, Maui Electric requested that the PUC open a new docket for Maui Electric’s competitive bidding process for additional firm capacity resources. In September 2016, Maui Electric submitted an application to purchase and install three temporary mobile distributed generation diesel engines to address increasing reserve capacity shortfalls on the island of Maui, but in February 2017 Maui Electric requested the PUC to suspend the proceeding until the progress in the demand response programs and the DR portfolio proceeding can be further evaluated.

~~Legislation and regulation.~~ Congress and the Hawaii legislature periodically consider legislation that could have positive or negative effects on the Utilities and their customers. See “Recent tax developments” in Note 9 of the Condensed Consolidated Financial Statements. Also, in recent years, legislative, regulatory and governmental activities related to the environment, including proposals and rulemaking under the Clean Air Act and Clean Water Act (CWA), have increased significantly.

~~Clean Water Act Section 316(b)~~. On August 14, 2014, the EPA published in the Federal Register the final regulations required by section 316(b) of the CWA designed to protect aquatic organisms from adverse impacts associated with existing power plant cooling water intake structures. The regulations were effective October 14, 2014 and apply to the cooling water systems for the steam generating units at three of Hawaiian Electric’s power plants on the island of Oahu. The regulations prescribe a process, including a number of required site-specific studies, for states to develop facility-specific entrainment and impingement controls to be incorporated in each facility’s National Pollutant Discharge Elimination System permit. Hawaiian Electric submitted the final site specific studies for the Honolulu and Waiau power plants to the DOH in December 2016, and the final site specific study for Kahe will be submitted to the DOH no later than October 2017. Hawaiian Electric will work with the DOH to identify the appropriate compliance methods for the 316(b) rule.

~~Mercury Air Toxics Standards~~. On February 16, 2012, the EPA published the final rule establishing the National Emission Standards for Hazardous Air Pollutants for fossil-fuel fired steam electrical generating units (EGUs) in the Federal Register. The final rule, known as the Mercury and Air Toxics Standards (MATS), applies to the 14 EGUs at Hawaiian Electric’s power plants. MATS established the Maximum Achievable Control Technology standards for the control of hazardous air pollutants emissions from new and existing EGUs. Hawaiian Electric initially selected a MATS compliance strategy based on switching to lower emission fuels, but has since continued developing and refining its emission control strategy. Hawaiian Electric’s liquid oil-fired steam generating units that are subject to the MATS limits are able to comply with the new standards without a significant fuel switch in combination with a suite of operational changes.

~~Hawaiian Electric has proceeded with the implementation of its MATS Compliance Plan and has met all compliance requirements to date.~~

~~PUC Commissioner.~~ On May 19, 2017, the Governor appointed James Griffin as an interim PUC Commissioner, subject to Senate confirmation. Mr. Griffin was a researcher and a faculty member at the Hawaii Natural Energy Institute at the University of Hawaii at Manoa. He also previously served as Chief of Policy and Research at the PUC.

~~FINANCIAL CONDITION~~

~~Liquidity and capital resources.~~ Management believes that Hawaiian Electric’s ability, and that of its subsidiaries, to generate cash, both internally from operations and externally from issuances of equity and debt securities and commercial paper and draws on lines of credit, is adequate to maintain sufficient liquidity to fund their respective capital expenditures and investments and to cover debt, retirement benefits and other cash requirements in the foreseeable future.

~~Hawaiian Electric’s consolidated capital structure was as follows:~~

(dollars in millions) June 30, 2017 December 31, 2016
Short-term borrowings $ 44
1 % $ —
— %
Long-term debt, net 1,319
41
1,319
42
Preferred stock 34
1
34
1
Common stock equity 1,804
57
1,800
57
$ 3,201
100 % $ 3,153
100 %

~~Information about Hawaiian Electric’s short-term borrowings (other than from Hawaii Electric Light and Maui Electric) and Hawaiian Electric’s line of credit facility were as follows:~~

Average balance Balance
(in millions) Six months ended June 30, 2017 June 30, 2017 December 31, 2016
Short-term borrowings ¹

Commercial paper $ 3
$ 44
$ —
Line of credit draws —
—
—
Borrowings from HEI —
—
—
Undrawn capacity under line of credit facility 200
200

¹ The maximum amount of external short-term borrowings by Hawaiian Electric during the first six months of 2017 was $44 million. As of June 30, 2017, Hawaiian Electric had short-term borrowings from Hawaii Electric Light and Maui Electric of $4.1 million and $1.0 million, respectively. As of July 27, 2017, Hawaiian Electric had $33 million of outstanding commercial paper, no draws under its line of credit facility and no borrowings from HEI. Also, as of July 27, 2017, Hawaiian Electric had short-term borrowings from Hawaii Electric Light and Maui Electric of $6.6 million and $4.5 million, respectively, which intercompany borrowings are eliminated in consolidation.

~~Hawaiian Electric has a $200 million line of credit facility. See Note 5 of the Condensed Consolidated Financial Statements.~~

In May 2015, up to $80 million of SPRBs ($70 million for Hawaiian Electric, $2.5 million for Hawaii Electric Light and $7.5 million for Maui Electric) were authorized by the Hawaii legislature for issuance, with PUC approval, prior to June 30, 2020 to finance the Utilities’ capital improvement programs.

On April 28, 2017, Hawaiian Electric, Hawaii Electric Light and Maui Electric received PUC approval to issue unsecured obligations bearing taxable interest and/or refunding SPRBs with principal amounts totaling up to $252 million, $88 million and $75 million, respectively, to refinance three series of outstanding revenue bonds. The approval is limited to 2017, and an expedited approval procedure will apply for refinancings during January 2018 through December 2020. Pursuant to this approval, on June 29, 2017, the Department issued, at par, Refunding Series 2017A SPRBs in the aggregate principal amount of $125 million with a maturity of May 1, 2026 and Refunding Series 2017B SPRBs in the aggregate principal amount of $140 million with a maturity of March 1, 2037. See Note 5 of the Condensed Consolidated Financial Statements.

On January 26, 2017, Hawaiian Electric, Hawaii Electric Light and Maui Electric obtained PUC approval to issue, on or before December 31, 2017, unsecured obligations bearing taxable interest (Hawaiian Electric up to $100 million, Hawaii Electric Light up to $10 million and Maui Electric up to $30 million), with the proceeds expected to be used, as applicable, to finance capital expenditures, repay long-term and/or short term debt used to finance or refinance capital expenditures and/or to reimburse funds used for payment of capital expenditures.

In March 2017 and amended in April 2017, the Utilities requested PUC approval to issue and sell each utility’s common stock through December 31, 2021 (Hawaiian Electric’s sale/s to HEI of up to $150 million and Hawaii Electric Light’s and Maui Electric’s sale/s to Hawaiian Electric of up to $10 million each) and the purchase of Hawaii Electric Light and Maui Electric common stock by Hawaiian Electric through December 31, 2021.

~~Cash flows. The following table reflects the changes in cash flows for the six months ended June 30, 2017 compared to the six months ended June 30, 2016:~~

Six months ended June 30,
(in thousands) 2017 2016 Change
Net cash provided by operating activities $ 150,676
$ 194,124
$ (43,448 )
Net cash used in investing activities (178,259 ) (180,191 ) 1,932
Net cash used in financing activities (4,121 ) (10,803 ) 6,682

~~Net cash provided by operating activities.~~ Cash flows from operating activities generally relate to the amount and timing of cash received from customers and payments made to third parties. Using the indirect method of determining cash flows from operating activities, noncash expense items such as depreciation and amortization, as well as changes in certain assets and liabilities, are added to (or deducted from) net income.

~~The decrease in net cash provided by operating activities was impacted by the following:~~

~~Lower cash from an increase in accounts receivable due to timing and increase in fuel prices.~~

~~Lower cash from an increase in fuel oil stock due to higher fuel prices.~~

~~Lower cash from an increase in unbilled revenues due to higher fuel prices.~~

Lower cash from refund of federal income taxes based on bonus depreciation enacted in the fourth quarter of 2015 that was subsequently received in 2016 (similar treatment was not granted in the fourth quarter of 2016).

~~And partially offset by an increase in net cash from operating activities provided by the following:~~

~~Higher cash from an increase in accounts payable due to higher fuel prices.~~

~~Net cash used in investing activities.~~ ~~The increase in net cash used in investing activities was driven primarily by a capital goods tax credit, partially offset by an increase in capital expenditures related to construction activities.~~

~~Net cash used in financing activities.~~ Financing activities provide supplemental cash for both day-to-day operations and capital requirements as needed. The decrease in net cash used in financing activities primarily reflect higher proceeds from short-term borrowings.

~~2017 forecast capital expenditures~~. For 2017, the Utilities forecast $420 million of net capital expenditures, which could change over time based upon external factors such as the timing and scope of environmental regulations, unforeseen delays in permitting and timing of PUC decisions. Proceeds from the issuance of equity and long-term debt, cash flows from operating activities, temporary increases in short-term borrowings and existing cash and cash equivalents are expected to provide the forecasted $420 million needed for the net capital expenditures in 2017 as well as to pay down commercial paper or other short-term borrowings, fund any unanticipated expenditures not included in the 2017 forecast such as increases in the costs or acceleration of the construction of capital projects, unanticipated capital expenditures that may be required by new environmental laws and regulations, unbudgeted acquisitions or investments in new businesses and significant increases in retirement benefit funding requirements.

~~Bank~~

Three months ended June 30 Increase
(in millions) 2017 2016 (decrease) Primary reason(s)
Interest income $ 59
$ 54
$ 5
The increase in interest income was the result of higher average earning asset balances and an increase in yields on earning assets. ASB’s average loan portfolio balance for the three months ended June 30, 2017 increased by $24 million compared to the same period in 2016 as average consumer, commercial real estate and home equity lines of credit balances increased by $60 million, $50 million and $21 million, respectively. The growth in these loan portfolios was reflective of ASB’s portfolio mix target and loan growth strategy. The average commercial loan balance decreased by $99 million primarily due to a decrease in the syndicated national credit loan portfolio. The yield on earning assets increased by 7 basis points due to a shift in the mix of the loan portfolio with the growth in the commercial real estate and consumer loan portfolios, which resulted in an increase in loan portfolio yields of 19 basis points and repricing of adjustable rate commercial loans with the increase in the interest rate environment. The average investment securities portfolio balance increased by $389 million due to the use of excess liquidity to purchase investments. The yield on the investment securities portfolio increased by 14 basis points as new investment purchase yields were higher due to the increase in short-term interest rates.
Noninterest income 16
17
(1 ) Noninterest income decreased slightly for the three months ended June 30, 2017 compared to noninterest income for the three months ended June 30, 2016 due to lower mortgage banking income partly offset by higher bank owned life insurance income. Prior year’s noninterest income included gains on sales of securities with no similar sales in 2017.
Revenues 75
71
4

Interest expense 3
3
—
Interest expense was flat for the three months ended June 30, 2017 compared to the same period in 2016 as higher interest expense from the growth in term certificates was offset by lower interest expense on other borrowings as a result of lower repurchase agreements. Average deposit balances for the three months ended June 30, 2017 increased by $487 million compared to the same period in 2016 due to an increase in core deposits and term certificates of $327 million and $160 million, respectively. Other borrowings decreased by $84 million primarily due to a decrease in repurchase agreements. The interest-bearing liability rate decreased by 2 basis points.
Provision for loan losses 3
5
(2 ) The provision for loan losses decreased by $1.9 million for the three months ended June 30, 2017 compared to the provision for loan losses for the three months ended June 30, 2016. The provision for loan losses for 2017 was primarily due to increased loan loss reserves for the consumer loan portfolio. The provision for loan losses for 2016 was primarily due to increased reserves for growth in the loan portfolio, additional loan loss reserves for the consumer loan portfolio and loan loss reserves for commercial loans due to downgrades of specific commercial credits. Delinquency rates have decreased from 0.49% at June 30, 2016 to 0.44% at June 30, 2017. The annualized net charge-off ratio for the three months ended June 30, 2017 was 0.21% compared to an annualized net charge-off ratio of 0.15% for the same period in 2016. The increase in net charge-offs were due to an increase in consumer loan portfolio charge-offs as a result of ASB’s strategic expansion of its unsecured consumer loan product offering with risk-based pricing.
Noninterest expense 45
43
2
The increase in noninterest expense for the three months ended June 30, 2017 compared to the same period in 2016 was primarily due to higher compensation and employee benefits expenses as a result of higher performance-based compensation costs and higher employee benefit costs. Prior year’s noninterest expense included costs related to the replacement and upgrade of the electronic banking platform.
Expenses 51
51
—

Operating income 24
20
4
Higher net interest income and lower provision for loan losses was partly offset by higher noninterest expenses and lower noninterest income.
Net income 17
13
4

Six months ended June 30 Increase
(in millions) 2017 2016 (decrease) Primary reason(s)
Interest income $ 117
$ 108
$ 9
The increase in interest income was the result of higher average earning asset balances and an increase in yields on earning assets. ASB’s average loan portfolio balance for the six months ended June 30, 2017 increased by $60 million compared to the same period in 2016 as average commercial real estate, consumer and home equity lines of credit balances increased by $76 million, $60 million and $19 million, respectively. The growth in these loan portfolios was reflective of ASB’s portfolio mix target and loan growth strategy. The average commercial loan balance decreased by $89 million primarily due to a decrease in the syndicated national credit loan portfolio. The yield on earning assets increased by 6 basis points due to a shift in the mix of the loan portfolio with the growth in the commercial real estate and consumer loan portfolios, which resulted in an increase in loan portfolio yields of 16 basis points and repricing of adjustable rate commercial loans with the increase in the interest rate environment. The average investment securities portfolio balance increased by $347 million due to the use of excess liquidity to purchase investments. The yield on the investment securities portfolio increased by 10 basis points as new investment purchase yields were higher due to the increase in short-term interest rates.
Noninterest income 31
32
(1 ) Noninterest income decreased slightly for the six months ended June 30, 2017 compared to noninterest income for the six months ended June 30, 2016 due to lower mortgage banking income partly offset by higher bank-owned life insurance income.
Revenues 148
140
8

Interest expense 6
6
—
Interest expense was flat for the six months ended June 30, 2017 compared to the same period in 2016 as higher interest expense from the growth in term certificates was offset by lower interest expense on other borrowings as a result of lower repurchase agreements. Average deposit balances for the six months ended June 30, 2017 increased by $511 million compared to the same period in 2016 due to an increase in core deposits and term certificates of $350 million and $161 million, respectively. Other borrowings decreased by $100 million primarily due to a decrease in repurchase agreements. The interest-bearing liability rate decreased by 3 basis points.
Provision for loan losses 7
10
(3 ) The provision for loan losses decreased by $2.8 million for the six months ended June 30, 2017 compared to the provision for loan losses for the six months ended June 30, 2016. The provision for loan losses for 2017 was primarily due to increased loan loss reserves for the consumer loan portfolio and additional loan loss reserves for the commercial real estate loan portfolio due to the downgrade of a commercial real estate relationship. The provision for loan losses for 2016 was primarily due to increased reserves for growth in the loan portfolio, additional loan loss reserves for the consumer loan portfolio and loan loss reserves for commercial loans due to downgrades of specific commercial credits. Delinquency rates have decreased from 0.49% at June 30, 2016 to 0.44% at June 30, 2017. The annualized net charge-off ratio for the six months ended June 30, 2017 was 0.25% compared to an annualized net charge-off ratio of 0.18% for the same period in 2016. The increase in net charge-offs were due to an increase in consumer loan portfolio charge-offs as a result of ASB’s strategic expansion of its unsecured consumer loan product offering with risk-based pricing.
Noninterest expense 86
84
2
The increase in noninterest expense for the six months ended June 30, 2017 compared to the same period in 2016 was primarily due to higher compensation and employee benefits expenses as a result of higher performance-based compensation costs and higher employee benefit costs. Prior year’s noninterest expense included costs related to the replacement and upgrade of the electronic banking platform.
Expenses 99
100
(1 )
Operating income 49
40
9
Higher net interest income and lower provision for loan losses was partly offset by higher noninterest expenses and lower noninterest income.
Net income 33
26
7

~~See Note 4 of the Condensed Consolidated Financial Statements and “Economic conditions” in the “HEI Consolidated” section above.~~

~~ASB continues to maintain its low-risk profile, strong balance sheet and straightforward community banking business model.~~

~~ASB’s return on average assets, return on average equity and net interest margin were as follows:~~

Three months ended June 30 Six months ended June 30
(percent) 2017 2016 2017 2016
Return on average assets 1.02
0.86
1.00
0.85
Return on average equity 11.25
9.22
11.04
9.06
Net interest margin 3.68
3.58
3.68
3.60

~~Average balance sheet and net interest margin.~~ ~~The following tables provide a summary of average balances including major categories of interest-earning assets and interest-bearing liabilities:~~

Three months ended June 30
2017 2016
(dollars in thousands) Average
balance
Interest¹
income/
expense
Yield/
rate (%) Average
balance
Interest¹income/
expense
Yield/
rate (%)
Assets:

Interest-earning deposits $ 46,507
$ 121
1.03
$ 64,821
$ 81
0.49
FHLB stock 11,759
57
1.96
11,284
44
1.58
Available-for-sale investment securities
Taxable 1,267,945
6,481
2.04
894,684
4,318
1.93
Non-taxable 15,427
160
4.11
—
—
—
Total available-for-sale investment securities 1,283,372
6,641
2.07
894,684
4,318
1.93
Loans
Residential 1-4 family 2,070,450
22,163
4.28
2,075,255
22,201
4.28
Commercial real estate 917,019
9,722
4.21
867,266
8,716
4.01
Home equity line of credit 877,462
7,248
3.31
856,960
6,989
3.28
Residential land 16,111
217
5.38
18,758
285
6.08
Commercial 663,200
7,090
4.27
762,247
7,595
3.99
Consumer 202,914
5,877
11.62
142,955
3,904
10.98
Total loans ^2,3
4,747,156
52,317
4.40
4,723,441
49,690
4.21
Total interest-earning assets ²
6,088,794
59,136
3.88
5,694,230
54,133
3.81
Allowance for loan losses (56,715 )

(52,749 )

Non-interest-earning assets 534,581

503,617

Total assets $ 6,566,660

$ 6,145,098

Liabilities and shareholder’s equity:

Savings $ 2,274,832
$ 386
0.07
$ 2,099,422
$ 343
0.07
Interest-bearing checking 908,864
59
0.03
834,821
42
0.02
Money market 146,962
45
0.12
165,433
52
0.13
Time certificates 679,866
1,821
1.07
520,151
1,254
0.97
Total interest-bearing deposits 4,010,524
2,311
0.23
3,619,827
1,691
0.19
Advances from Federal Home Loan Bank 101,335
788
3.08
101,648
785
3.06
Securities sold under agreements to repurchase 95,740
36
0.15
179,559
682
1.51
Total interest-bearing liabilities 4,207,599
3,135
0.30
3,901,034
3,158
0.32
Non-interest bearing liabilities:

Deposits 1,664,592

1,568,725

Other 99,710

98,678

Shareholder’s equity 594,759

576,661

Total liabilities and shareholder’s equity $ 6,566,660

$ 6,145,098

Net interest income
$ 56,001

$ 50,975

Net interest margin (%) ⁴

3.68

3.58

Six months ended June 30
2017 2016
(dollars in thousands) Average
balance
Interest¹
income/
expense
Yield/
rate (%) Average
balance
Interest¹income/
expense
Yield/
rate (%)
Assets:

Interest-earning deposits $ 69,421
$ 307
0.88
$ 72,070
$ 180
0.49
FHLB stock 11,498
105
1.85
11,031
88
1.61
Available-for-sale investment securities
Taxable 1,206,272
13,130
2.18
874,542
9,192
2.10
Non-taxable 15,427
310
4.00
—
—
—
Total available-for-sale investment securities 1,221,699
13,440
2.20
874,542
9,192
2.10
Loans
Residential 1-4 family 2,071,931
43,789
4.23
2,075,890
44,521
4.29
Commercial real estate 913,940
19,134
4.18
837,837
16,880
4.02
Home equity line of credit 872,973
14,364
3.32
854,145
13,854
3.26
Residential land 17,057
495
5.80
18,482
561
6.07
Commercial 666,741
14,245
4.30
755,510
14,967
3.96
Consumer 195,158
11,032
11.40
135,572
7,344
10.89
Total loans ^2,3
4,737,800
103,059
4.36
4,677,436
98,127
4.20
Total interest-earning assets ²
6,040,418
116,911
3.88
5,635,079
107,587
3.82
Allowance for loan losses (56,477 )

(51,599 )

Non-interest-earning assets 527,302

500,412

Total assets $ 6,511,243

$ 6,083,892

Liabilities and shareholder’s equity:

Savings $ 2,261,549
$ 760
0.07
$ 2,073,790
$ 676
0.07
Interest-bearing checking 897,346
114
0.03
828,345
84
0.02
Money market 151,293
92
0.12
166,338
105
0.13
Time certificates 670,717
3,448
1.04
509,884
2,418
0.95
Total interest-bearing deposits 3,980,905
4,414
0.22
3,578,357
3,283
0.18
Advances from Federal Home Loan Bank 100,671
1,563
3.09
101,854
1,571
3.05
Securities sold under agreements to repurchase 94,713
77
0.16
193,296
1,381
1.42
Total interest-bearing liabilities 4,176,289
6,054
0.29
3,873,507
6,235
0.32
Non-interest bearing liabilities:

Deposits 1,646,275

1,537,660

Other 98,875

99,427

Shareholder’s equity 589,804

573,298

Total liabilities and shareholder’s equity $ 6,511,243

$ 6,083,892

Net interest income
$ 110,857

$ 101,352

Net interest margin (%) ⁴

3.68

3.60


¹	Interest income includes taxable equivalent basis adjustments, based upon a federal statutory tax rate of 35%, of $0.06 million and nil for the three months ended June 30, 2017 and 2016, respectively and $0.1 million and nil for the six months ended June 30, 2017 and 2016, respectively.

²~~Includes loans held for sale, at lower of cost or fair value.~~


³	Includes recognition of deferred loan fees of $0.6 million and $0.7 million for the three months ended June 30, 2017 and 2016 and $1.1 million and $1.5 million for the six months ended June 30, 2017 and 2016, respectively, together with interest accrued prior to suspension of interest accrual on nonaccrual loans.


⁴	~~Defined as net interest income as a percentage of average total interest-earning assets.~~

~~Earning assets, costing liabilities and other factors.~~ Earnings of ASB depend primarily on net interest income, which is the difference between interest earned on earning assets and interest paid on costing liabilities. The interest rate environment has been impacted by disruptions in the financial markets over a period of several years. These conditions have begun to moderate with the interest rate increases in the past year which resulted in an increase in ASB’s net interest income and net interest margin.

~~Loan originations and mortgage-related securities are ASB’s primary earning assets.~~

~~Loan portfolio~~. ASB’s loan volumes and yields are affected by market interest rates, competition, demand for financing, availability of funds and management’s responses to these factors. The composition of ASB’s loans receivable was as follows:

June 30, 2017 December 31, 2016
(dollars in thousands) Balance % of total Balance % of total
Real estate:

Residential 1-4 family $ 2,061,549
43.4
$ 2,048,051
43.2
Commercial real estate 808,900
17.1
800,395
16.9
Home equity line of credit 883,135
18.6
863,163
18.2
Residential land 16,009
0.3
18,889
0.4
Commercial construction 116,548
2.5
126,768
2.7
Residential construction 10,759
0.2
16,080
0.3
Total real estate, net 3,896,900
82.1
3,873,346
81.7
Commercial 649,657
13.7
692,051
14.6
Consumer 201,199
4.2
178,222
3.7
4,747,756
100.0
4,743,619
100.0
Less: Deferred fees and discounts (3,122 )
(4,926 )
Allowance for loan losses (56,356 )
(55,533 )
Total loans, net $ 4,688,278

$ 4,683,160

~~Home equity— key credit statistics~~. Attention has been given by regulators and rating agencies to the potential for increased exposure to credit losses associated with home equity lines of credit (HELOC) that were originated during the period of rapid home price appreciation between 2003 and 2007 as they have reached, or are starting to reach, the end of their 10-year, interest only payment periods. Once the interest only payment period has ended, payments are reset to include principal repayments along with interest. ASB does not have a large exposure to HELOCs originated between 2003 and 2007. Nearly all of the HELOC originations prior to 2008 consisted of amortizing equity lines that have structured principal payments during the draw period. These older equity lines represent 2% of the portfolio and are included in the amortizing balances identified in the loan portfolio table below.

June 30, 2017 December 31, 2016
Outstanding balance of home equity loans (in thousands) $ 883,135
$ 863,163
Percent of portfolio in first lien position 46.2 % 45.1 %
Annualized net charge-off (recovery) ratio (0.03 )% 0.01 %
Delinquency ratio 0.28 % 0.35 %

End of draw period – interest only Current
June 30, 2017 Total Interest only 2017-2018 2019-2021 Thereafter amortizing
Outstanding balance (in thousands) $ 883,135
$ 701,709
$ 62,453
$ 101,546
$ 537,710
$ 181,426
% of total 100 % 79 % 7 % 11 % 61 % 21 %

The HELOC portfolio comprised 19% of the total loan portfolio and is generally an interest-only revolving loan for a 10-year period, after which time the HELOC outstanding balance converts to a fully amortizing variable rate term loan with a 20-year amortization period. This product type comprises 79% of the total HELOC portfolio and is the current product offering. Borrowers also have a “Fixed Rate Loan Option” to convert a part of their available line of credit into a 5, 7 or 10-year fully amortizing fixed rate loan with level principal and interest payments. As of ~~June 30, 2017, approximately 19% of the portfolio balances were amortizing loans under the Fixed Rate Loan Option.~~

~~Loan portfolio risk elements~~. ~~See Note 4 of the Condensed Consolidated Financial Statements.~~

~~Available-for-sale investment securities~~. ~~ASB’s investment portfolio was comprised as follows:~~

June 30, 2017 December 31, 2016
(dollars in thousands) Balance % of total Balance % of total
U.S. Treasury and federal agency obligations $ 186,583
14 % $ 192,281
18 %
Mortgage-related securities — FNMA, FHLMC and GNMA 1,100,876
85
897,474
81
Mortgage revenue bond 15,427
1
15,427
1
Total available-for-sale investment securities $ 1,302,886
100 % $ 1,105,182
100 %

Principal and interest on mortgage-related securities issued by Federal National Mortgage Association (FNMA), Federal Home Loan Mortgage Corporation (FHLMC) and Government National Mortgage Association (GNMA) are guaranteed by the issuer and, in the case of GNMA, backed by the full faith and credit of the U.S. government.

~~Deposits and other borrowings~~. Deposits continue to be the largest source of funds for ASB and are affected by market interest rates, competition and management’s responses to these factors. Deposit retention and growth will remain challenging in the current environment due to competition for deposits and the low level of short-term interest rates. Advances from the FHLB of Des Moines and securities sold under agreements to repurchase continue to be additional sources of funds. As of ~~June 30, 2017~~ ~~and December 31, 2016, ASB’s costing liabilities consisted of 97% deposits and 3% other borrowings. The weighted average cost of deposits for the first~~ ~~six~~ ~~months of 2017 and 2016 was 0.16% and 0.13%, respectively.~~

~~Federal Home Loan Bank of Des Moines~~. As of June 30, 2017 and December 31, 2016, ASB had $100 million of advances outstanding at the FHLB of Des Moines. As of June 30, 2017, the unused borrowing capacity with the FHLB of Des Moines was $1.8 billion. The FHLB of Des Moines will continue to be a source of liquidity for ASB.

~~Other factors~~. Interest rate risk is a significant risk of ASB’s operations and also represents a market risk factor affecting the fair value of ASB’s investment securities. Increases and decreases in prevailing interest rates generally translate into decreases and increases in the fair value of the investment securities, respectively. In addition, changes in credit spreads also impact the fair values of the investment securities.

~~As of~~ ~~June 30, 2017~~, ASB had an unrealized loss, net of taxes, on available-for-sale investment securities (including securities pledged for repurchase agreements) in AOCI of $5.7 million compared to an unrealized loss, net of taxes, of $7.9 million at December 31, 2016. See “Item 3. Quantitative and qualitative disclosures about market risk” for a discussion of ASB’s interest rate risk sensitivity.

During the first six months of 2017, ASB recorded a provision for loan losses of $6.7 million primarily due to increased loan loss reserves for the consumer loan portfolio and additional loan loss reserves for the commercial real estate loan portfolio due to the downgrade of a commercial real estate relationship. During the first ~~six~~ months of 2016, ASB recorded a provision for loan losses of $9.5 million primarily due to increased reserves for growth in the loan portfolio, additional loan loss reserves for the consumer loan portfolio and loan loss reserves for commercial loans due to downgrades of specific commercial credits. Financial stress on ASB’s customers may result in higher levels of delinquencies and losses.

Six months ended June 30
Year ended
December 31,
(in thousands) 2017 2016 2016
Allowance for loan losses, January 1 $ 55,533
$ 50,038
$ 50,038
Provision for loan losses 6,741
9,519
16,763
Less: net charge-offs 5,918
4,226
11,268
Allowance for loan losses, end of period $ 56,356
$ 55,331
$ 55,533
Ratio of net charge-offs during the period to average loans outstanding (annualized) 0.25 % 0.18 % 0.24 %

We maintain a reserve for credit losses that consists of two components, the allowance for loan losses and a reserve for unfunded loan commitments (unfunded reserve). The level of the reserve for unfunded loan commitments is adjusted by recording an expense or recovery in other noninterest expense. As of June 30, 2017 and December 31, 2016, the reserve for unfunded loan commitments was $1.7 million and $1.8 million, respectively.

~~Legislation and regulation.~~ ASB is subject to extensive regulation, principally by the OCC and the FDIC. Depending on ASB’s level of regulatory capital and other considerations, these regulations could restrict the ability of ASB to compete with other institutions and to pay dividends to its shareholder. See the discussion below under “Liquidity and capital resources.”

~~Dodd-Frank Wall Street Reform and Consumer Protection Act (Dodd-Frank Act)~~. Regulation of the financial services industry, including regulation of HEI, ASB Hawaii and ASB, has changed and will continue to change as a result of the enactment of the Dodd-Frank Act, which became law in July 2010. Importantly for HEI, ASB Hawaii and ASB, under the Dodd-Frank Act all of the functions of the Office of Thrift Supervision transferred on July 21, 2011 to the OCC, the FDIC, the FRB and the Consumer Financial Protection Bureau (Bureau). Supervision and regulation of HEI and ASB Hawaii, as thrift holding companies, moved to the FRB, and supervision and regulation of ASB, as a federally chartered savings bank, moved to the OCC. While the laws and regulations applicable to HEI and ASB did not generally change, the applicable laws and regulations are being interpreted, and new and amended regulations may be adopted, by the FRB, the OCC and the Bureau. In addition, HEI will continue to be required to serve as a source of strength to ASB in the event of its financial distress. The Dodd-Frank Act also imposed new restrictions on the ability of a savings bank to pay dividends should it fail to remain a qualified thrift lender.

More stringent affiliate transaction rules now apply to ASB in the securities lending, repurchase agreement and derivatives areas. Standards were raised with respect to the ability of ASB to merge with or acquire another institution. In reviewing a potential merger or acquisition, the approving federal agency will need to consider the extent to which the proposed transaction will result in “greater or more concentrated risks to the stability of the U.S. banking or financial system.”

The Dodd-Frank Act established the Bureau. It has authority to prohibit practices it finds to be unfair, deceptive or abusive, and it may also issue rules requiring specified disclosures and the use of new model forms. On January 10, 2013, the Bureau issued the Ability-to-Repay rule which closed for comment on February 25, 2013. For mortgages, among other things, (i) potential borrowers have to supply financial information, and lenders must verify it, (ii) to qualify for a particular loan, a consumer has to have sufficient assets or income to pay back the loan and (iii) lenders have to determine the consumer’s ability to repay both the principal and the interest over the long term - not just during an introductory period when the rate may be lower.

ASB may also be subject to new state regulation because of a provision in the Dodd-Frank Act that acknowledges that a federal savings bank may be subject to state regulation and allows federal law to preempt a state consumer financial law on a “case by case” basis only when (1) the state law would have a discriminatory effect on the bank compared to that on a bank chartered in that state, (2) the state law prevents or significantly interferes with a bank’s exercise of its power or (3) the state law is preempted by another federal law.

The Dodd-Frank Act also adopts a number of provisions that impact the mortgage industry, including the imposition of new specific duties on the part of mortgage originators (such as ASB) to act in the best interests of consumers and to take steps to ensure that consumers will have the capability to repay loans they may obtain, as well as provisions imposing new disclosure requirements and requiring appraisal reforms.

Also, the Dodd-Frank Act directs the Bureau to publish rules and forms that combine certain disclosures that consumers receive in connection with applying for and closing on a mortgage loan under the Truth in Lending Act and the Real Estate Settlement Procedures Act. Consistent with this requirement, the Bureau amended Regulation X (Real Estate Settlement Procedures Act) and Regulation Z (Truth in Lending) to establish new disclosure requirements and forms in Regulation Z for most closed-end consumer credit transactions secured by real property. In addition to combining the existing disclosure requirements and implementing new requirements, the final rule provides extensive guidance regarding compliance with those requirements. This rule was effective October 3, 2015.

The “Durbin Amendment” to the Dodd-Frank Act required the FRB to issue rules to ensure that debit card interchange fees are “reasonable and proportional” to the processing costs incurred. In June 2011, the FRB issued a final rule establishing standards for debit card interchange fees and prohibiting network exclusivity arrangements and routing restrictions. Under the final rule, effective October 1, 2011, the maximum permissible interchange fee that an issuer may receive for an electronic debit transaction is 21-24 cents, depending on certain components. Financial institutions and their affiliates that have less than $10 billion in assets are exempt from this Amendment; however, on July 1, 2013, ASB became non-exempt as the consolidated assets of HEI exceeded $10 billion. The debit card interchange fees received by ASB have been lower as a result of the application of this Amendment.

~~Final Capital Rules~~. On July 2, 2013, the FRB finalized its rule implementing the Basel III regulatory capital framework. The final rule would apply to banking organizations of all sizes and types regulated by the FRB and the OCC, except bank holding companies subject to the FRB’s Small Bank Holding Company Policy Statement and Savings & Loan Holding Companies (SLHCs) substantially engaged in insurance underwriting or commercial activities. HEI currently meets the requirements of the exemption as a top-tier grandfathered unitary SLHC that derived, as of June 30 of the previous calendar year, either 50% or more of its total consolidated assets or 50% or more of its total revenues on an enterprise-wide basis (calculated under GAAP) from activities that are not financial in nature pursuant to Section 4(k) of the Bank Holding Company Act. The FRB is temporarily excluding these SLHCs from the final rule while it considers a proposal relating to capital and other requirements for SLHC intermediate holding companies (such as ASB Hawaii). The FRB indicated that it would release a proposal on intermediate holding companies that would specify the criteria for establishing and transferring activities to intermediate holding

companies and propose to apply the FRB’s capital requirements to such intermediate holding companies. The FRB has not yet issued such a proposal, or a proposal on how to apply the Basel III capital rules to SLHCs that are substantially engaged in commercial or insurance underwriting activities, such as grandfathered unitary SLHCs like HEI.

Pursuant to the final rule and consistent with the proposals, all banking organizations, including covered holding companies, would initially be subject to the following minimum regulatory capital requirements: a common equity Tier 1 capital ratio of 4.5%, a Tier 1 capital ratio of 6%, a total capital ratio of 8% of risk-weighted assets and a tier 1 leverage ratio of 4%, and these requirements would increase in subsequent years. In order to avoid restrictions on capital distributions and discretionary bonus payments to executive officers, the final rule requires a banking organization to hold a buffer of common equity tier 1 capital above its minimum capital requirements in an amount greater than 2.5% of total risk-weighted assets (capital conservation buffer). In addition, a countercyclical capital buffer would expand the capital conservation buffer by up to 2.5% of a banking organization’s total risk-weighted assets for advanced approaches banking organizations. The final rule would establish qualification criteria for common equity, additional tier 1 and tier 2 capital instruments that help to ensure their ability to absorb losses. All banking organizations would be required to calculate risk-weighted assets under the standardized approach, which harmonizes the banking agencies’ calculation of risk-weighted assets and address shortcomings in capital requirements identified by the agencies. The phased-in effective dates of the capital requirements under the final rule are:

~~Minimum Capital Requirements~~

Effective dates 1/1/2015 1/1/2016 1/1/2017 1/1/2018 1/1/2019
Capital conservation buffer
0.625 % 1.25 % 1.875 % 2.50 %
Common equity Tier-1 ratio + conservation buffer 4.50 % 5.125 % 5.75 % 6.375 % 7.00 %
Tier-1 capital ratio + conservation buffer 6.00 % 6.625 % 7.25 % 7.875 % 8.50 %
Total capital ratio + conservation buffer 8.00 % 8.625 % 9.25 % 9.875 % 10.50 %
Tier-1 leverage ratio 4.00 % 4.00 % 4.00 % 4.00 % 4.00 %
Countercyclical capital buffer — not applicable to ASB
0.625 % 1.25 % 1.875 % 2.50 %

~~The final rule was effective January 1, 2015 for ASB. As of~~ ~~June 30, 2017, ASB met the new capital requirements with a Common equity Tier-1 ratio of 12.4%, a Tier-1 capital ratio of 12.4%, a Total capital ratio of 13.7% and a Tier-1 leverage ratio of 8.5%.~~

Subject to the timing and final outcome of the FRB’s SLHC intermediate holding company proposal, HEI anticipates that the capital requirements in the final rule will eventually be effective for HEI or ASB Hawaii as well. If the fully phased-in capital requirements were currently applicable to HEI, management believes HEI would satisfy the capital requirements, including the fully phased-in capital conservation buffer. Management cannot predict what final rule the FRB may adopt concerning intermediate holding companies or their impact on ASB Hawaii, if any.

~~Military Lending Act.~~ The Department of Defense (DOD) amended its regulation that implements the Military Lending Act (MLA), which became effective on October 3, 2016. The DOD amended its regulation primarily for the purpose of extending the protections of the MLA to a broader range of closed-end and open-end credit products. It initially applied to three narrowly-defined “consumer credit” products: closed-end payday loans; closed-end auto title loans; and closed-end tax refund anticipation loans. The DOD revised the scope of the definition of ‘‘consumer credit’’ to be generally consistent with the credit products that have been subject to the requirements of the Regulation Z, namely: credit offered or extended to a covered borrower primarily for personal, family or household purposes and that is (i) subject to a finance charge or (ii) payable by a written agreement in more than four installments.

Additionally, the DOD elected to exercise its discretion by generally requiring any fees for credit insurance products or for credit-related ancillary products to be included in the Military Annual Percentage Rate. The DOD also modified the disclosures that a creditor must provide to a covered borrower and implemented the enforcement provisions of the MLA. ASB has modified certain products, practices and associated training to conform to these changes.

~~Overtime Rules.~~ The Secretary of Labor updated the overtime regulations of the Fair Labor Standards Act to simplify and modernize them. The Department of Labor issued final rules that will raise the salary threshold indicating eligibility from $455/week to $913/week ($47,476 per year), and update automatically the salary threshold every three years, based on wage growth over time, increasing predictability. The final rule was to become effective on December 1, 2016. In late-November 2016 however, the U.S. District Court in the Eastern District of Texas granted a nationwide preliminary injunction that blocked the final rule, saying the Department of Labor's rule exceeds the authority the agency was delegated by Congress. Despite this block, ASB modified its salaries in the fourth quarter of 2016 such that it is in voluntary compliance with the final rule.

~~Arbitration Agreements.~~ Pursuant to section 1028(b) of the Dodd-Frank Act, on July 19, 2017, the Bureau issued a final rule to regulate arbitration agreements in contracts for specified consumer financial product and services. First, the final rule prohibits

covered providers of certain consumer financial products and services from using an agreement with a consumer that provides for arbitration of any future dispute between the parties to bar the consumer from filing or participating in a class action concerning the covered consumer financial product or service. Second, the final rule requires covered providers that are involved in arbitration pursuant to a pre-dispute arbitration agreement to submit specified arbitral records to the Bureau and also to submit specified court records. ~~This regulation is effective September 18, 2017.~~ ~~ASB is currently evaluating the impact of this final rule on its affected agreements.~~

FINANCIAL CONDITION

Liquidity and capital resources. As a result of the Tax Cut and Jobs Act, utility property is no longer eligible for bonus depreciation, but further guidance is required in order to finally determine the timing of the application of the new law. However, note that recent clarification in the tax law indicates that certain assets with longer construction periods that were placed in service after the effective date may be grandfathered and qualify for the old 50% bonus depreciation if subject to binding contracts entered into before such effective date. The Utilities are currently evaluating its larger projects placed into service after September 27, 2017 for applicability. Nevertheless, the initial cash requirement for future utility capital projects will generally increase because of the loss of the immediate tax benefit from bonus depreciation. The Company believes that its ability to generate cash, both internally from electric utility and banking operations and externally from issuances of equity and debt securities, commercial paper and bank borrowings, is adequate to maintain sufficient liquidity to fund its contractual obligations and commercial commitments, its forecasted capital expenditures and investments, its expected retirement benefit plan contributions and other cash requirements for the foreseeable future.

The consolidated capital structure of HEI (excluding deposit liabilities and other bank borrowings) was as follows:



(dollars in millions)	June 30, 2018				December 31, 2017
Short-term borrowings—other than bank	$	203	5	%	$	118	3	%
Long-term debt, net—other than bank	1,783		43		1,684		43
Preferred stock of subsidiaries	34		1		34		1
Common stock equity	2,103		51		2,097		53
	$	4,123	100	%	$	3,933	100	%

HEI’s commercial paper borrowings and line of credit facility were as follows:



	Average balance		Balance
(in millions)	Six months ended June 30, 2018		June 30, 2018		December 31, 2017
Commercial paper	$	49	$	61	$	63
Line of credit draws	—		—		—
Undrawn capacity under HEI’s line of credit facility			150		150

Note: This table does not include Hawaiian Electric’s separate commercial paper issuances and line of credit facilities and draws, which are disclosed below under “Electric utility—Financial Condition—Liquidity and capital resources.” The maximum amount of HEI’s external short-term borrowings during the first six months of 2018 was $68 million.

HEI has a $150 million line of credit facility with no amounts outstanding at June 30, 2018. See Note 5 of the Condensed Consolidated Financial Statements.

The Company has the ability to satisfy the share purchase requirements for the HEI Dividend Reinvestment and Stock Purchase Plan (DRIP), HEIRSP and ASB 401(k) Plan either through the issuance of new shares, which provides new capital, or through open market purchases of its common stock. From December 7, 2016 to date, HEI satisfied the share purchase requirements for these plans through open market purchases of its common stock rather than through new issuances.

For the first six months of 2018, net cash provided by operating activities of HEI consolidated was $108 million. Net cash used by investing activities for the same period was $391 million, primarily due to Hawaiian Electric’s consolidated capital expenditures and ASB’s net increase in loans held for investment and purchases of investment securities, partly offset by ASB’s receipt of repayments from investment securities and Hawaiian Electric’s receipt of contributions in aid of construction. Net cash provided by financing activities during this period was $276 million as a result of several factors, including increases in short-term borrowings and ASB’s deposit liabilities, proceeds from other bank borrowings and long-term debt and net increases in ASB’s retail purchase agreements, partly offset by the payment of common stock dividends and repayments of other bank borrowings. Other than capital contributions from their parent company, intercompany services (and related intercompany payables and receivables), Hawaiian Electric’s periodic short-term borrowings from HEI (and related interest) and the payment of dividends to HEI, the electric utility and bank segments are largely autonomous in their operating, investing and financing activities. (See the electric utility and bank segments’ discussions of their cash flows in their respective “Financial condition—Liquidity and capital resources” sections below.) During the first six months of 2018, Hawaiian Electric and ASB (through ASB Hawaii) paid cash dividends to HEI of $52 million and $22 million, respectively.

CERTAIN FACTORS THAT MAY AFFECT FUTURE RESULTS AND FINANCIAL CONDITION

The Company’s results of operations and financial condition can be affected by numerous factors, many of which are beyond the Company’s control and could cause future results of operations to differ materially from historical results. For information about certain of these factors, see pages 49, 63 to 65, and 75 to 77 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2017 Form 10-K.

Additional factors that may affect future results and financial condition are described on pages iv and v under “Cautionary Note Regarding Forward-Looking Statements.”

MATERIAL ESTIMATES AND CRITICAL ACCOUNTING POLICIES

In accordance with SEC Release No. 33-8040, “Cautionary Advice Regarding Disclosure About Critical Accounting Policies,” management has identified the accounting policies it believes to be the most critical to the Company’s financial statements—that is, management believes that these policies are both the most important to the portrayal of the Company’s results of operations and financial condition, and currently require management’s most difficult, subjective or complex judgments.

For information about these material estimates and critical accounting policies, see pages 50 to 51, 65, and 77 to 80 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2017 Form 10-K.

Following are discussions of the results of operations, liquidity and capital resources of the electric utility and bank segments.

Electric utility

RESULTS OF OPERATIONS



Three months ended June 30				Increase
2018		2017		(decrease)						(dollars in millions, except per barrel amounts)
$	608	$	557	$	51					Revenues. Net increase largely due to:
							$	27		higher fuel oil prices¹
							19			higher purchased power energy costs²
							12			higher RAM revenue
							10			higher rate relief
							8			higher KWH generated
							(3		)	lower PPAC revenues
							(8		)	lower KWH purchased
							(13		)	Tax reform adjustment
172		141		31						Fuel oil expense. Increase due to higher fuel oil prices and higher KWH generated
161		153		8						Purchased power expense. Increase due to higher fuel oil prices
							18			higher purchased power energy price
							(1		)	lower AES Hawaii capacity charges
							(1		)	lower PGV capacity charges
							(7		)	lower KWH purchased
113		105		8						Operation and maintenance expenses. Net increase due to:
							7			reset of pension costs as part of rate case interim decisions
							1			Big Island lava eruption response costs
							1			higher vegetation management costs
							(2		)	higher overhaul costs related to Waiau and Kahe plants in 2017
108		101		7						Other expenses. Increase due to higher revenue taxes from higher revenue, coupled with higher depreciation expense for plant investments in 2017
55		56		(1		)				Operating income. Decrease due to higher operation and maintenance and other expenses offset by higher revenue
31		26		5						Net income for common stock. Increase due to higher RAM and rate relief, offset by higher expenses

2,128		2,150		(22		)				Kilowatthour sales (millions)³
$	81.84	$	69.86	$	11.98					Average fuel oil cost per barrel¹



Six months ended June 30				Increase
2018		2017		(decrease)						(dollars in millions, except per barrel amounts)
$	1,179	$	1,075	$	104					Revenues. Net increase largely due to:
							$	61		higher fuel oil prices¹
							28			higher RAM revenues
							23			higher purchased power energy costs²
							17			higher rate relief
							(3		)	lower KWH generated
							(21		)	Tax reform adjustment
339		286		53						Fuel oil expense. Increase due to higher fuel oil prices, partially offset by lower KWH generated
301		280		21						Purchased power expense. Increase due to higher fuel oil prices
							21			higher purchased power energy price
							2			higher AES Hawaii capacity charges
							(3		)	lower KWH purchased
220		204		16						Operation and maintenance expenses. Net increase due to:
							10			reset of pension costs as part of rate case interim decisions
							2			write-off of smart grid costs
							1			higher ERP costs related to outside consultants
							1			one-time rent expense adjustment for existing substation land
							1			Big Island lava eruption response costs
							1			higher vegetation management costs
212		199		13						Other expenses. Increase due to higher revenue taxes from higher revenue, coupled with higher depreciation expense for plant investments in 2017
107		107		—						Operating income. Higher revenue from RAM and rate relief offset by higher operation and maintenance and other expenses
59		47		12						Net income for common stock. Increase due to higher RAM and rate relief, offset by higher expenses

4,140		4,188		(48		)				Kilowatthour sales (millions)³
$	81.26	$	67.78	$	13.48					Average fuel oil cost per barrel¹
462,547		460,858		1,689						Customer accounts (end of period)


1	The rate schedules of the electric utilities currently contain energy cost adjustment clauses (ECACs) through which changes in fuel oil prices and certain components of purchased energy costs are passed on to customers.


2	The rate schedules of the electric utilities currently contain purchase power adjustment clauses (PPACs) through which changes in purchase power expenses (except purchased energy costs) are passed on to customers.


3	KWH sales were lower when compared to the same quarter in the prior year due largely to continued energy efficiency and conservation efforts by customers and increasing levels of private customer-sited renewable generation.

The Utilities’ effective tax rates for the second quarters of 2018 and 2017 were 22% and 36%, respectively. The Utilities’ effective tax rates for the first six months of 2018 and 2017 were 23% and 36%, respectively. The effective tax rates were lower in the three and six months ended June 30, 2018 compared to the same periods in 2017 due primarily to the provision in the Tax Act that lowered the federal income tax rate from 35% to 21%. The lower tax rate was partially offset by other Tax Act changes (the non-deductibility of excess executive compensation and various fringe benefit costs). Although the Utilities’ effective income tax rate decreased, the net benefits of the Tax Act, including the lower effective tax rate, are being returned to customers through rates.

Hawaiian Electric’s consolidated ROACE was 7.2% for the twelve months ended June 30, 2018, and 7.2% for the twelve months ended June 30, 2017.

The Utilities’ consolidated KWH sales have declined each year since 2007. Based on expectations of additional customer renewable self-generation and energy-efficiency installations, the Utilities’ full year 2018 KWH sales are expected to be below the 2017 level. However, due to the decoupling model implemented in 2011, revenues are not tied to KWH sales and include annual rate adjustments to revenues. See “Decoupling” in the “Regulatory proceedings” section of Note 3 of the condensed consolidated financial statements for additional information.

The net book value (cost less accumulated depreciation) of utility property, plant and equipment (PPE) as of June 30, 2018 amounted to $4 billion, of which approximately 30% related to generation PPE, 61% related to transmission and distribution PPE, and 9% related to other PPE. Approximately 10% of the total net book value relates to generation PPE that has been deactivated or that the Utilities plan to deactivate or decommission. See “Adequacy of supply” below.

See “Economic conditions” in the “HEI Consolidated” section above.

Executive overview and strategy. The Utilities provide electricity on all the principal islands in the state, other than Kauai, and operate five separate grids. The Utilities’ mission is to provide innovative energy leadership for Hawaii, to meet the needs and expectations of customers and communities, and to empower them with affordable, reliable and clean energy. The goal is to create a modern, flexible and dynamic electric grid that enables an optimal mix of distributed energy resources (such as private rooftop solar), demand response and grid-scale resources to achieve the statutory goal of 100% renewable energy by 2045.

Transition to renewable energy. The Utilities are committed to partnering with the State of Hawaii in achieving its Renewable Portfolio Standard goal of 100% renewable energy by 2045. Hawaii’s RPS law requires electric utilities to meet an RPS of 15%, 30%, 40%, 70% and 100% by December 31, 2015, 2020, 2030, 2040 and 2045, respectively. The Utilities have been successful in adding significant amounts of renewable energy resources to their electric systems and exceeded the 2015 RPS goal. The Utilities' RPS for 2017 was about 27% and on its way to achieving the 2020 RPS goal of 30%. (See "Developments in renewable energy efforts” below).

In April 2014, the PUC issued orders that collectively address certain key policy, resource planning and operational issues for the Utilities. The April 2014 regulatory orders were to address: (1) Integrated Resource Planning and Power Supply Improvement Plans (PSIPs), (2) Reliability Standards Working Group, and (3) Policy Statement and Order Regarding Demand Response Programs, which are described below. The PUC also provided its inclinations on the future of Hawaii’s electric utilities in one of the orders. The PUC provided its 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.

Integrated Resource Planning and Power Supply Improvement Plans. In August 2014, the Utilities filed proposed Power Supply Improvement Plans (PSIPs) with the PUC , and subsequently filed updated PSIPs in April 2016 and December 2016 in response to PUC orders.

In the December 2016 PSIP Update Report, the updated plans describe greater and faster expansion of the Utilities’ renewable energy portfolio than in the plans filed in April 2016. 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, and additional grid-scale renewable energy resources. The Utilities already have the highest percentage of customers using private rooftop solar of any utility in the U.S. and customer-sited resources are seen as a key contributor to the growth of the renewable portfolio on every island. In addition, the plans forecast the addition of 360 MW of grid-scale solar and 157 MW of grid-scale wind, with 8 MW derived from the first phase of the community-based renewable energy (CBRE) program. The plans also include 115 MW from Demand Response (DR) programs, which can shift customer use of electricity to times when more renewable energy is available, potentially making room to add even more renewable resources. The Utilities’ priority is to continue replacing fossil fuel generation with renewables over the next few years as federal tax incentives for renewables begin to phase out. The December 2016 Update Report emphasizes work that is in progress or planned through 2021 on each of the five islands the Utilities serve.

On March 1, 2018, the Utilities filed its Integrated Grid Planning (IGP) Report that provides an innovative systems approach to energy planning intended to yield the most cost-effective renewable energy pathways that are rooted in customer and stakeholder input. The Utilities’ IGP fully integrates resource, transmission, and distribution planning and incorporates solutions sourcing into the planning process. This will enable optimization and coordination of the solutions, thereby resulting in actionable near-term plans that maximize value to customers.

Reliability standards working group. In April 2014, 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 that 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 DR programs, and ordered the Utilities to develop an integrated DR Portfolio Plan that will enhance system operations and reduce costs to customers. The Utilities’ DR Portfolio will create the economic and technical means by which customers can use their own equipment and behavior to have a role in the management of the electricity grid. Participating customers will be empowered with increasing opportunities to simultaneously install DER enabling active participation in the grid and its associated economics. These opportunities will take the form of either rates and incentive-based programs that will compensate customers for their participation, or by way of engagements with turnkey service providers that contract with the Utilities to aggregate and deliver various grid services on behalf of participating customers and their distributed assets.

The Utilities filed their DR Portfolio Plan in July 2014 and an updated Plan in February 2017. In July 2015, the PUC issued an order appointing a special adviser to guide, monitor and review the Utilities’ Plan design and implementation. In December 2015, the Utilities filed an application with the PUC for approval of their proposed DR Portfolio Tariff Structure, Reporting Schedule and Cost Recovery of Program Costs. On January 25, 2018, the PUC approved the Utilities’ revised DR Portfolio tariff structure. The PUC supported the approach of working with aggregators to implement the DR portfolio, and ordered the Utilities to complete contracting by June 2018 and initiate first implementation by the third quarter of 2018. The Companies have selected the aggregators and commenced negotiations in July 2018 with a target to meet the goal of initiating implementation by the third quarter of 2018.

In October 2017, the PUC approved the Utilities request made in December 2015 to defer and recover certain computer software and software development costs for a DR Management System in an amount not to exceed $3.9 million, exclusive of AFUDC, through the Renewable Energy Infrastructure Program Surcharge. The Utilities completed the first milestone of Blueprinting and will move onto the realization phase in the third quarter of 2018. The Utilities are still on schedule for the DR Management System to be in service by first quarter of 2019.

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

In June 2015, the Utilities submitted their final Statement of Position in the DER proceeding, which included new pricing provisions for future private rooftop PV systems, technical standards for advanced inverters, new options for customers including battery-equipped private rooftop PV systems, a pilot time-of-use rate, an improved method of calculating the amount of private rooftop PV that can be safely installed, and a streamlined and standardized PV application process.

In October 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 the NEM programs to new participants, and approved new interim options for customers to interconnect DER to the utility electric grids, including Self Supply and Grid Supply tariff options and modified interconnection standards. 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 October 2017, the PUC issued a D&O which further revises interconnection requirements, creates a Smart Export program, modifies the customer-grid supply program (Controllable Customer Grid Supply), clarifies that non-export customer systems can be added to the existing NEM program, and provides guidance and reporting requirements regarding hosting capacity analyses. The Smart Export program is designed for PV systems with battery storage and features zero compensation during mid-day, but enhanced compensation at other times of the day to reflect the value of the energy to the grid at different times of the day. The Controllable Customer Grid Supply program allows PV systems without battery storage to deliver energy to the grid on an as-available basis except when system-wide technical conditions require reduction of output. The D&O specified island-specific pricing and program caps for the Smart Export and Controllable Customer Grid Supply programs. Customers currently under the customer-grid supply program are grandfathered under existing rates for the next five years. The

D&O also authorizes activation of new advanced inverter functions in PV and storage systems, which will provide support to the electric grid during different types of grid disturbances.

In February 2018, the PUC issued an order which approved, with certain modifications, new tariffs proposed by the Utilities, which will implement the Smart Export and Controllable Customer Grid Supply programs in manners consistent with the PUC’s October 2017 D&O, and approved, with certain modifications, revisions to existing tariffs also proposed by the Utilities. The February 2018 order denied the Utilities’ proposal to allow NEM customers to add non-export energy storage systems, but on June 29, 2018, the PUC issued an order which approved, with certain modifications, the Utilities’ revised proposal to allow NEM customers to add non-export energy storage systems.

Grid modernization. After launching a smart grid customer engagement plan during the second quarter of 2014, Hawaiian Electric replaced approximately 5,200 residential and commercial meters with smart meters, 160 direct load control switches, fault circuit indicators and remote controlled switches in selected areas across Oahu as part of the Smart Grid Initial Phase implementation. Also under the Initial Phase a grid efficiency measure called Volt/Var Optimization (or Conservation Voltage Reduction) was enabled, customer energy portals were launched and are available for customer use and a PrePay Application was launched. The Initial Phase implementation was completed in 2015. The smart grid provides benefits such as customer tools to manage their electric bills, potentially shortening outages and enabling the Utilities to integrate more low-cost renewable energy, like wind and solar, which will reduce Hawaii’s dependence on imported oil.

The PUC indicated that the overall goal of the Grid Modernization Strategy is to deploy modern grid investments at an appropriate priority, sequence and pace to cost-effectively maximize flexibility, minimize the risk of redundancy and obsolescence, deliver customer benefits and enable greater DER and renewable energy integration. On June 30, 2017, the Utilities filed an initial draft of the Grid Modernization Strategy describing how new technology will help triple private rooftop solar and make use of rapidly evolving products including storage and advanced inverters. The cost of the first segment of the modernization is estimated at about $205 million over six years. The Utilities filed their final Grid Modernization Strategy on August 29, 2017. On February 7, 2018, the PUC issued an order setting forth next steps and directives for the Utilities to implement the Grid Modernization Strategy. The Utilities have begun work to implement the Grid Modernization Strategy by issuing solicitations for advanced meters, a meter data management system, and a communications network. Also, the Utilities have filed their first application with the PUC on June 21, 2018, for the first implementation phase. Additional applications will be filed later to implement subsequent phases of the strategy.

Community-Based Renewable Energy. On October 1, 2015, the Utilities filed a proposed CBRE program and tariff with the PUC that would allow customers who cannot, or chose not to, take advantage of private rooftop solar to receive the benefits of renewable energy to help offset their monthly electric bills and support clean energy for Hawaii. In December 2017, the PUC adopted a CBRE program framework, the Utilities provided comments and filed relevant materials for review and on June 29, 2018, the PUC issued an order approving the Utilities’ tariffs. The tariffs became effective on July 11, 2018 for each island and phase 1 of the CBRE program commenced.

The first phase will total 8 MW of solar PV only with one credit rate for each island. The Utilities' role will be limited to administrative only during the first phase. The second phase will commence after review of the first full year of the first phase. The second phase is contemplated to be a larger capacity and include multiple credit rates (e.g., time of day) and various technologies. The Utilities will have the opportunity to develop self-build projects; however 50% of utility capacity will be reserved for low to moderate income customers.

Microgrid services tariff proceeding. On July 10, 2018, the PUC issued an order instituting a proceeding to investigate establishment of a microgrid services tariff, pursuant to Act 200 (July 10, 2018 Act). The PUC will issue subsequent order(s) establishing a statement of issues to be addressed in the order, and issue a procedural schedule to govern this proceeding, after the deadline for the filing of motions to intervene or participate.

Decoupling. See "Decoupling" in Note 3 of the Condensed Consolidated Financial Statements for a discussion of decoupling.

As part of decoupling, the Utilities also track their rate-making ROACEs as calculated under the earnings sharing mechanism, which includes only items considered in establishing rates. At year-end, each utility's rate-making ROACE is compared against its ROACE allowed by the PUC to determine whether earnings sharing has been triggered. Annual earnings of a utility over and above the ROACE allowed by the PUC are shared between the utility and its ratepayers on a tiered basis. Earnings sharing credits are included in the annual decoupling filing for the following year. Results for 2017, 2016 and 2015 did not trigger the earnings sharing mechanism for the Utilities.

Regulated returns.Actual and PUC-allowed (as of June 30, 2018) returns were as follows:



%	Rate-making Return on rate base (RORB)*						ROACE**						Rate-making ROACE***
Twelve months ended June 30, 2018	Hawaiian Electric		Hawaii Electric Light		Maui Electric		Hawaiian Electric		Hawaii Electric Light		Maui Electric		Hawaiian Electric		Hawaii Electric Light		Maui Electric
Utility returns	6.32		6.92		5.96		7.21		7.51		6.78		7.65		8.18		6.96
PUC-allowed returns	7.57		7.80		7.34		9.50		9.50		9.00		9.50		9.50		9.00
Difference	(1.25	)	(0.88	)	(1.38	)	(2.29	)	(1.99	)	(2.22	)	(1.85	)	(1.32	)	(2.04	)

* Based on recorded operating income and average rate base, both adjusted for items not included in determining electric rates.

** Recorded net income divided by average common equity.

*** ROACE adjusted to remove items not included by the PUC in establishing rates, such as incentive compensation.

The gap between PUC-allowed ROACEs and the ROACEs actually achieved is primarily due to: the consistent exclusion of certain expenses from rates (for example, incentive compensation and charitable contributions), the recognition of annual RAM revenues on June 1 annually rather than on January 1, the low RBA interest rate (currently a short-term debt rate rather than the actual cost of capital), O&M increases and return on capital additions since the last rate case in excess of indexed escalations, and the portion of the pension regulatory asset not earning a return due to pension contributions and pension costs in excess of the pension amount in rates. In 2017, the utility ROACEs actually achieved reflect negative impacts of the Tax Act on deferred tax assets.

Most recent rate proceedings. Unless otherwise agreed or ordered, each electric utility is currently required by PUC order to initiate a rate proceeding every third year (on a staggered basis) to allow the PUC and the Consumer Advocate to regularly evaluate decoupling and to allow the utility to request electric rate increases to cover rising operating costs and the cost of plant and equipment, including the cost of new capital projects to maintain and improve service reliability and integrate more renewable energy. The PUC may grant an interim increase within 10 to 11 months following the filing of an application, but there is no guarantee of such an interim increase and interim amounts collected are refundable, with interest, to the extent they exceed the amount approved in the PUC’s final D&O. The timing and amount of any final increase is determined at the discretion of the PUC. The adoption of revenue, expense, rate base and cost of capital amounts (including the ROACE and RORB) for purposes of an interim rate increase does not commit the PUC to accept any such amounts in its final D&O.

The effects of the Tax Act on Utilities’ regulated operations accrued to the benefit of customers from the effective date of January 1, 2018. Generally, the lower corporate income tax rate lowers the Utilities’ revenue requirements through lower income tax expense and through the amortization of a regulatory liability for excess accumulated deferred income taxes (ADIT) resulting from the recording of ADIT in prior years at the higher income tax rate. The revenues collected in the first and a portion of the second quarters reflected income taxes at the old 35% rate and consequently, the Utilities reduced revenues to the extent the income taxes collected in 2018 revenue exceeded the taxes accrued at the new 21% rate. This reduction was recorded to a regulatory liability and electric rates have been adjusted in the second quarter to initiate the pass back of the 2018 excess to customers over various amortization periods. In addition, rates have been adjusted to begin passing back the excess ADIT that was accumulated as of December 31, 2017. The Tax Act also excludes essentially all of the Utilities’ plant from qualifying for bonus depreciation, which will partially offset the aforementioned impacts by lowering ADIT and thereby increasing rate base and the associated revenue requirement for new plant going forward.



Test year (dollars in millions)	Date (filed/ implemented)	Amount			% over rates in effect	ROACE (%)	RORB (%)	Rate base		Common equity %	Stipulated agreement reached with Consumer Advocate
Hawaiian Electric
2017 ¹
Request	12/16/16	$	106.4		6.9	10.60	8.28	$	2,002	57.36	Yes
Interim increase	2/16/18	36.0			2.3	9.50	7.57	1,980		57.10
Interim increase with Tax Act	4/13/18	(0.6		)	—	9.50	7.57	1,993		57.10
Final increase		(0.6		)	—	9.50	7.57	1,993		57.10
Hawaii Electric Light
2016²
Request	9/19/16	$	19.3		6.5	10.60	8.44	$	479	57.12	Yes
Interim increase	8/31/17	9.9			3.4	9.50	7.80	482		56.69
Interim increase with Tax Act	5/1/18	1.5			0.5	9.50	7.80	481		56.69
Final increase		—			—	9.50	7.80	481		56.69
Maui Electric
2018
Request	10/12/17	$	30.1		9.3	10.60	8.05	$	473	56.94	Yes
Joint Statement of Probable
Entitlement (which will be
superceded by any PUC interim D&O)
At old depreciation rates	7/6/18	6.4			1.95	9.50	7.43	465		57.02
At new depreciation rates	7/6/18	12.5			3.82	9.50	7.43	462		57.02

Note: The “Request date” reflects the application filing date for the rate proceeding. The “Interim increase” date reflects the effective date of the revised schedules and tariffs as a result of the PUC-approved increase.


1	On June 22, 2018, the PUC issued a final decision and order approving the final increase amounts in the table above for Hawaiian Electric. The effective date of this final increase is subject to PUC-approval of Hawaiian Electric’s revised rate schedules and tariffs.

2 On June 29, 2018, the PUC issued a final decision and order approving the final increase amounts in the table above for Hawaii Electric Light. The effective date of this final increase is subject to PUC-approval of Hawaii Electric Light’s revised rate schedules and tariffs.

See “Most recent rate proceedings” in Note 3 of the Condensed Consolidated Financial Statements.

Performance-based regulation. See “Performance incentive mechanisms” and “Performance-based regulation proceeding” in Note 3 of the Condensed Consolidated Financial Statements.

Depreciation docket. In December 2016, the Utilities filed an application with the PUC for approval of changes in the depreciation and amortization rates and amortization period for CIAC, based on a 2015 Book Depreciation Study. In July 2018, the PUC approved the stipulated agreement between the Utilities and the Consumer Advocate, which among other things:

Authorized the use of consolidated depreciation and amortization rates rather than separate depreciation and amortization rates for the three utilities

Established revised depreciation and amortization rates for the three utilities

Approved the implementation of the new depreciation and amortization rates and other changes to coincide with the effective date of the interim or final base rates approved in the subsequent rate case for each utility, beginning with Maui Electric’s ongoing 2018 test year

Developments in renewable energy efforts. Developments in the Utilities’ efforts to further their renewable energy strategy include renewable energy projects discussed in Note 3 of the Condensed Consolidated Financial Statements and the following:

New renewable PPAs.

In July 2015, Maui Electric signed two PPAs, with Kuia Solar and South Maui Renewable Resources (which subsequently assigned its PPA to SSA Solar of HI 2, LLC and SSA Solar of HI 3, LLC, respectively), each for a 2.87-MW solar facility. In February 2016, the PUC approved both PPAs, subject to certain conditions and modifications. The guaranteed commercial operations date for the facilities was December 31, 2016, however both projects experienced delays. South Maui Renewable Resources reached commercial operations on May 5, 2018, and Kuia Solar is now expected to be in commercial operations by the end of the third quarter of 2018.

In December 2014, the PUC approved a PPA for Renewable As-Available Energy dated October 3, 2013 between Hawaiian Electric and Na Pua Makani Power Partners, LLC (NPM) for a proposed 24-MW wind farm on Oahu. The NPM wind farm is expected to be placed into service by August 31, 2019.

Hawaiian Electric terminated PPAs to purchase solar energy with three affiliates of SunEdison, which affiliates were acquired by an affiliate of NRG Energy, Inc. (NRG) during SunEdison’s Chapter 11 bankruptcy proceedings. Hawaiian Electric then negotiated with NRG and its newly acquired affiliates and entered into amended and restated PPAs for solar energy on Oahu with Waipio PV, LLC for 45.9 MW, Lanikuhana Solar, LLC for 14.7 MW and Kawailoa Solar, LLC for 49.0 MW. In July 2017, the PUC approved the three NRG PPAs, subject to modifications and conditions. The three projects are expected to be in service by the end of 2019.

In February 2018, NRG and GIP III Zephyr Acquisition Partners, a subsidiary of Global Infrastructure Partners (GIP), entered into an agreement where GIP has agreed to purchase substantially all of NRG’s renewable platform, including NRG’s renewable operations, maintenance and development businesses. Kawailoa Solar, LLC, Lanikuhana Solar, LLC, and Waipio PV, LLC, along with NRG Renew LLC, are included in the sale transaction. NRG Renew has confirmed that this transaction will not in any way affect the completion or success of the three PV Projects.

In July 2018, the PUC approved the Maui Electric’s PPA with Molokai New Energy Partners to purchase solar energy from a PV plus battery storage project. The 4.9 MW project will deliver no more than 2.64 MW at any time to the Molokai system and is expected to be in service by end of 2019.

Tariffed renewable resources.

As of June 30, 2018, there were approximately 449 MW, 91 MW and 101 MW of installed distributed renewable energy technologies (mainly PV) at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively, for tariff-based private customer generation programs, namely Standard Interconnection Agreement (SIA), NEM, Customer Grid Supply, Customer Self Supply, Grid Supply Plus and Smart Export. As of June 30, 2018, an estimated 28% of single family homes on the islands of Oahu, Hawaii and Maui have installed private rooftop solar systems, and approximately 17% of the Utilities' total customers have solar systems.

The Utilities began accepting energy from feed-in tariff projects in 2011. As of June 30, 2018, there were 31 MW, 3 MW and 5 MW of installed feed-in tariff capacity from renewable energy technologies at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.

Biofuel sources.

In September 2015, the PUC approved Hawaiian Electric’s 2-year biodiesel supply contract with Pacific Biodiesel Technologies, LLC (PBT) to supply 2 million to 3 million gallons of biodiesel at Campbell Industrial Park combustion turbine No. 1 (CIP CT-1) and the Honolulu International Airport Emergency Power Facility beginning in November 2015. The PBT contract is set to expire on November 2, 2018. PBT also has a spot buy contract with Hawaiian Electric to purchase additional quantities of biodiesel at or below the price of diesel. Some purchases of “at parity” biodiesel have been made under the spot purchase contract, which was recently extended through June 2019. REG Marketing & Logistics Group, LLC has a contingency supply contract with Hawaiian Electric to also supply biodiesel to CIP CT-1 in the event PBT is not able to supply necessary quantities. This contingency contract has been extended to November 2019, and will continue with no volume purchase requirements.

On October 27, 2017, Hawaiian Electric entered into a new biodiesel supply contract with PBT, subject to PUC approval, to supply 2 million to 4 million gallons of biodiesel per year for three years. The new PBT contract is expected to commence as early as November 2018 to be used as fuel for power generation at Hawaiian Electric’s Schofield Generating Station, the Honolulu International Airport Emergency Power Facility and any other generating unit on Oahu, as necessary.

Requests for renewable proposals, expressions of interest, and information.

In response to requests filed by the Utilities, on October 6, 2017, the PUC opened a docket to receive filings, review approval requests, and resolve disputes, if necessary, related to the Utilities' plan to proceed with a competitive bidding process for dispatchable firm renewable generation and variable renewable generation. On October 23, 2017, the Utilities filed draft requests for proposals for 220 MW of renewable generation on Oahu (Oahu Variable RFP), 50 MW of renewable generation on Hawaii Island (Hawaii Variable RFP), and 100 MW of renewable generation on Maui, including 40 MW of firm renewable generation, comprising the Maui Variable RFP and Maui Firm RFP (all resources to be in service by the end of 2022). With this filing, the Utilities also filed proposed model power purchase agreements and timelines for each proposed procurement. In January 2018, the PUC issued an order appointing Independent Observers for the RFPs and directed the Utilities to move forward with the three Variable RFPs. On February 20, 2018, the PUC approved, with minor modification, the proposed Variable RFPs and directed the Utilities to issue the RFPs, as modified. On February 27, 2018, the Utilities opened the RFPs to receive proposals, with an April

30, 2018 deadline for such proposals. The Utilities are currently evaluating responses to the RFPs and plan to select a final award group by September 17, 2018 and file PPAs with the selected projects by the end of 2018. The Utilities are currently working with the independent observer for the Maui Firm RFP to update and revise the draft Maui Firm RFP for filing with the PUC for approval.

On January 5, 2017, Hawaiian Electric issued requests for Onshore Wind Expression of Interest to developers that are capable of developing utility scale onshore wind projects that are eligible to capture the federal Investment Tax Credit for Large Wind on the island of Oahu. Hawaiian Electric is in non-binding confidential negotiations with a developer that responded.

On December 12, 2016, the Utilities issued a request for information asking interested landowners to provide information about properties available for utility-scale renewable energy projects or for growing biofuel feedstock on the islands of Oahu, Hawaii, Maui, Molokai and Lanai. Responses have been made available to developers interested in developing renewable energy projects on these five islands.

Adequacy of supply.

Hawaiian Electric. In January 2018, Hawaiian Electric filed its 2018 Adequacy of Supply (AOS) letter, which indicated that based on its June 2017 sales and peak forecast for the 2018 - 2023 time period, Hawaiian Electric's generation capacity will be sufficient to meet reasonably expected demands for service and provide reasonable reserves for emergencies through 2021, but may have shortfalls in meeting the Utilities’ generating system reliability guideline. The calculated reliability guideline shortfalls are relatively small and Hawaiian Electric can implement mitigation measures.

In accordance with its planning criteria, Hawaiian Electric deactivated two fossil fuel generating units from active service at its Honolulu Power Plant in January 2014. Hawaiian Electric acquired new firm capacity of 8 MW with the commissioning of the State of Hawaii Department of Transportation’s emergency power facility in June 2017. Hawaiian Electric is continuing negotiations with firm capacity IPPs on Oahu. On August 31, 2017, 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, 2018. The PPA with AES Hawaii is scheduled to expire in 2022. On June 7, 2018, Hawaiian Electric’s Schofield Generating Station was placed into service, providing approximately 50 MW of additional generating capability on Oahu.

Hawaii Electric Light. In January 2018, Hawaii Electric Light filed its 2018 AOS letter, which indicated that Hawaii Electric Light’s generation capacity through 2020 is sufficient to meet reasonably expected demands for service and provide for reasonable reserves for emergencies. Hawaii Electric Light is anticipating the addition of the firm dispatchable Hu Honua facility to be online by the end of 2018. Since May 2018, the Puna Geothermal Venture facility has been offline due to the ongoing lava flow on Hawaii Island. Hawaii Electric Light expects to have sufficient generation capacity despite the shutdown of Puna Geothermal Venture.

Maui Electric. In January 2018, Maui Electric filed its 2018 AOS letter, which indicated that Maui Electric’s generation capacity for the islands of Lanai and Molokai for the next three years is sufficiently large to meet all reasonably expected demands for service and provide reasonable reserves for emergencies. The 2018 AOS letter also indicated that without the peak reduction benefits of demand response but with the equivalent firm capacity value of wind generation, Maui Electric expects to have a reserve capacity shortfall from 2018 to 2020 on the island of Maui. Maui Electric is evaluating several measures to mitigate the anticipated reserve capacity shortfall. Maui Electric anticipates needing a significant amount of additional firm capacity on Maui in the 2022 timeframe after the planned retirement of the Kahului Power Plant.

In May 2016, Maui Electric requested that the PUC open a new docket for Maui Electric’s competitive bidding process for additional firm capacity resources. In October 2017, Maui Electric filed a draft RFP and supporting documents as requested by the PUC. In January 2018, the PUC issued an order appointing an Independent Observer of the RFP process that reports to the PUC for Maui Firm RFP. However, the PUC stated Maui Electric should focus on its variable RFP and noted that it would provide further guidance on the Firm RFP.

In September 2016, Maui Electric submitted an application to purchase and install three temporary mobile distributed generation diesel engines to address increasing reserve capacity shortfalls on the island of Maui; Maui Electric has since requested the PUC to suspend the proceeding to evaluate contingency measures and permanent solutions to minimize or eliminate the risk of near-term capacity shortfalls on the island of Maui.

Legislation and regulation. Congress and the Hawaii legislature periodically consider legislation that could have positive or negative effects on the Utilities and their customers. Also see “Environmental regulation” in Note 3 of the Condensed Consolidated Financial Statements.

Clean Water Act Section 316(b). On August 14, 2014, the EPA published in the Federal Register the final regulations required by section 316(b) of the CWA designed to protect aquatic organisms from adverse impacts associated with existing

power plant cooling water intake structures. The regulations were effective October 14, 2014 and apply to the cooling water systems for the steam generating units at three of Hawaiian Electric’s power plants on the island of Oahu. The regulations prescribe a process, including a number of required site-specific studies, for states to develop facility-specific entrainment and impingement controls to be incorporated in each facility’s National Pollutant Discharge Elimination System permit. Hawaiian Electric submitted the final site specific studies to the DOH in December 2016 for the Honolulu and Waiau power plants and in September 2017 for the Kahe power plant. Hawaiian Electric will work with the DOH to identify the appropriate compliance methods for the 316(b) rule.

Performance-based ratemaking legislation. See “Performance incentive mechanisms” and “Performance-based regulation proceeding” in Note 3 of the Condensed Consolidated Financial Statements.

Potential impact of lava flows. In May 2018, a lava eruption occurred within the Leilani Estates subdivision, located along the lower East Rift Zone of Kilauea Volcano in the Puna district on the island of Hawaii. Since the time of the initial event, over 20 fissures have erupted lava and gas in the area covering approximately 12.8 square miles or 8,000 acres of land. Approximately 3,000 of the 86,000 Hawaii Electric Light customers reside in that area and over 1,000 customers have evacuated their homes, some permanently. The lava flow is currently concentrated to fissure #8, located within Leilani Estates, which is active and feeding a perched lava channel leading northeastward from the vent toward the Kapoho region. The flow has damaged some of Hawaii Electric Light’s property in the affected area and has also resulted in the shutdown of independent power producer PGV’s facilities. PGV has retained all of its employees despite the current shutdown and will evaluate the future availability of that plant. Hawaii Electric Light continues to serve the load of Hawaii Island without capacity from PGV, and the Utilities expect to meet its 2020 RPS goals without the return of PGV to service. Although the lava eruption continues and is unpredictable, the financial impact to Hawaii Electric Light to date has not been material.

PUC Commissioner. Jennifer Potter began her term as PUC Commissioner, effective July 1, 2018, replacing outgoing commissioner Lorraine Akiba, whose term expired on June 30, 2018. Ms. Potter was an assistant specialist at Hawaii Natural Energy Institute, and previously worked at Lawrence Berkley National Lab as a senior scientific engineering associate, as well as at the Sacramento Municipal Utility District in various positions.

FINANCIAL CONDITION

Liquidity and capital resources. As a result of the Tax Cut and Jobs Act, utility property is no longer eligible for bonus depreciation, but further guidance is required in order to finally determine the timing of the application of the new law. However, note that recent clarification in the tax law indicates that certain assets with longer construction periods that were placed in service after the effective date may be grandfathered and qualify for the old 50% bonus depreciation if subject to binding contracts entered into before such effective date. The Utilities are currently evaluating its larger projects placed into service after September 27, 2017 for applicability. Nevertheless, the initial cash requirement for future capital projects will generally increase because of the loss of the immediate tax benefit from bonus depreciation. Management believes that Hawaiian Electric’s ability, and that of its subsidiaries, to generate cash, both internally from operations and externally from issuances of equity and debt securities and commercial paper and draws on lines of credit, is adequate to maintain sufficient liquidity to fund their respective capital expenditures, investments, debt repayments, retirement benefit plan contributions and other cash requirements in the foreseeable future.

Hawaiian Electric’s consolidated capital structure was as follows:



(dollars in millions)	June 30, 2018				December 31, 2017
Short-term borrowings	$	92	3	%	$	5	—	%
Long-term debt, net	1,468		42		1,369		42
Preferred stock	34		1		34		1
Common stock equity	1,852		54		1,845		57
	$	3,446	100	%	$	3,253	100	%

Information about Hawaiian Electric’s short-term borrowings (other than from Hawaii Electric Light and Maui Electric) and Hawaiian Electric’s line of credit facility were as follows:



	Average balance		Balance
(in millions)	Six months ended June 30, 2018		June 30, 2018		December 31, 2017
Short-term borrowings ¹
Commercial paper	$	88	$	92	$	5
Line of credit draws	—		—		—
Borrowings from HEI	—		—		—
Undrawn capacity under line of credit facility	—		200		200

¹ The maximum amount of external short-term borrowings by Hawaiian Electric during the first six months of 2018 was $157 million. As of June 30, 2018, Hawaiian Electric had short-term borrowings from Hawaii Electric Light of $1 million and Maui Electric had short-term borrowings from Hawaiian Electric of $5.6 million.

Hawaiian Electric has a $200 million line of credit facility with no amounts outstanding at June 30, 2018. See Note 5 of the Condensed Consolidated Financial Statements.

Upon PUC approval received in April 2018 (April 2018 Approval), on May 30, 2018, Hawaiian Electric, Hawaii Electric Light and Maui Electric issued through a private placement, $75 million, $15 million and $10 million, respectively, of unsecured senior notes bearing taxable interest. The April 2018 Approval also authorized the use of the expedited approval procedure to request for the remaining additional taxable debt to be issued during 2019 through 2021, with certain conditions, for up to $205 million and $15 million for Hawaiian Electric and Hawaii Electric Light, respectively. Maui Electric does not have authorization to issue additional taxable debt beyond 2018. See Note 5 of the Condensed Consolidated Financial Statements.

On July 12, 2018, the Utilities requested PUC approval to issue the remaining authorized amounts under the April 2018 Approval in 2019 through 2020 (Hawaiian Electric up to $205 million and Hawaii Electric Light up to $15 million of taxable debt), as well as a supplemental increase to authorize the issuance of additional taxable debt to finance capital expenditures, repay long-term and/or short term debt used to finance or refinance capital expenditures, and/or to reimburse funds used for payment of capital expenditures, and to refinance the Utilities’ 2004 junior subordinated deferrable interest debentures prior to maturity. In addition, the Utilities requested approval to extend the period to issue additional taxable debt from December 31, 2021 to December 31, 2022. The new total “up to” amounts of taxable debt authorized to be issued through December 31, 2022 are $410 million, $150 million and $130 million for Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.

Cash flows. The following table reflects the changes in cash flows for the six months ended June 30, 2018 compared to the six months ended June 30, 2017:



	Six months ended June 30,
(in thousands)	2018			2017			Change
Net cash provided by operating activities	$	69,836		$	138,755		$	(68,919	)
Net cash used in investing activities	(195,346		)	(166,338		)	(29,008		)
Net cash provided by (used in) financing activities	133,853			(4,121		)	137,974

Net cash provided by operating activities. Cash flows from operating activities generally relate to the amount and timing of cash received from customers and payments made to third parties. Using the indirect method of determining cash flows from operating activities, noncash expense items such as depreciation and amortization, as well as changes in certain assets and liabilities, are added to (or deducted from) net income. The decrease in net cash provided by operating activities was primarily driven by lower cash from an increase in accounts receivable due to timing and increase in customer bills as a result of higher fuel prices and purchased power costs included in rates, and a decrease in accounts payable due to timing on payments of invoices related to fuel and capital projects, partially offset by lower income taxes paid due to the lower federal income tax rate from the Tax Act.

Net cash used in investing activities. The increase in net cash used in investing activities was primarily driven by an increase in capital expenditures related to construction activities, and a decrease in contributions received in aid of construction.

Net cash provided by financing activities. Financing activities provide supplemental cash for both day-to-day operations and capital requirements as needed. The increase in net cash provided by financing activities primarily reflected higher proceeds from long-term and short-term borrowings.

Forecast capital expenditures. For the five-year period 2018 through 2022, the Utilities forecast up to $2.2 billion of net capital expenditures, which could change over time based upon external factors such as the timing and scope of environmental regulations, unforeseen delays in permitting and timing of PUC decisions. Proceeds from the issuance of equity and long-term debt, cash flows from operating activities, temporary increases in short-term borrowings and existing cash and cash equivalents are expected to provide the funds needed for the net capital expenditures, to pay down commercial paper or other short-term borrowings, as well as to fund any unanticipated expenditures not included in the 2018 to 2022 forecast (such as increases in the costs or acceleration of capital projects or unanticipated capital expenditures that may be required by new environmental laws and regulations).

Management periodically reviews capital expenditure estimates and the timing of construction projects. These estimates may change significantly as a result of many considerations, including changes in economic conditions, changes in forecasts of KWH sales and peak load, the availability of purchased power and changes in expectations concerning the construction and ownership of future generation units, the availability of generating sites and transmission and distribution corridors, the need for fuel infrastructure investments, the ability to obtain adequate and timely rate increases, escalation in construction costs, the effects of opposition to proposed construction projects and requirements of environmental and other regulatory and permitting authorities.

Bank



	Three months ended June 30				Increase
(in millions)	2018		2017		(decrease)			Primary reason(s)
Interest income	$	63	$	59	$	4		The increase in interest income was the result of increases in balances and yields on earning assets. ASB’s average investment securities portfolio balance for the three months ended June 30, 2018 increased by $218 million compared to the same period in 2017 as ASB used excess liquidity to purchase investments. The yield on the investment securities portfolio increased by 15 basis points as new investment purchase yields were higher due to the rising interest rate environment. ASB’s average loan portfolio balance for the three months ended June 30, 2018 increased by $28 million compared to the same period in 2017 as the average residential, home equity line of credit and consumer loan portfolios for the three months ended June 30, 2018 increased by $49 million, $55 million and $31 million, respectively, compared to the same period in 2017. The growth in these loan portfolios aligned with ASB’s portfolio mix target and loan growth strategy. The average commercial and commercial real estate balances decreased by $70 million and $37 million, respectively. The decrease in these loan portfolios was reflective of ASB’s strategic decision to reduce the balances in certain commercial and national loan portfolios to improve the credit quality of those portfolios. The yield on loans benefited from the rising interest rate environment, which resulted in an increase in yield of 17 basis points.
Noninterest income	14		16		(2		)	Noninterest income decreased for the three months ended June 30, 2018 compared to noninterest income for the three months ended June 30, 2017 primarily due to lower fees from other financial services in 2018 as a result of debit card interchange expenses being netted against income beginning in 2018. Prior year’s debit card interchange expenses were recorded in other noninterest expense. This change was in accordance with the new revenue recognition accounting standard. See Note 7 of the Condensed Consolidated Financial Statements for additional information on the new revenue recognition standard.
Revenues	77		75		2
Interest expense	3		3		—			Interest expense was flat for the three months ended June 30, 2018 compared to the same period in 2017 as higher interest expense from the growth in time certificates was partly offset by lower interest expense on other borrowings as a result of lower FHLB advances. Average deposit balances for the three months ended June 30, 2018 increased by $363 million compared to the same period in 2017 due to an increase in core deposits and time certificates of $277 million and $86 million, respectively. Average other borrowings for the three months ended June 30, 2018 decreased by $69 million compared to the same period in 2017 due to a decrease in the average FHLB advances and repurchase agreements of $49 million and $20 million, respectively. The interest-bearing liability rate for the three months ended June 30, 2018 increased by 4 basis points compared to the same period in 2017.
Provision for loan losses	3		3		—			The provision for loan losses was flat for the three months ended June 30, 2018 compared to the provision for loan losses for the three months ended June 30, 2017. The provision for loan losses for 2018 was primarily due to increased reserves for growth in the loan portfolio and additional loan loss reserves for the consumer and residential loan portfolios, partly offset by the release of reserves for the home equity line of credit, commercial and commercial real estate loan portfolios as result of improved credit quality in those loan portfolios. The provision for loan losses for 2017 was primarily due to increased loan loss reserves for the consumer loan portfolio. Delinquency rates have increased from 0.44% at June 30, 2017 to 0.54% at June 30, 2018. The annualized net charge-off ratio for the three months ended June 30, 2018 was 0.32% compared to an annualized net charge-off ratio of 0.21% for the same period in 2017.
Noninterest expense	44		45		(1		)	The decrease in noninterest expense for the three months ended June 30, 2018 compared to the same period in 2017 was primarily due to the reclassification of debit card interchange expenses to noninterest income in accordance with the new revenue recognition accounting standard that became effective on January 1, 2018.
Expenses	50		51		(1		)
Operating income	27		24		3			The increase in operating income for the three months ended June 30, 2018 compared to the same period in 2017 was primarily due to higher interest income and lower noninterest expense, partly offset by lower noninterest income.
Net income	21		17		4			The increase in net income for the three months ended June 30, 2018 compared to the same period in 2017 was primarily due to higher operating income and lower income tax expense as a result of the lower corporate rate from the Tax Act.



	Six months ended June 30				Increase
(in millions)	2018		2017		(decrease)			Primary reason(s)
Interest income	$	125	$	117	$	8		The increase in interest income was primarily the result of an increase in yields on earning assets and higher investment securities portfolio balances. ASB’s average investment securities portfolio balance for the six months ended June 30, 2018 increased by $271 million compared to the same period in 2017 as ASB used excess liquidity to purchase investments. The yield on the investment securities portfolio increased by 12 basis points as new investment purchase yields were higher due to the rising interest rate environment. ASB’s average loan portfolio balance for the six months ended June 30, 2018 increased by $6 million compared to the same period in 2017 as increases in the average residential, home equity line of credit and consumer loan portfolios for the six months ended June 30, 2018 of $52 million, $54 million and $37 million, respectively, were largely offset by decreases in the the average commercial and commercial real estate balances of $90 million and $47 million, respectively. The growth in residential, home equity line of credit and consumer loan portfolios aligned with ASB’s portfolio mix target and loan growth strategy. The decrease in commercial and commercial real estate loan portfolios was reflective of ASB’s strategic decision to reduce the balances in certain commercial and national loan portfolios to improve the credit quality of those portfolios. The yield on loans benefited from the rising interest rate environment, which resulted in an increase in yields of 18 basis points.
Noninterest income	27		31		(4		)	Noninterest income decreased for the six months ended June 30, 2018 compared to noninterest income for the six months ended June 30, 2017 primarily due to lower fees from other financial services in 2018 as a result of debit card interchange expenses being netted against income beginning in 2018. Prior year’s debit card interchange expenses were recorded in other noninterest expense. This change was in accordance with the new revenue recognition accounting standard. See Note 7 of the Condensed Consolidated Financial Statements for additional information on the new revenue recognition standard.
Revenues	152		148		4
Interest expense	7		6		1			Interest expense increased slightly for the six months ended June 30, 2018 compared to the same period in 2017 due to higher interest expense from the growth in time certificates, but was partially offset by lower interest expense on other borrowings as a result of lower FHLB advances. Average deposit balances for the six months ended June 30, 2018 increased by $331 million compared to the same period in 2017 due to an increase in core deposits and time certificates of $222 million and $109 million, respectively. Average other borrowings for the six months ended June 30, 2018 decreased by $29 million compared to the same period in 2017 due to a decrease in FHLB advances, partly offset by an increase in repurchase agreements. The interest-bearing liability rate for the six months ended June 30, 2018 increased by 4 basis points compared to the same period in 2017.
Provision for loan losses	6		7		(1		)	The provision for loan losses decreased slightly for the six months ended June 30, 2018 compared to the provision for loan losses for the six months ended June 30, 2017. The provision for loan losses for 2018 was primarily due to increased reserves for growth in the loan portfolio and additional loan loss reserves for the consumer loan portfolio, partly offset by the release of reserves for the commercial loan portfolio due to a recovery on a previously charged-off commercial loan and improved credit quality of the commercial loan portfolio. The provision for loan losses for 2017 was primarily due to increased loan loss reserves for the consumer loan portfolio and additional loan loss reserves for the commercial real estate loan portfolio due to the downgrade of a specific commercial real estate relationship. Delinquency rates have increased from 0.44% at June 30, 2017 to 0.54% at June 30, 2018. The annualized net charge-off ratio for the six months ended June 30, 2018 was 0.30% compared to an annualized net charge-off ratio of 0.25% for the same period in 2017.
Noninterest expense	87		86		1			The increase in noninterest expense for the six months ended June 30, 2018 compared to the same period in 2017 was primarily due to higher compensation and employee benefits expenses as a result of an increase in the minimum pay rate for employees, higher performance-based incentives and annual merit increases, and higher service expenses, partly offset by the reclassification of debit card interchange expenses in accordance with the new revenue recognition accounting standard.
Expenses	100		99		1
Operating income	52		49		3			The increase in operating income for the six months ended June 30, 2018 compared to the same period in 2017 was primarily due to higher interest income, partly offset by lower noninterest income and higher noninterest expenses.
Net income	40		33		7			The increase in net income for the six months ended June 30, 2018 compared to the same period in 2017 was primarily due to higher operating income and lower income tax expense as a result of the lower corporate rate from the Tax Act.

See Note 4 of the Condensed Consolidated Financial Statements and “Economic conditions” in the “HEI Consolidated” section above.

ASB continues to maintain its low-risk profile, strong balance sheet and straightforward community banking business model.

ASB’s return on average assets, return on average equity and net interest margin were as follows:



	Three months ended June 30		Six months ended June 30
(%)	2018	2017	2018	2017
Return on average assets	1.20	1.02	1.16	1.00
Return on average equity	13.56	11.25	13.07	11.04
Net interest margin	3.76	3.68	3.76	3.68



	Three months ended June 30
	2018						2017
(dollars in thousands)	Average balance			Interest¹ income/ expense		Yield/ rate (%)	Average balance			Interest¹income/ expense		Yield/ rate (%)
Assets:
Interest-earning deposits	$	53,677		$	240	1.77	$	46,507		$	121	1.03
FHLB stock	10,245			77		2.99	11,759			57		1.96
Investment securities
Taxable	1,485,780			8,182		2.20	1,267,945			6,481		2.04
Non-taxable	15,427			162		4.16	15,427			160		4.11
Total investment securities	1,501,207			8,344		2.22	1,283,372			6,641		2.07
Loans
Residential 1-4 family	2,119,594			21,581		4.07	2,070,450			22,163		4.28
Commercial real estate	879,748			9,959		4.49	917,019			9,722		4.21
Home equity line of credit	932,828			8,354		3.59	877,462			7,248		3.31
Residential land	16,525			223		5.41	16,111			217		5.38
Commercial	592,780			6,814		4.59	663,200			7,090		4.27
Consumer	234,178			7,702		13.19	202,914			5,877		11.62
Total loans ^2,3	4,775,653			54,633		4.57	4,747,156			52,317		4.40
Total interest-earning assets ²	6,340,782			63,294		3.99	6,088,794			59,136		3.88
Allowance for loan losses	(54,191		)				(56,715		)
Non-interest-earning assets	590,493						534,581
Total assets	$	6,877,084					$	6,566,660
Liabilities and shareholder’s equity:
Savings	$	2,343,928		$	411	0.07	$	2,274,832		$	386	0.07
Interest-bearing checking	1,030,309			208		0.08	908,864			59		0.03
Money market	125,961			73		0.23	146,962			45		0.12
Time certificates	766,148			2,592		1.36	679,866			1,821		1.07
Total interest-bearing deposits	4,266,346			3,284		0.31	4,010,524			2,311		0.23
Advances from Federal Home Loan Bank	52,176			254		1.95	101,335			788		3.08
Securities sold under agreements to repurchase	75,687			139		0.74	95,740			36		0.15
Total interest-bearing liabilities	4,394,209			3,677		0.34	4,207,599			3,135		0.30
Non-interest bearing liabilities:
Deposits	1,772,173						1,664,592
Other	103,991						99,710
Shareholder’s equity	606,711						594,759
Total liabilities and shareholder’s equity	$	6,877,084					$	6,566,660
Net interest income				$	59,617					$	56,001
Net interest margin (%) ⁴						3.76						3.68



	Six months ended June 30
	2018						2017
(dollars in thousands)	Average balance			Interest¹ income/ expense		Yield/ rate (%)	Average balance			Interest¹ income/ expense		Yield/ rate (%)
Assets:
Interest-earning deposits	$	55,078		$	456	1.65	$	69,421		$	307	0.88
FHLB stock	10,009			154		3.09	11,498			105		1.85
Investment securities
Taxable	1,477,468			16,973		2.30	1,206,272			13,130		2.18
Non-taxable	15,427			312		4.02	15,427			310		4.00
Total investment securities	1,492,895			17,285		2.32	1,221,699			13,440		2.20
Loans
Residential 1-4 family	2,124,429			43,428		4.09	2,071,931			43,789		4.23
Commercial real estate	866,689			19,210		4.42	913,940			19,134		4.18
Home equity line of credit	926,951			16,342		3.56	872,973			14,364		3.32
Residential land	16,485			446		5.41	17,057			495		5.80
Commercial	576,743			12,993		4.53	666,741			14,245		4.30
Consumer	232,519			15,014		13.02	195,158			11,032		11.40
Total loans ^2,3	4,743,816			107,433		4.54	4,737,800			103,059		4.36
Total interest-earning assets ²	6,301,798			125,328		3.99	6,040,418			116,911		3.88
Allowance for loan losses	(53,881		)				(56,477		)
Non-interest-earning assets	582,346						527,302
Total assets	$	6,830,263					$	6,511,243
Liabilities and shareholder’s equity:
Savings	$	2,327,596		$	812	0.07	$	2,261,549		$	760	0.07
Interest-bearing checking	982,096			282		0.06	897,346			114		0.03
Money market	119,830			99		0.17	151,293			92		0.12
Time certificates	779,796			5,048		1.31	670,717			3,448		1.04
Total interest-bearing deposits	4,209,318			6,241		0.30	3,980,905			4,414		0.22
Advances from Federal Home Loan Bank	51,647			499		1.95	100,671			1,563		3.09
Securities sold under agreements to repurchase	114,997			390		0.68	94,713			77		0.16
Total interest-bearing liabilities	4,375,962			7,130		0.33	4,176,289			6,054		0.29
Non-interest bearing liabilities:
Deposits	1,748,695						1,646,275
Other	100,892						98,875
Shareholder’s equity	604,714						589,804
Total liabilities and shareholder’s equity	$	6,830,263					$	6,511,243
Net interest income				$	118,198					$	110,857
Net interest margin (%) ⁴						3.76						3.68


¹	Interest income includes taxable equivalent basis adjustments, based upon a federal statutory tax rate of 21% and 35%, of $0.03 million and $0.06 million for the three months ended June 30, 2018 and 2017, respectively and $0.07 million and $0.1 million for the six months ended June 30, 2018 and 2017, respectively.

²Includes loans held for sale, at lower of cost or fair value.


³	Includes recognition of net deferred loan fees of $0.1 million and $0.6 million for the three months ended June 30, 2018 and 2017 and $0.1 million and $1.1 million for the six months ended June 30, 2018 and 2017, respectively, together with interest accrued prior to suspension of interest accrual on nonaccrual loans.


⁴	Defined as net interest income, on a fully taxable equivalent basis, as a percentage of average total interest-earning assets.

Earning assets, costing liabilities and other factors. Earnings of ASB depend primarily on net interest income, which is the difference between interest earned on earning assets and interest paid on costing liabilities. The interest rate environment has been impacted by disruptions in the financial markets over a period of several years. These conditions have begun to moderate with the interest rate increases in the past year, resulting in an increase in ASB’s net interest income and net interest margin.

Loan originations and mortgage-related securities are ASB’s primary earning assets.

Loan portfolio. ASB’s loan volumes and yields are affected by market interest rates, competition, demand for financing, availability of funds and management’s responses to these factors. See Note 4 of the Condensed Consolidated Financial Statements for the composition of ASB’s loans.

Home equity— key credit statistics. Attention has been given by regulators and rating agencies to the potential for increased exposure to credit losses associated with home equity lines of credit (HELOC) that were originated during the period of rapid home price appreciation between 2003 and 2007 as they have reached the end of their 10-year, interest only payment periods. Once the interest only payment period has ended, payments are reset to include principal repayments along with interest. ASB does not have a large exposure to HELOCs originated between 2003 and 2007. Nearly all of ASB’s HELOC originations prior to 2008 consisted of amortizing equity lines that have structured principal payments during the draw period. These older equity lines represent 1% of the HELOC portfolio and are included in the amortizing balances identified in the loan portfolio table below.



	June 30, 2018			December 31, 2017
Outstanding balance of home equity loans (in thousands)	$	938,902		$	913,052
Percent of portfolio in first lien position	48.4		%	48.0		%
Annualized net charge-off (recovery) ratio	0.03		%	(0.03		)%
Delinquency ratio	0.52		%	0.28		%



							End of draw period – interest only									Current
June 30, 2018	Total			Interest only			2018-2019			2020-2022			Thereafter			amortizing
Outstanding balance (in thousands)	$	938,902		$	720,008		$	39,223		$	105,070		$	575,715		$	218,894
% of total	100		%	77		%	4		%	11		%	62		%	23		%

The HELOC portfolio makes up 20% of the total loan portfolio and is generally an interest-only revolving loan for a 10-year period, after which time the HELOC outstanding balance converts to a fully amortizing variable rate term loan with a 20-year amortization period. This product type comprises 78% of the total HELOC portfolio and is the current product offering. Borrowers also have a “Fixed Rate Loan Option” to convert a part of their available line of credit into a 5, 7 or 10-year fully amortizing fixed rate loan with level principal and interest payments. As of June 30, 2018, approximately 21% of the portfolio balances were amortizing loans under the Fixed Rate Loan Option.

Loan portfolio risk elements. See Note 4 of the Condensed Consolidated Financial Statements.

Investment securities. ASB’s investment portfolio was comprised as follows:



	June 30, 2018				December 31, 2017
(dollars in thousands)	Balance		% of total		Balance		% of total
U.S. Treasury and federal agency obligations	$	175,933	12	%	$	184,298	13	%
Mortgage-related securities — FNMA, FHLMC and GNMA	1,240,462		84		1,245,988		86
Corporate bonds	40,336		3		—		—
Mortgage revenue bond	15,427		1		15,427		1
Total investment securities	$	1,472,158	100	%	$	1,445,713	100	%

Deposits and other borrowings. Deposits continue to be the largest source of funds for ASB and are affected by market interest rates, competition and management’s responses to these factors. Deposit retention and growth will remain challenging in the current environment due to competition for deposits and the low level of short-term interest rates. Advances from the FHLB of Des Moines and securities sold under agreements to repurchase continue to be additional sources of funds. As of June 30, 2018, ASB’s costing liabilities consisted of 98% deposits and 2% other borrowings compared to 97% deposits and 3% other borrowings as of December 31, 2017. During the first six months of 2018, ASB developed new deposit products that enabled approximately $102 million of retail repurchase agreements to be transferred to deposits. The weighted average cost of deposits for the first six months of 2018 and 2017 was 0.21% and 0.16%, respectively.

Federal Home Loan Bank of Des Moines. As of June 30, 2018 and December 31, 2017, ASB had $50 million of advances outstanding at the FHLB of Des Moines. As of June 30, 2018, the unused borrowing capacity with the FHLB of Des Moines was $2.0 billion. The FHLB of Des Moines continues to be an important source of liquidity for ASB.

Other factors. Interest rate risk is a significant risk of ASB’s operations and also represents a market risk factor affecting the fair value of ASB’s investment securities. Increases and decreases in prevailing interest rates generally translate into decreases and increases in the fair value of the investment securities, respectively. In addition, changes in credit spreads also impact the fair values of the investment securities.

As of June 30, 2018, ASB had an unrealized loss, net of taxes, on available-for-sale investment securities (including securities pledged for repurchase agreements) in AOCI of $32.6 million compared to an unrealized loss, net of taxes, of $15.0 million as of December 31, 2017. See “Item 3. Quantitative and qualitative disclosures about market risk” for a discussion of ASB’s interest rate risk sensitivity.

During the first six months of 2018, ASB recorded a provision for loan losses of $6.3 million primarily due to increased reserves for growth in the loan portfolio and additional loan loss reserves for the consumer loan portfolio, partly offset by the release of reserves for the commercial loan portfolio due to a recovery on a previously charged-off commercial loan and improved credit quality. During the first six months of 2017, ASB recorded a provision for loan losses of $6.7 million primarily due to increased loss reserves for the consumer loan portfolio and additional loss reserves for the commercial real estate loan portfolio due to the downgrade of a commercial real estate relationship. Financial stress on ASB’s customers may result in higher levels of delinquencies and losses.



	Six months ended June 30						Year ended December 31,
(in thousands)	2018			2017			2017
Allowance for loan losses, January 1	$	53,637		$	55,533		$	55,533
Provision for loan losses	6,304			6,741			10,901
Less: net charge-offs	7,138			5,918			12,797
Allowance for loan losses, end of period	$	52,803		$	56,356		$	53,637
Ratio of net charge-offs during the period to average loans outstanding (annualized)	0.30		%	0.25		%	0.27		%

ASB maintains a reserve for credit losses that consists of two components, the allowance for loan losses and a reserve for unfunded loan commitments (unfunded reserve). The level of the reserve for unfunded loan commitments is adjusted by recording an expense or recovery in other noninterest expense. As of June 30, 2018 and December 31, 2017, the reserve for unfunded loan commitments was $1.7 million.

Legislation and regulation. ASB is subject to extensive regulation, principally by the OCC and the FDIC. Depending on ASB’s level of regulatory capital and other considerations, these regulations could restrict the ability of ASB to compete with other institutions and to pay dividends to its shareholder. See the discussion below under “Liquidity and capital resources.”

Final Capital Rules. On July 2, 2013, the FRB finalized its rule implementing the Basel III regulatory capital framework. The final rule would apply to banking organizations of all sizes and types regulated by the FRB and the OCC, except bank holding companies subject to the FRB’s Small Bank Holding Company Policy Statement and Savings & Loan Holding Companies (SLHCs) substantially engaged in insurance underwriting or commercial activities. HEI currently meets the requirements of the exemption as a top-tier grandfathered unitary SLHC that derived, as of June 30 of the previous calendar year, either 50% or more of its total consolidated assets or 50% or more of its total revenues on an enterprise-wide basis (calculated under GAAP) from activities that are not financial in nature pursuant to Section 4(k) of the Bank Holding Company Act. The FRB is temporarily excluding these SLHCs from the final rule while it considers a proposal relating to capital and other requirements for SLHC intermediate holding companies (such as ASB Hawaii). The FRB indicated that it would release a proposal on intermediate holding companies that would specify the criteria for establishing and transferring activities to intermediate holding companies and propose to apply the FRB’s capital requirements to such intermediate holding companies. The FRB has not yet issued such a proposal, or a proposal on how to apply the Basel III capital rules to SLHCs that are substantially engaged in commercial or insurance underwriting activities, such as grandfathered unitary SLHCs like HEI.

buffer). In addition, a countercyclical capital buffer would expand the capital conservation buffer by up to 2.5% of a banking organization’s total risk-weighted assets for advanced approaches banking organizations. The final rule would establish qualification criteria for common equity, additional tier 1 and tier 2 capital instruments that help to ensure their ability to absorb losses. All banking organizations would be required to calculate risk-weighted assets under the standardized approach, which harmonizes the banking agencies’ calculation of risk-weighted assets and addresses shortcomings in capital requirements identified by the agencies. The phased-in effective dates of the capital requirements under the final rule are:

Minimum Capital Requirements



Effective dates	1/1/2015		1/1/2016		1/1/2017		1/1/2018		1/1/2019
Capital conservation buffer			0.625	%	1.25	%	1.875	%	2.50	%
Common equity Tier-1 ratio + conservation buffer	4.50	%	5.125	%	5.75	%	6.375	%	7.00	%
Tier-1 capital ratio + conservation buffer	6.00	%	6.625	%	7.25	%	7.875	%	8.50	%
Total capital ratio + conservation buffer	8.00	%	8.625	%	9.25	%	9.875	%	10.50	%
Tier-1 leverage ratio	4.00	%	4.00	%	4.00	%	4.00	%	4.00	%
Countercyclical capital buffer — not applicable to ASB			0.625	%	1.25	%	1.875	%	2.50	%

The final rule was effective January 1, 2015 for ASB and as of June 30, 2018, ASB met the new capital requirements (see “Financial Condition” for a summary of ASB’s capital ratios).

Overtime Rules. The Secretary of Labor updated the overtime regulations of the Fair Labor Standards Act to simplify and modernize them. The Department of Labor issued final rules that will raise the salary threshold indicating eligibility from $455/week to $913/week ($47,476 per year), and update automatically the salary threshold every three years, based on wage growth over time, increasing predictability. The final rule was to become effective on December 1, 2016. In late-November 2016 however, the U.S. District Court in the Eastern District of Texas granted a nationwide preliminary injunction that blocked the final rule, saying the Department of Labor's rule exceeds the authority the agency was delegated by Congress. Despite this block, ASB modified its salaries in the fourth quarter of 2016 such that it is in voluntary compliance with the final rule. On July 26, 2017, the Department of Labor published a Request for Information Defining and Delimiting the Exemptions for Executive, Administrative, Professional, Outside Sales and Computer Employees. On August 31, 2017, U.S. District Court in the Eastern District of Texas granted summary judgment against the Department of Labor in consolidated cases challenging the final rule published on May 23, 2016. The court held that the final rule’s salary level exceeded the Department of Labor’s authority and concluded that the final rule was invalid. The Department of Labor is undertaking rulemaking to revise the regulation.

Arbitration Agreements. Pursuant to section 1028(b) of the Dodd-Frank Act, on July 19, 2017, the Bureau issued a final rule to regulate arbitration agreements in contracts for specified consumer financial product and services. First, the final rule prohibits covered providers of certain consumer financial products and services from using an agreement with a consumer that provides for arbitration of any future dispute between the parties to bar the consumer from filing or participating in a class action concerning the covered consumer financial product or service. Second, the final rule requires covered providers that are involved in arbitration pursuant to a pre-dispute arbitration agreement to submit specified arbitral records to the Bureau and also to submit specified court records. The compliance date for this regulation was March 19, 2018. Under the Congressional Review Act, the U.S. House of Representatives voted to overturn the final rule on July 25, 2017, and the U.S. Senate did the same on October 24, 2017. On November 1, 2017, the President signed the repeal of the final rule. In light of these developments, ASB did not modify its existing agreements.

Expedited Funds Availability Act of 1987 (EFA Act) and the Check Clearing for the 21st Century Act of 2003 (Check 21 Act). The Board of Governors of the Federal Reserve System amended Regulation CC, Availability of Funds and Collection of Checks, which implements EFA Act and Check 21 Act effective July 1, 2018. The Board of Governors modified the current check collection and returns requirement to reflect the virtually all-electronic check collection and return environment and to encourage all depository banks to receive, and paying banks to send, returned checks electronically. The Board of Governors applied Regulation CC’s existing check warranties to checks that are collected electronically, and adopted new warranties and indemnities related to checks collected and returned electronically and to electronically-created items.

on properties most likely to be impacted by the path of the lava flow. None of the bank’s branches have been damaged by the lava flow and the bank has limited exposure to residential loan losses due to its decision in 2014 to cease originations in the designated lava zone areas. The bank has one commercial real estate loan and four commercial loans with businesses located in Pahoa, near the Puna district, but outside of the current risk area. Although the lava eruption continues and is unpredictable, the financial impact to the bank, to date, has not been material.

FINANCIAL CONDITION

Liquidity and capital resources.


(dollars in millions)	June 30, 2017		December 31, 2016		% change		June 30, 2018		December 31, 2017		% change
Total assets	$	6,611	$	6,421	3		$	6,984	$	6,799	3
Available-for-sale investment securities	1,303		1,105		18
Loans receivable held for investment, net	4,688		4,683		—
Investment securities							1,416		1,446		(2	)
Loans held for investment, net							4,722		4,617		2
Deposit liabilities	5,724		5,549		3		6,116		5,891		4
Other bank borrowings	188		193		(3	)	127		191		(34	)

As of June 30, ~~2017~~,2018, ASB was one of Hawaii’s largest financial institutions based on assets of ~~$6.6~~$7.0 billion and deposits of ~~$5.7~~$6.1 billion.

As of June 30, ~~2017~~2018, ASB’s unused FHLB borrowing capacity was approximately ~~$1.8~~$2.0 billion. As of June 30, ~~2017~~2018, ASB had commitments to borrowers for loans and unused lines and letters of credit of $1.8 ~~billion. As~~billion, of ~~June 30, 2017, the Company did not have~~which commitments ~~to lend~~ to borrowers whose loan terms have been modified in troubled debt ~~restructurings.~~restructurings were $0.01 million. Management believes ASB’s current sources of funds will enable it to meet these obligations while maintaining liquidity at satisfactory levels.

For the six months ended June 30, 2018, net cash provided by ASB’s operating activities was $45 million. Net cash used during the same period by ASB’s investing activities was $190 million, primarily due to purchases of available-for-sale investment securities of $134 million, a net increase in loans of $112 million, additions to premises and equipment of $40 million, and purchases of held-to-maturity investment securities of $20 million, partly offset by receipt of repayments from available-for-sale investment securities of $108 million, and proceeds from the sale of commercial loans of $7 million. Net cash provided by financing activities during this period was $140 million, primarily due to increases in deposit liabilities of $123 million, proceeds from FHLB advances of $177 million, and a net increase in retail repurchase agreements of $38 million, partly offset by principal payments on FHLB advances of $177 million, and $22 million in common stock dividends to HEI (through ASB Hawaii).

For the six months ended June 30, 2017, net cash provided by ASB’s operating activities was $46 million. Net cash used during the same period by ASB’s investing activities was $221 million, primarily due to purchases of investment securities of $296 million, a net increase in loans receivable of $20 million and additions to premises and equipment of $20 million, partly offset by receipt of repayments from investment securities of $100 million, proceeds from the sale of commercial loans of $13 million and a decrease in restricted cash of $2 million. Net cash provided by financing activities during this period was $152 million, primarily due to increases in deposit liabilities of $175 million and a net increase in retail repurchase agreements of $9 million, partly offset by repayments of securities sold under agreements to repurchase of $14 million and $19 million in common stock dividends to HEI (through ASB Hawaii).

For the six months ended June 30, 2016, net cash provided by ASB’s operating activities was $25 million. Net cash used during the same period by ASB’s investing activities was $205 million, primarily due to purchases of investment securities of $177 million, a net increase in loans receivable of $156 million and additions to premises and equipment of $6 million, partly offset by receipt of repayments and calls of investment securities of $103 million, proceeds from the sale of investment securities of $16 million and proceeds from the sale of commercial loans of $14 million. Net cash provided by financing activities during this period was $134 million, primarily due to increases in deposit liabilities of $207 million, partly offset by a net decrease in retail repurchase agreements of $27 million, maturities of securities sold under agreements to repurchase of $29 million and $18 million in common stock dividends to HEI (through ASB Hawaii).

ASB believes that maintaining a satisfactory regulatory capital position provides a basis for public confidence, affords protection to depositors, helps to ensure continued access to capital markets on favorable terms and provides a foundation for growth. FDIC regulations restrict the ability of financial institutions that are not well-capitalized to compete on the same terms as well-capitalized institutions, such as by offering interest rates on deposits that are significantly higher than the rates offered by competing institutions. As of June 30, ~~2017~~2018, ASB was well-capitalized (minimum ratio requirements noted in parentheses) with a Common equity Tier-1 ratio of ~~12.4%~~12.7% (6.5%), a Tier-1 capital ratio of ~~12.4%~~12.7% (8.0%), a Total capital ratio of ~~13.7%~~13.9% (10.0%) and a Tier-1 leverage ratio of ~~8.5%~~8.6% (5.0%). As of December 31, ~~2016,~~2017, ASB was well-capitalized with a common equity Tier-1 ratio of ~~12.2%~~13.0%, Tier-1 capital ratio of ~~12.2%~~13.0%, a Total capital ratio of ~~13.4%~~14.2% and a Tier-1 leverage ratio of 8.6%. All dividends are subject to review by the OCC and FRB and receipt of a letter from the FRB communicating the agencies’ non-objection to the payment of any dividend ASB proposes to declare and pay to HEI (through ASB Hawaii).

Item 3. Quantitative and Qualitative Disclosures About Market Risk

The Company considers interest-rate risk (a non-trading market risk) to be a very significant market risk for ASB as it could potentially have a significant effect on the Company’s results of operations, financial condition and liquidity. For additional quantitative and qualitative information about the Company’s market risks, see HEI’s and Hawaiian Electric’s Quantitative and Qualitative Disclosures About Market Risk in Part II, Item 7A of HEI’s ~~2016~~2017 Form 10-K (pages 7980 to ~~81)~~82).

ASB’s interest-rate risk sensitivity measures as of June 30, ~~2017~~2018 and December 31, ~~2016~~2017 constitute “forward-looking statements” and were as follows:


Change in interest rates	Change in NII (gradual change in interest rates)				Change in EVE (instantaneous change in interest rates)				Change in NII (gradual change in interest rates)				Change in EVE (instantaneous change in interest rates)
(basis points)	June 30, 2017		December 31, 2016		June 30, 2017		December 31, 2016		June 30, 2018		December 31, 2017		June 30, 2018		December 31, 2017
+300	2.6	%	1.9	%	(7.6	)%	(8.0	)%	2.2	%	3.0	%	(8.9	)%	(8.0	)%
+200	1.7		0.8		(4.1	)	(4.6	)	1.7		2.4		(5.3	)	(4.0	)
+100	0.8		—		(1.1	)	(1.6	)	1.1		1.6		(1.9	)	(0.6	)
-100	(1.4	)	(0.5	)	(3.5	)	(1.6	)	(2.6	)	(2.7	)	(2.5	)	(6.0	)

~~Management believes that ASB’s interest rate risk position as of June 30, 2017 represents a reasonable level of risk.~~ The NII profile under the rising interest rate risk scenarios was ~~more~~less asset sensitive for all rate increases as of June 30, ~~2017~~2018 compared to December 31, ~~2016. Interest income increased due to~~2017. NII asset sensitivity has been slowly decreasing as rising rates have slowed prepayment expectations, reducing the ~~growth~~amount of the fixed-rate mortgage and mortgage-backed investment ~~portfolio and higher income from the commercial and HELOC loan~~ portfolios ~~due~~available to ~~an increase~~reprice in the ~~short-term LIBOR and prime rates.~~rising rate scenarios. In addition, the ~~repricing assumptions~~fixed-rate portion of ~~certain commercial loans were updated, which resulted~~the HELOC portfolio grew, further reducing the amount available to reprice in ~~a net increase in NII.~~rising rate scenarios.

ASB’s base EVE increased to ~~$1.12~~$1.22 billion as of June 30, ~~2017,~~2018, compared to ~~$1.09~~$1.18 billion as of December 31, ~~2016,~~2017, due to the growth and mix of the balance sheet. The growth of the investment ~~portfolio was~~and loan portfolios were funded with the increase in core deposits. ~~The upward shift in short term rates resulted in the market valuation of assets exceeding the valuation of liabilities.~~

EVE sensitivity to rising rates ~~declined~~increased as of June 30, ~~2017~~2018 compared to December 31, ~~2016.~~2017. During the first ~~half~~six months of the year, market rates increased, slowing prepayments and extending duration in the ~~purchase of intermediate-termed duration~~residential loan and mortgage-backed investment ~~securities was funded by longer duration core deposits, resulting in a net decrease in EVE sensitivity.~~portfolios.

The computation of the prospective effects of hypothetical interest rate changes on the NII sensitivity and the percentage change in EVE is based on numerous assumptions, including relative levels of market interest rates, loan prepayments, balance changes and pricing strategies, and should not be relied upon as indicative of actual results. To the extent market conditions and other factors vary from the assumptions used in the simulation analysis, actual results may differ materially from the simulation results. Furthermore, NII sensitivity analysis measures the change in ASB’s twelve-month, pretax NII in alternate interest rate scenarios, and is intended to help management identify potential exposures in ASB’s current balance sheet and formulate appropriate strategies for managing interest rate risk. The simulation does not contemplate any actions that ASB management might undertake in response to changes in interest rates. Further, the changes in NII vary in the twelve-month simulation period and are not necessarily evenly distributed over the period. These analyses are for analytical purposes only and do not represent management’s views of future market movements, the level of future earnings or the timing of any changes in earnings within the twelve month analysis horizon. The actual impact of changes in interest rates on NII will depend on the magnitude and speed with which rates change, actual changes in ASB’s balance sheet and management’s responses to the changes in interest rates.

Item 4. Controls and Procedures

HEI:

Disclosure Controls and Procedures

The Company maintains a set of disclosure controls and procedures designed to provide reasonable assurance that information required to be disclosed by the Company in reports that it files or submits under the Securities Exchange Act of 1934, as amended (Exchange Act), is recorded, processed, summarized and reported within the time periods specified in SEC’s rules and forms, and that such information is accumulated and communicated to the Company’s management, including its Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

An evaluation was performed under the supervision and with the participation of the Company’s management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures, as defined in Rule 13a-15(e) or Rule 15d-15(e) of the Exchange Act. Management, including the Company’s Chief Executive Officer and Chief Financial Officer, concluded that the Company’s disclosure controls and procedures were effective, as of the end of the period covered by ~~the~~this report, at the reasonable assurance level.

Changes in Internal Control Over Financial Reporting

There have been no changes in internal control over financial reporting during the second quarter of ~~2017~~2018 that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

Hawaiian Electric:

Disclosure Controls and Procedures

Hawaiian Electric maintains a set of disclosure controls and procedures designed to provide reasonable assurance that information required to be disclosed by Hawaiian Electric in reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in SEC’s rules and forms, and that such information is accumulated and communicated to Hawaiian Electric’s management, including its Chief Executive Officer and Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.

An evaluation was performed under the supervision and with the participation of Hawaiian Electric’s management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of Hawaiian Electric’s disclosure controls and procedures, as defined in Rule 13a-15(e) or Rule 15d-15(e) of the Exchange Act. Management, including Hawaiian Electric’s Chief Executive Officer and Chief Financial Officer, concluded that Hawaiian Electric’s disclosure controls and procedures were effective, as of the end of the period covered by ~~the~~this report, at the reasonable assurance level.

Changes in Internal Control Over Financial Reporting

There have been no changes in internal control over financial reporting during the second quarter of ~~2017~~2018 that have materially affected, or are reasonably likely to materially affect, Hawaiian Electric’s internal control over financial reporting.

PART II - OTHER INFORMATION

Item 1. Legal Proceedings

The descriptions of legal proceedings (including judicial proceedings and proceedings before the PUC and environmental and other administrative agencies) in HEI’s and Hawaiian Electric’s ~~2016~~2017 Form 10-K (see “Part I. Item 3. Legal Proceedings” and proceedings referred to therein) and this Form 10-Q (see “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and Notes 3 and 4 of the Condensed Consolidated Financial Statements) are incorporated by reference in this Item 1. With regard to any pending legal proceeding, alternative dispute resolution, such as mediation or settlement, may be pursued where appropriate, with such efforts typically maintained in confidence unless and until a resolution is achieved. Certain HEI subsidiaries (including Hawaiian Electric and its subsidiaries, ASB and ~~ASB)~~Pacific Current and its subsidiaries) may also be involved in ordinary routine PUC proceedings, environmental proceedings and litigation incidental to their respective businesses.

Item 1A. Risk Factors

For information about Risk Factors, see pages 2526 to 3537 of HEI’s and Hawaiian Electric’s ~~2016~~2017 Form 10-K and “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” “Quantitative and Qualitative

Disclosures about Market Risk” and the Condensed Consolidated Financial Statements herein. Also, see “Cautionary Note Regarding Forward-Looking Statements” on pages iv and v herein.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

(c) Purchases of HEI common shares were made on the open market during the second quarter of 2018 to satisfy the requirements of certain plans as follows:

ISSUER PURCHASES OF EQUITY SECURITIES

Period*

Total Number of Shares Purchased **

Average
Price Paid
per Share **
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
April 1 to 30, 2017 39,114
$33.51 — NA
May 1 to 31, 2017 33,303
$32.87 — NA
June 1 to 30, 2017 193,655
$33.64 — NA



Period*	Total Number of Shares Purchased **	Average Price Paid per Share **	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs	Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
April 1 to 30, 2018	25,870	$34.64	—	NA
May 1 to 31, 2018	28,287	$33.91	—	NA
June 1 to 30, 2018	198,215	$33.01	—	NA

NA Not applicable.

* Trades (total number of shares purchased) are reflected in the month in which the order is placed.

** The purchases were made to satisfy the requirements of the DRIP, the HEIRSP and the ASB 401(k) Plan for shares purchased for cash or by the reinvestment of dividends by participants under those plans and none of the purchases were made under publicly announced repurchase plans or programs. Average prices per share are calculated exclusive of any commissions payable to the brokers making the purchases for the DRIP, the HEIRSP and the ASB 401(k) Plan. Of the “Total number of shares purchased,” all of the ~~39,114~~25,870 shares, ~~23,773~~24,187 of the ~~33,303~~28,287 shares and ~~168,855~~171,915 of the ~~193,655~~198,215 shares were purchased for the DRIP; none of the ~~39,114~~25,870 shares, ~~8,800~~4,100 of the ~~33,303~~28,287 shares and ~~21,300~~23,100 of the ~~193,655~~198,215 shares were purchased for the HEIRSP; and the remainder was purchased for the ASB 401(k) Plan. The repurchased shares were issued for the accounts of the participants under registration statements registering the shares issued under these plans.

Item 5. Other Information

A. Ratio of earnings to fixed charges.


	Six months ended June 30		Years ended December 31					Six months ended June 30		Years ended December 31
	2017	2016	2016	2015	2014	2013	2012	2018	2017	2017	2016	2015	2014	2013
HEI and Subsidiaries
Excluding interest on ASB deposits	3.31	3.64	5.05	3.68	3.80	3.55	3.30	3.18	3.31	3.93	5.05	3.68	3.80	3.55
Including interest on ASB deposits	3.11	3.46	4.75	3.54	3.65	3.42	3.15	2.94	3.11	3.65	4.75	3.54	3.65	3.42
Hawaiian Electric and Subsidiaries	2.90	3.76	4.11	3.97	4.04	3.72	3.37	2.88	2.90	3.64	4.11	3.97	4.04	3.72

See HEI Exhibit 12.1 and Hawaiian Electric Exhibit 12.2.

Item 6. Exhibits



~~HEI Exhibit.10.1~~		~~Second Amended~~
HEI Exhibit 4		Third Amendment effective July 1, 2018 to Master Trust Agreement (dated September 4, 2012) between HEI and ~~Restated Credit Agreement, dated as of June 30, 2017, among HEI, as Borrower, the Lenders Party Thereto~~ASB and Wells Fargo Bank, National Association, as Syndication Agent, and Bank of America, N.A., MUFG Union Bank, N.A., Barclays Bank PLC, U.S. Bank National Association and Bank of Hawaii as Co-Documentation Agents, and JPMorgan Chase Bank, N.A., as Administrative Agent, Swingline Lender and Issuing Bank, and JPMorgan Chase Bank, N.A. and Wells Fargo Securities, LLC, as Joint Lead Arrangers and Joint Book RunnersFidelity Management Trust Company.

HEI Exhibit 10		Amended and Restated Severance Pay Plan for Management Employees of Hawaiian Electric Industries, Inc. and Executive Employees of Affiliates, effective as of April 2, 2018.

HEI Exhibit 12.1		Hawaiian Electric Industries, Inc. and Subsidiaries Computation of ratio of earnings to fixed charges, six months ended June 30, ~~2017~~2018 and ~~2016~~2017 and years ended December 31, 2017, 2016, 2015, 2014 ~~2013~~ and ~~2012~~2013

HEI Exhibit 31.1		Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Constance H. Lau (HEI Chief Executive Officer)

HEI Exhibit 31.2		Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Gregory C. Hazelton (HEI Chief Financial Officer)

HEI Exhibit 32.1		HEI Certification Pursuant to 18 U.S.C. Section 1350

HEI Exhibit 101.INS		XBRL Instance Document

HEI Exhibit 101.SCH		XBRL Taxonomy Extension Schema Document

HEI Exhibit 101.CAL		XBRL Taxonomy Extension Calculation Linkbase Document

HEI Exhibit 101.DEF		XBRL Taxonomy Extension Definition Linkbase Document

HEI Exhibit 101.LAB		XBRL Taxonomy Extension Label Linkbase Document

HEI Exhibit 101.PRE		XBRL Taxonomy Extension Presentation Linkbase Document

~~Hawaiian Electric Exhibit 2~~		~~Termination Agreement, dated July 14, 2017, by and among Hamakua Energy Partners, L.P. and Hamakua Land Partnership, L.L.P. and Hawaii Electric Light Company, Inc.~~

~~Hawaiian Electric Exhibit 10.2~~		Second Amended and Restated Credit Agreement, dated as of June 30, 2017, among Hawaiian Electric Company, Inc., as Borrower, the Lenders Party Hereto and Wells Fargo Bank, National Association, as Syndication Agent, and Bank of America, N.A., MUFG Union Bank, N.A., Barclays Bank PLC, U.S. Bank National Association and Bank of Hawaii as Co-Documentation Agents, and JPMorgan Chase Bank, N.A., as Administrative Agent, Swingline Lender and Issuing Bank, and JPMorgan Chase Bank, N.A. and Wells Fargo Securities, LLC, as Joint Lead Arrangers and Joint Book Runners

Hawaiian Electric Exhibit 12.2		Hawaiian Electric Company, Inc. and Subsidiaries Computation of ratio of earnings to fixed charges, six months ended June 30, ~~2017~~2018 and ~~2016~~2017 and years ended December 31, 2017, 2016, 2015, 2014 ~~2013~~ and ~~2012~~2013

Hawaiian Electric Exhibit 31.3		Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Alan M. Oshima (Hawaiian Electric Chief Executive Officer)

Hawaiian Electric Exhibit 31.4		Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Tayne S. Y. Sekimura (Hawaiian Electric Chief Financial Officer)

Hawaiian Electric Exhibit 32.2		Hawaiian Electric Certification Pursuant to 18 U.S.C. Section 1350

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized. The signature of the undersigned companies shall be deemed to relate only to matters having reference to such companies and any subsidiaries thereof.



HAWAIIAN ELECTRIC INDUSTRIES, INC.		HAWAIIAN ELECTRIC COMPANY, INC.
(Registrant)		(Registrant)


By	/s/ Constance H. Lau	By	/s/ Alan M. Oshima
	Constance H. Lau		Alan M. Oshima
	President and Chief Executive Officer		President and Chief Executive Officer
	(Principal Executive Officer of HEI)		(Principal Executive Officer of Hawaiian Electric)


By	/s/ Gregory C. Hazelton	By	/s/ Tayne S. Y. Sekimura
	Gregory C. Hazelton		Tayne S. Y. Sekimura
	Executive Vice President and		Senior Vice President
	Chief Financial Officer		and Chief Financial Officer
	(Principal Financial ~~and Accounting~~Officer of HEI)		(Principal Financial Officer of Hawaiian Electric)
	~~Officer of HEI)~~


Date: August 3, ~~2017~~2018		Date: August 3, ~~2017~~2018

8890



	Refunding Series 2007B Special Purpose Revenue Bonds	Series 2007A Special Purpose Revenue Bonds
Aggregate principal amount	$125 million	$140 million
Fixed coupon interest rate	4.60%	4.65%
Maturity date	May 1, 2026	March 1, 2037



%	Return on rate base (RORB)*						ROACE**						Rate-making ROACE***
Twelve months ended June 30, 2017	Hawaiian Electric		Hawaii Electric Light		Maui Electric		Hawaiian Electric		Hawaii Electric Light		Maui Electric		Hawaiian Electric		Hawaii Electric Light		Maui Electric
Utility returns	6.77		6.71		6.83		7.25		6.91		7.50		7.99		7.54		7.96
PUC-allowed returns	8.11		8.31		7.34		10.00		10.00		9.00		10.00		10.00		9.00
Difference	(1.34	)	(1.60	)	(0.51	)	(2.75	)	(3.09	)	(1.50	)	(2.01	)	(2.46	)	(1.04	)



	Three months ended June 30		Six months ended June 30
(percent)	2017	2016	2017	2016
Return on average assets	1.02	0.86	1.00	0.85
Return on average equity	11.25	9.22	11.04	9.06
Net interest margin	3.68	3.58	3.68	3.60