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 March 31,June 30, 2014
 OR
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’sRegistrant��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 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
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
 
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
 
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 April 30,July 31, 2014
Hawaiian Electric Industries, Inc. (Without Par Value)  101,477,616102,560,176 Shares
Hawaiian Electric Company, Inc. ($6-2/3 Par Value) 15,429,105 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 March 31,June 30, 2014
 
TABLE OF CONTENTS
 
Page No.  
ii
 
Glossary of Terms
iv
 
Forward-Looking Statements
   
  
PART I. FINANCIAL INFORMATION
1
 
Item 1.
Financial Statements
    
   
Hawaiian Electric Industries, Inc. and Subsidiaries
1
  
Consolidated Statements of Income -
three and six months ended March 31,June 30, 2014 and 2013
2013
2
  
Consolidated Statements of Comprehensive Income -
three and six months ended March 31,June 30, 2014 and 2013
2013
3
  
Consolidated Balance Sheets - March 31,June 30, 2014 and December 31, 2013
2013
4
  
Consolidated Statements of Changes in Shareholders’ Equity -
threesix months ended March 31,June 30, 2014 and 2013
2013
5
  
Consolidated Statements of Cash Flows -
threesix months ended March 31,June 30, 2014 and 2013
2013
   
Hawaiian Electric Company, Inc. and Subsidiaries
6
  
Consolidated Statements of Income -
three and six months ended March 31,June 30, 2014 and 2013
2013
6
  
Consolidated Statements of Comprehensive Income -
three and six months ended March 31,June 30, 2014 and 2013
2013
7
  
Consolidated Balance Sheets - March 31,June 30, 2014 and December 31, 2013
2013
8
  
Consolidated Statements of Changes in Common Stock Equity -
threesix months ended March 31,June 30, 2014 and 2013
2013
9
  
Consolidated Statements of Cash Flows -
threesix months ended March 31,June 30, 2014 and 2013
2013
10
  
Notes to Consolidated Financial Statements
5056
 
Item 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
5056
  
HEI consolidated
5461
  
Electric Utilities
6371
  
Bank
6979
 
Item 3.
Quantitative and Qualitative Disclosures About Market Risk
7080
 
Item 4.
Controls and Procedures
   
  
PART II.
OTHER INFORMATION
7181
 
Item 1.
Legal Proceedings
7181
 
Item 1A.
Risk Factors
7181
 Item 2Unregistered Sales of Equity Securities and Use of Proceeds
7181
 
Item 5.
Other Information
7282
 
Item 6.
Exhibits
7383
 
Signatures
 

i


Hawaiian Electric Industries, Inc. and Subsidiaries
Hawaiian Electric Company, Inc. and Subsidiaries
Form 10-Q—Quarter ended March 31,June 30, 2014
 
GLOSSARY OF TERMS
 
Terms Definitions
AFTAPAdjusted Funding Target Attainment Percentage
AFUDC Allowance for funds used during construction
AOCI Accumulated other comprehensive income/(loss)
ARO Asset retirement obligation
ASB American Savings Bank, F.S.B., a wholly-owned subsidiary of American Savings Holdings, Inc.
ASHI 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
CIP CT-1 Campbell Industrial Park 110 MW combustion turbine No. 1
CIS Customer Information System
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); American Savings Holdings, Inc. and its subsidiary, American Savings Bank, F.S.B.; HEI Properties, Inc.; Hawaiian Electric Industries Capital Trust II and Hawaiian Electric Industries Capital Trust III (inactive financing entities); and The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.).
Consumer Advocate Division of Consumer Advocacy, Department of Commerce and Consumer Affairs of the State of Hawaii
DBEDT State of Hawaii Department of Business, Economic Development and Tourism
D&O Decision and order
Dodd-Frank Act Dodd-Frank Wall Street Reform and Consumer Protection Act
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 clauses
EIP 2010 Equity and Incentive Plan
EGU Electrical generating unit
Energy Agreement Agreement dated October 20, 2008 and signed by the Governor of the State of Hawaii, the State of Hawaii Department of Business, Economic Development and Tourism, the Division of Consumer Advocacy of the Department of Commerce and Consumer Affairs, and Hawaiian Electric, for itself and on behalf of its electric utility subsidiaries committing to actions to develop renewable energy and reduce dependence on fossil fuels in support of the HCEI
EPA Environmental Protection Agency — federal
EPS Earnings per share
ERISAEmployee Retirement Income Security Act of 1974, as amended
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
 

ii
GLOSSARY OF TERMS, continued

Terms Definitions
GAAP Accounting principles generally accepted in the United States of America
GHG Greenhouse gas
GNMA Government National Mortgage Association
HCEI Hawaii Clean Energy Initiative
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.
Hawaii Electric LightHawaii Electric Light Company, Inc., an electric utility subsidiary of Hawaiian Electric Company, Inc.
HEI Hawaiian Electric Industries, Inc., direct parent company of Hawaiian Electric Company, Inc., American Savings Holdings, Inc., HEI Properties, Inc., Hawaiian Electric Industries Capital Trust II, Hawaiian Electric Industries Capital Trust III and The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.)
HEIRSP Hawaiian Electric Industries Retirement Savings Plan
Hawaii Electric LightHELOC Hawaii Electric Light Company, Inc., an electric utility subsidiaryHome equity line of Hawaiian Electric Company, Inc.credit
HPOWER City and County of Honolulu with respect to a power purchase agreement for a refuse-fired plant
IPP Independent power producer
IRP Integrated resource planning
Kalaeloa Kalaeloa Partners, L.P.
KW Kilowatt
KWH Kilowatthour
LTIP Long-term incentive plan
MAP-21LGD 
Moving Ahead for Progress in the 21st Century Act
Loss given default
Maui Electric Maui Electric Company, Limited, an electric utility subsidiary of Hawaiian Electric Company, Inc.
MW Megawatt/s (as applicable)
NAAQSNational Ambient Air Quality Standard
NII Net interest income
NQSONonqualified stock option
O&M Other operation and maintenance
OCC Office of the Comptroller of the Currency
OPEB Postretirement benefits other than pensions
PPA Power purchase agreement
PPAC Purchased power adjustment clause
PUC Public Utilities Commission of the State of Hawaii
RAM Revenue adjustment mechanism
RBA Revenue balancing account
RFP Request for proposals
REIP Renewable Energy Infrastructure Program
ROACE Return on average common equity
RORB Return on average rate base
RPS Renewable portfolio standard
SAR Stock appreciation right
SEC Securities and Exchange Commission
See Means the referenced material is incorporated by reference
SOIP1987 Stock Option and Incentive Plan, as amended
TDR Troubled debt restructuring
Trust IIIHECO Capital Trust III
Utilities 
Hawaiian Electric Company, Inc., Hawaii Electric Light Company, Inc. and Maui Electric Company, Limited

VIE Variable interest entity
 

iii


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 “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 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 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 American Savings Bank, F.S.B. (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, unrest, ongoing conflicts in North Africa and the Middle East, terrorist acts, potential conflict or crisis with North Korea or Iran, and developments in the Ukraine);
the effects of future actions or inaction of the U.S. government or related agencies, including those related to the U.S. debt ceiling and monetary policy;
weather and natural disasters (e.g., hurricanes, earthquakes, tsunamis, lightning strikes 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, 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 implementation of the Energy Agreement with the State of Hawaii and Consumer Advocate (Energy Agreement), setting forth the goals and objectives of a Hawaii Clean Energy Initiative (HCEI), and the fulfillment by the Utilities of their commitments under the Energy Agreement (given the Public Utilities Commission of the State of Hawaii (PUC) approvals needed; the PUC’s potential delay in considering (and potential disapproval of actual or proposed) HCEI-related costs; reliance by the Utilities on outside parties such as the state, independent power producers (IPPs) and developers; potential changes in political support for the HCEI; and uncertainties surrounding wind power, proposed undersea cables, biofuels, environmental assessments and the impacts of implementation of the HCEI on future costs of electricity);
the ability of the Utilities to develop, implement and recover the costs of implementing the Utilities’ action plans and business model changes that are being developed in response to the four orders that the PUC issued in April 2014, in which the PUC: directed the Utilities to develop, among other things, Power Supply Improvement Plans, a Demand Response Portfolio Plan and a Distributed Generation Interconnection Plan; described the PUC’s 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 emphasized the need to “leap ahead” of other states in creating a 21st century generation system and modern transmission and distribution grids;
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, 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 of other cost recovery mechanisms, including the purchased power adjustment clauses (PPACs), revenue 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 impact of fuel price volatility on customer satisfaction and political and regulatory support for the Utilities;

iv



the risks associated with increasing reliance on renewable energy, as contemplated under the Energy Agreement, 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 ability of the electric utilitiesUtilities 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 HEI, ASB and Hawaiian Electric and their subsidiariesthe Utilities or their competitors;
cyber security risks and the potential for cyber incidents, including potential incidents at HEI, ASB and Hawaiian Electric and their subsidiariesthe Utilities (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;
federal, state, county and international governmental and regulatory actions, such as existing, new and changes in laws, rules and regulations applicable to HEI, Hawaiian Electric,the Utilities and ASB and their subsidiaries (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 (GHG) 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 renewable portfolio standards (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 electric utilitiesUtilities to recover increasing costs and earn a reasonable return on capital investments not covered by revenue adjustment mechanisms;
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, Hawaiian Electric,the Utilities and ASB, and their subsidiaries, including the possible adoption of International Financial Reporting Standards or 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 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, Hawaiian Electric, ASBthe Utilities and their subsidiaries;ASB;
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); 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 and their subsidiaries undertake no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise.


v

PART I - FINANCIAL INFORMATION

Item 1.  Financial Statements

Hawaiian Electric Industries, Inc. and Subsidiaries
Consolidated Statements of Income (unaudited)
 
 Three months  
 ended March 31		 Three months ended June 30 Six months ended June 30
(in thousands, except per share amounts) 2014 2013 2014 2013 2014 2013
Revenues  
  
  
  
  
  
Electric utility $720,062
 $717,441
 $738,429
 $728,525
 $1,458,491
 $1,445,966
Bank 63,619
 64,756
 60,616
 66,027
 124,235
 130,783
Other 68
 35
 (388) 15
 (320) 50
Total revenues 783,749
 782,232
 798,657
 794,567
 1,582,406
 1,576,799
Expenses  
  
  
  
  
  
Electric utility 649,396
 666,320
 668,361
 669,550
 1,317,757
 1,335,870
Bank 41,996
 43,005
 43,568
 41,322
 85,564
 84,327
Other 4,051
 4,082
 4,453
 3,488
 8,504
 7,570
Total expenses 695,443
 713,407
 716,382
 714,360
 1,411,825
 1,427,767
Operating income (loss)  
  
  
  
  
  
Electric utility 70,666
 51,121
 70,068
 58,975
 140,734
 110,096
Bank 21,623
 21,751
 17,048
 24,705
 38,671
 46,456
Other (3,983) (4,047) (4,841) (3,473) (8,824) (7,520)
Total operating income 88,306
 68,825
 82,275
 80,207
 170,581
 149,032
Interest expense, net—other than on deposit liabilities and other bank borrowings (19,456) (18,731) (20,022) (18,442) (39,478) (37,173)
Allowance for borrowed funds used during construction 614
 730
 523
 398
 1,137
 1,128
Allowance for equity funds used during construction 1,609
 1,215
 1,387
 1,560
 2,996
 2,775
Income before income taxes 71,073
 52,039
 64,163
 63,723
 135,236
 115,762
Income taxes 24,673
 17,887
 22,269
 22,662
 46,942
 40,549
Net income 46,400
 34,152
 41,894
 41,061
 88,294
 75,213
Preferred stock dividends of subsidiaries 473
 473
 473
 473
 946
 946
Net income for common stock $45,927
 $33,679
 $41,421
 $40,588
 $87,348
 $74,267
Basic earnings per common share $0.45
 $0.34
 $0.41
 $0.41
 $0.86
 $0.75
Diluted earnings per common share $0.45
 $0.34
 $0.41
 $0.41
 $0.86
 $0.75
Dividends per common share $0.31
 $0.31
 $0.31
 $0.31
 $0.62
 $0.62
Weighted-average number of common shares outstanding 101,382
 98,135
 101,495
 98,660
 101,439
 98,399
Net effect of potentially dilutive shares 783
 405
 330
 589
 606
 562
Adjusted weighted-average shares 102,165
 98,540
 101,825
 99,249
 102,045
 98,961
 
The accompanying notes are an integral part of these consolidated financial statements.


1


Hawaiian Electric Industries, Inc. and Subsidiaries
Consolidated Statements of Comprehensive Income (unaudited)
 
 Three months  
 ended March 31		 Three months ended June 30 Six months ended June 30
(in thousands) 2014 2013 2014 2013 2014 2013
Net income for common stock $45,927
 $33,679
 $41,421
 $40,588
 $87,348
 $74,267
Other comprehensive income (loss), net of taxes:  
  
  
  
  
  
Net unrealized gains (losses) on securities:  
  
  
  
  
  
Net unrealized gains (losses) on securities arising during the period, net of (taxes) benefits of ($1,664) and $547 for the respective periods 2,520
 (828)
Less: reclassification adjustment for net realized gains included in net income, net of taxes of $1,132 and nil for the respective periods (1,715) —
Net unrealized gains (losses) on securities arising during the period, net of (taxes) benefits of ($1,679), $5,485, ($3,343) and $6,032 for the respective periods 2,543
 (8,307) 5,063
 (9,135)
Less: reclassification adjustment for net realized gains included in net income, net of taxes of nil, $488, $1,132 and $488 for the respective periods —
 (738) (1,715) (738)
Derivatives qualified as cash flow hedges:  
  
  
  
  
  
Less: reclassification adjustment to net income, net of tax benefits of $37 for both periods 59
 59
Less: reclassification adjustment to net income, net of tax benefits of $38, $38, $75 and $75 for the respective periods 59
 59
 118
 118
Retirement benefit plans:  
  
  
  
  
  
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits of $1,796 and $3,846 for the respective periods 2,813
 6,021
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $1,598 and $3,384 for the respective periods (2,510) (5,313)
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits of $1,742, $3,630, $3,632 and $7,476 for the respective periods 2,873
 5,680
 5,686
 11,701
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $1,641, $3,184, $3,239 and $6,568 for the respective periods (2,575) (4,999) (5,085) (10,312)
Other comprehensive income (loss), net of taxes 1,167
 (61) 2,900
 (8,305) 4,067
 (8,366)
Comprehensive income attributable to Hawaiian Electric Industries, Inc. $47,094
 $33,618
 $44,321
 $32,283
 $91,415
 $65,901
 
The accompanying notes are an integral part of these consolidated financial statements.

2


Hawaiian Electric Industries, Inc. and Subsidiaries
Consolidated Balance Sheets (unaudited)
 
(dollars in thousands) March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
Assets  
  
  
  
  
  
Cash and cash equivalents  
 $269,120
  
 $220,036
 $188,377
 $220,036
Accounts receivable and unbilled revenues, net  
 324,433
  
 346,785
 349,771
 346,785
Available-for-sale investment and mortgage-related securities  
 517,534
  
 529,007
 549,321
 529,007
Investment in stock of Federal Home Loan Bank of Seattle  
 86,697
  
 92,546
 80,863
 92,546
Loans receivable held for investment, net  
 4,147,537
  
 4,110,113
 4,245,240
 4,110,113
Loans held for sale, at lower of cost or fair value  
 4,363
  
 5,302
 956
 5,302
Property, plant and equipment, net of accumulated depreciation of $2,206,650 and $2,192,422 at the respective dates  
 3,908,392
  
 3,865,514
Property, plant and equipment, net of accumulated depreciation of $2,224,728 and $2,192,422 at the respective dates 3,980,096
 3,865,514
Regulatory assets  
 579,963
  
 575,924
 582,645
 575,924
Other  
 537,841
  
 512,627
 557,684
 512,627
Goodwill  
 82,190
  
 82,190
 82,190
 82,190
Total assets  
 $10,458,070
  
 $10,340,044
 $10,617,143
 $10,340,044
Liabilities and shareholders’ equity  
  
  
  
  
  
Liabilities  
  
  
  
  
  
Accounts payable  
 $210,511
  
 $212,331
 $176,379
 $212,331
Interest and dividends payable  
 28,520
  
 26,716
 25,315
 26,716
Deposit liabilities  
 4,477,987
  
 4,372,477
 4,524,860
 4,372,477
Short-term borrowings—other than bank  
 136,369
  
 105,482
 185,175
 105,482
Other bank borrowings  
 244,642
  
 244,514
 242,455
 244,514
Long-term debt, net—other than bank  
 1,492,945
  
 1,492,945
 1,517,945
 1,492,945
Deferred income taxes  
 538,321
  
 529,260
 579,222
 529,260
Regulatory liabilities  
 350,916
  
 349,299
 354,980
 349,299
Contributions in aid of construction  
 438,020
  
 432,894
 442,379
 432,894
Defined benefit pension and other postretirement benefit plans liability  
 284,043
  
 288,539
 278,427
 288,539
Other  
 475,575
  
 524,224
 494,834
 524,224
Total liabilities  
 8,677,849
  
 8,578,681
 8,821,971
 8,578,681
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: 101,477,616 shares and 101,259,800 shares at the respective dates  
 1,491,338
  
 1,488,126
Common stock, no par value, authorized 200,000,000 shares; issued and outstanding: 101,560,176 shares and 101,259,800 shares at the respective dates 1,493,436
 1,488,126
Retained earnings  
 270,173
  
 255,694
 280,126
 255,694
Accumulated other comprehensive loss, net of tax benefits  
  
  
  
 (12,683) (16,750)
Net unrealized losses on securities $(2,858)  
 $(3,663)  
Unrealized losses on derivatives (466)  
 (525)  
Retirement benefit plans (12,259) (15,583) (12,562) (16,750)
Total shareholders’ equity  
 1,745,928
  
 1,727,070
 1,760,879
 1,727,070
Total liabilities and shareholders’ equity  
 $10,458,070
  
 $10,340,044
 $10,617,143
 $10,340,044
 
The accompanying notes are an integral part of these consolidated financial statements.

3

Hawaiian Electric Industries, Inc. and Subsidiaries
Consolidated Statements of Changes in Shareholders’ Equity (unaudited)
 
 Common stock Retained 
Accumulated
other
comprehensive
   Common stock Retained 
Accumulated
other
comprehensive
  
(in thousands, except per share amounts) Shares Amount Earnings income (loss) Total Shares Amount Earnings income (loss) Total
Balance, December 31, 2013 101,260
 $1,488,126
 $255,694
 $(16,750) $1,727,070
 101,260
 $1,488,126
 $255,694
 $(16,750) $1,727,070
Net income for common stock —
 —
 45,927
 —
 45,927
 —
 —
 87,348
 —
 87,348
Other comprehensive income, net of taxes —
 —
 —
 1,167
 1,167
 —
 —
 —
 4,067
 4,067
Issuance of common stock, net 218
 3,212
 —
 —
 3,212
 300
 5,310
 —
 —
 5,310
Common stock dividends ($0.31 per share) —
 —
 (31,448) —
 (31,448)
Balance, March 31, 2014 101,478
 $1,491,338
 $270,173
 $(15,583) $1,745,928
Common stock dividends ($0.62 per share) —
 —
 (62,916) —
 (62,916)
Balance, June 30, 2014 101,560
 $1,493,436
 $280,126
 $(12,683) $1,760,879
                    
Balance, December 31, 2012 97,928
 $1,403,484
 $216,804
 $(26,423) $1,593,865
 97,928
 $1,403,484
 $216,804
 $(26,423) $1,593,865
Net income for common stock —
 —
 33,679
 —
 33,679
 —
 —
 74,267
 —
 74,267
Other comprehensive loss, net of tax benefits —
 —
 —
 (61) (61) —
 —
 —
 (8,366) (8,366)
Issuance of common stock, net 543
 10,216
 —
 —
 10,216
 1,116
 25,887
 —
 —
 25,887
Common stock dividends ($0.31 per share) —
 —
 (30,434) —
 (30,434)
Balance, March 31, 2013 98,471
 $1,413,700
 $220,049
 $(26,484) $1,607,265
Common stock dividends ($0.62 per share) —
 —
 (61,004) —
 (61,004)
Balance, June 30, 2013 99,044
 $1,429,371
 $230,067
 $(34,789) $1,624,649
 
The accompanying notes are an integral part of these consolidated financial statements.


4


Hawaiian Electric Industries, Inc. and Subsidiaries
Consolidated Statements of Cash Flows (unaudited)
Three months ended March 31 2014 2013
Six months ended June 30 2014 2013
(in thousands)        
Cash flows from operating activities  
  
  
  
Net income $46,400
 $34,152
 $88,294
 $75,213
Adjustments to reconcile net income to net cash provided by operating activities  
  
  
  
Depreciation of property, plant and equipment 43,181
 39,726
 86,397
 79,843
Other amortization 1,609
 935
 4,014
 2,868
Provision for loan losses 995
 1,858
 2,016
 899
Loans receivable originated and purchased, held for sale (46,998) (79,224) (69,656) (128,276)
Proceeds from sale of loans receivable, held for sale 48,720
 102,254
 75,040
 148,243
Increase in deferred income taxes 6,298
 19,967
 28,252
 40,403
Excess tax benefits from share-based payment arrangements (164) (414) (267) (445)
Allowance for equity funds used during construction (1,609) (1,215) (2,996) (2,775)
Change in cash overdraft (1,038) —
 (1,038) —
Changes in assets and liabilities  
  
  
  
Decrease in accounts receivable and unbilled revenues, net 22,352
 14,335
Increase in fuel oil stock (34,260) (29,272)
Decrease (increase) in accounts receivable and unbilled revenues, net (2,986) 3,564
Decrease (increase) in fuel oil stock (27,206) 43,974
Increase in regulatory assets (9,258) (17,746) (17,731) (37,586)
Increase (decrease) in accounts, interest and dividends payable (9,307) 38,148
Decrease in accounts, interest and dividends payable (64,843) (43,384)
Change in prepaid and accrued income taxes and utility revenue taxes (19,474) (50,933) (32,510) (33,822)
Decrease in defined benefit pension and other postretirement benefit plans liability (818) (702) (1,714) (330)
Change in other assets and liabilities (27,208) (23,550) (16,871) (17,597)
Net cash provided by operating activities 19,421
 48,319
 46,195
 130,792
Cash flows from investing activities  
  
  
  
Available-for-sale investment and mortgage-related securities purchased (79,912) (26,705) (125,531) (39,721)
Principal repayments on available-for-sale investment and mortgage-related securities 15,597
 36,504
 33,202
 62,819
Proceeds from sale of available-for-sale investment securities 79,564
 —
 79,564
 71,367
Redemption of stock from Federal Home Loan Bank of Seattle 11,683
 1,742
Net increase in loans held for investment (37,887) (66,934) (137,122) (201,184)
Proceeds from sale of real estate acquired in settlement of loans 1,429
 3,046
 2,162
 5,712
Capital expenditures (65,829) (71,041) (149,253) (158,830)
Contributions in aid of construction 6,958
 11,710
 13,209
 17,188
Other 5,848
 869
 (16) 622
Net cash used in investing activities (74,232) (112,551) (272,102) (240,285)
Cash flows from financing activities  
  
  
  
Net increase in deposit liabilities 105,510
 82,704
 152,383
 46,326
Net increase in short-term borrowings with original maturities of three months or less 30,887
 50,244
 79,693
 42,093
Net increase (decrease) in retail repurchase agreements 141
 (2,680)
Net decrease in retail repurchase agreements (2,053) (8,054)
Proceeds from other bank borrowings —
 25,000
Repayments of other bank borrowings —
 (25,000)
Proceeds from issuance of long-term debt —
 50,000
 125,000
 50,000
Repayment of long-term debt —
 (50,000) (100,000) (50,000)
Excess tax benefits from share-based payment arrangements 164
 414
 267
 445
Net proceeds from issuance of common stock 3,054
 4,703
 3,048
 11,994
Common stock dividends (31,435) (24,394) (62,892) (48,921)
Preferred stock dividends of subsidiaries (473) (473) (946) (946)
Other (3,953) (3,240) (252) 606
Net cash provided by financing activities 103,895
 107,278
 194,248
 43,543
Net increase in cash and cash equivalents 49,084
 43,046
Net decrease in cash and cash equivalents (31,659) (65,950)
Cash and cash equivalents, beginning of period 220,036
 219,662
 220,036
 219,662
Cash and cash equivalents, end of period $269,120
 $262,708
 $188,377
 $153,712
 The accompanying notes are an integral part of these consolidated financial statements.

5


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidated Statements of Income (unaudited)
 Three months  
 ended March 31		 Three months ended June 30 Six months ended June 30
(in thousands) 2014 2013 2014 2013 2014 2013
Revenues $720,062
 $717,441
 $738,429
 $728,525
 $1,458,491
 $1,445,966
Expenses  
  
  
  
  
  
Fuel oil 286,300
 305,100
 270,257
 289,278
 556,557
 594,378
Purchased power 164,916
 153,364
 188,323
 178,444
 353,239
 331,808
Other operation and maintenance 88,606
 101,813
 98,564
 94,397
 187,170
 196,210
Depreciation 41,603
 38,280
 41,593
 38,590
 83,196
 76,870
Taxes, other than income taxes 67,971
 67,763
 69,624
 68,841
 137,595
 136,604
Total expenses 649,396
 666,320
 668,361
 669,550
 1,317,757
 1,335,870
Operating income 70,666
 51,121
 70,068
 58,975
 140,734
 110,096
Allowance for equity funds used during construction 1,609
 1,215
 1,387
 1,560
 2,996
 2,775
Interest expense and other charges, net (15,723) (14,519) (16,852) (14,408) (32,575) (28,927)
Allowance for borrowed funds used during construction 614
 730
 523
 398
 1,137
 1,128
Income before income taxes 57,166
 38,547
 55,126
 46,525
 112,292
 85,072
Income taxes 21,247
 13,619
 20,397
 17,333
 41,644
 30,952
Net income 35,919
 24,928
 34,729
 29,192
 70,648
 54,120
Preferred stock dividends of subsidiaries 229
 229
 229
 229
 458
 458
Net income attributable to Hawaiian Electric 35,690
 24,699
 34,500
 28,963
 70,190
 53,662
Preferred stock dividends of Hawaiian Electric 270
 270
 270
 270
 540
 540
Net income for common stock $35,420
 $24,429
 $34,230
 $28,693
 $69,650
 $53,122

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.
 
The accompanying notes are an integral part of these consolidated financial statements.

Hawaiian Electric Company, Inc. and Subsidiaries
Consolidated Statements of Comprehensive Income (unaudited)
 
 Three months ended 
 March 31		 Three months ended June 30 Six months ended June 30
(in thousands) 2014 2013 2014 2013 2014 2013
Net income for common stock $35,420
 $24,429
 $34,230
 $28,693
 $69,650
 $53,122
Other comprehensive income, net of taxes:  
  
  
  
  
  
Retirement benefit plans:  
  
  
  
  
  
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits of $1,605 and $3,395 for the respective periods 2,519
 5,331
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $1,598 and $3,384 for the respective periods (2,510) (5,313)
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits of $1,647, $3,195, $3,252 and $6,590 for the respective periods 2,588
 5,016
 5,107
 10,347
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes of $1,641, $3,184, $3,239 and $6,568 for the respective periods (2,575) (4,999) (5,085) (10,312)
Other comprehensive income, net of taxes 9
 18
 13
 17
 22
 35
Comprehensive income attributable to Hawaiian Electric Company, Inc. $35,429
 $24,447
 $34,243
 $28,710
 $69,672
 $53,157
 
The accompanying notes are an integral part of these consolidated financial statements.


6


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidated Balance Sheets (unaudited)
(dollars in thousands, except par value) March 31,
2014		 December 31,
2013		 June 30,
2014		 December 31,
2013
Assets  
  
  
  
Property, plant and equipment        
Utility property, plant and equipment  
  
  
  
Land $51,845
 $51,883
 $52,010
 $51,883
Plant and equipment 5,762,899
 5,701,875
 5,830,723
 5,701,875
Less accumulated depreciation (2,134,460) (2,111,229) (2,150,913) (2,111,229)
Construction in progress 148,602
 143,233
 168,280
 143,233
Utility property, plant and equipment, net 3,828,886
 3,785,762
 3,900,100
 3,785,762
Nonutility property, plant and equipment, less accumulated depreciation of $1,224 and $1,223 at respective dates 6,566
 6,567
Nonutility property, plant and equipment, less accumulated depreciation of $1,226 and $1,223 at respective dates 6,564
 6,567
Total property, plant and equipment, net 3,835,452
 3,792,329
 3,906,664
 3,792,329
Current assets  
  
  
  
Cash and cash equivalents 17,359
 62,825
 12,720
 62,825
Customer accounts receivable, net 164,016
 175,448
 175,634
 175,448
Accrued unbilled revenues, net 131,864
 144,124
 141,869
 144,124
Other accounts receivable, net 16,690
 14,062
 18,915
 14,062
Fuel oil stock, at average cost 168,347
 134,087
 161,293
 134,087
Materials and supplies, at average cost 60,089
 59,044
 60,879
 59,044
Prepayments and other 32,299
 52,857
 61,891
 52,857
Regulatory assets 77,455
 69,738
 78,945
 69,738
Total current assets 668,119
 712,185
 712,146
 712,185
Other long-term assets  
  
  
  
Regulatory assets 502,508
 506,186
 503,700
 506,186
Unamortized debt expense 9,124
 9,003
 8,905
 9,003
Other 67,386
 67,426
 68,426
 67,426
Total other long-term assets 579,018
 582,615
 581,031
 582,615
Total assets $5,082,589
 $5,087,129
 $5,199,841
 $5,087,129
Capitalization and liabilities  
  
  
  
Capitalization  
  
  
  
Common stock ($6 2/3 par value, authorized 50,000,000 shares; outstanding 15,429,105 shares) $102,880
 $102,880
 $102,880
 $102,880
Premium on capital stock 541,449
 541,452
 541,449
 541,452
Retained earnings 961,337
 948,624
 974,028
 948,624
Accumulated other comprehensive income, net of income taxes-retirement benefit plans 617
 608
 630
 608
Common stock equity 1,606,283
 1,593,564
 1,618,987
 1,593,564
Cumulative preferred stock — not subject to mandatory redemption 34,293
 34,293
 34,293
 34,293
Long-term debt, net 1,206,545
 1,206,545
 1,206,545
 1,206,545
Total capitalization 2,847,121
 2,834,402
 2,859,825
 2,834,402
Commitments and contingencies (Note 3) 

 

 

 

Current liabilities  
  
  
  
Current portion of long-term debt 11,400
 11,400
 11,400
 11,400
Short-term borrowings from non-affiliates 34,996
 —
 102,989
 —
Accounts payable 182,826
 189,559
 153,743
 189,559
Interest and preferred dividends payable 24,100
 21,652
 21,751
 21,652
Taxes accrued 193,734
 249,445
 216,374
 249,445
Regulatory liabilities 1,437
 1,916
 789
 1,916
Other 62,476
 63,881
 64,569
 63,881
Total current liabilities 510,969
 537,853
 571,615
 537,853
Deferred credits and other liabilities  
  
  
  
Deferred income taxes 515,041
 507,161
 557,056
 507,161
Regulatory liabilities 349,479
 347,383
 354,191
 347,383
Unamortized tax credits 75,544
 73,539
 77,713
 73,539
Defined benefit pension and other postretirement benefit plans liability 257,601
 262,162
 252,785
 262,162
Other 88,814
 91,735
 84,277
 91,735
Total deferred credits and other liabilities 1,286,479
 1,281,980
 1,326,022
 1,281,980
Contributions in aid of construction 438,020
 432,894
 442,379
 432,894
Total capitalization and liabilities $5,082,589
 $5,087,129
 $5,199,841
 $5,087,129
 The accompanying notes are an integral part of these consolidated financial statements.

7


Hawaiian Electric Company, Inc. and Subsidiaries
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, 2013 15,429
 $102,880
 $541,452
 $948,624
 $608
 $1,593,564
 15,429
 $102,880
 $541,452
 $948,624
 $608
 $1,593,564
Net income for common stock —
 —
 —
 35,420
 —
 35,420
 —
 —
 —
 69,650
 —
 69,650
Other comprehensive income, net of taxes —
 —
 —
 —
 9
 9
 —
 —
 —
 —
 22
 22
Common stock dividends —
 —
 —
 (22,707) —
 (22,707) —
 —
 —
 (44,246) —
 (44,246)
Common stock issue expenses —
 —
 (3) —
 —
 (3)
Balance, March 31, 2014 15,429
 $102,880
 $541,449
 $961,337
 $617
 $1,606,283
Common stock issuance expenses —
 —
 (3) —
 —
 (3)
Balance, June 30, 2014 15,429
 $102,880
 $541,449
 $974,028
 $630
 $1,618,987
Balance, December 31, 2012 14,665
 $97,788
 $468,045
 $907,273
 $(970) $1,472,136
 14,665
 $97,788
 $468,045
 $907,273
 $(970) $1,472,136
Net income for common stock —
 —
 —
 24,429
 —
 24,429
 —
 —
 —
 53,122
 —
 53,122
Other comprehensive income, net of taxes —
 —
 —
 —
 18
 18
 —
 —
 —
 —
 35
 35
Common stock dividends —
 —
 —
 (20,070) —
 (20,070) —
 —
 —
 (40,789) —
 (40,789)
Balance, March 31, 2013 14,665
 $97,788
 $468,045
 $911,632
 $(952) $1,476,513
Balance, June 30, 2013 14,665
 $97,788
 $468,045
 $919,606
 $(935) $1,484,504
 
The accompanying notes are an integral part of these consolidated financial statements.


8


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidated Statements of Cash Flows (unaudited)
 
Three months ended March 31, 2014 2013
Six months ended June 30 2014 2013
(in thousands)        
Cash flows from operating activities  
  
  
  
Net income $35,919
 $24,928
 $70,648
 $54,120
Adjustments to reconcile net income to net cash provided by operating activities  
  
  
  
Depreciation of property, plant and equipment 41,603
 38,280
 83,196
 76,870
Other amortization 1,621
 957
 3,597
 2,884
Increase in deferred income taxes 20,344
 17,975
 45,386
 38,780
Change in tax credits, net 2,032
 1,382
 4,227
 2,997
Allowance for equity funds used during construction (1,609) (1,215) (2,996) (2,775)
Change in cash overdraft (1,038) —
 (1,038) —
Changes in assets and liabilities  
  
  
  
Decrease in accounts receivable 8,804
 38,703
Decrease (increase) in accounts receivable (5,039) 32,253
Decrease (increase) in accrued unbilled revenues 12,260
 (1,317) 2,255
 (4,889)
Increase in fuel oil stock (34,260) (29,272)
Decrease (increase) in fuel oil stock (27,206) 43,974
Increase in materials and supplies (1,045) (3,345) (1,835) (7,139)
Increase in regulatory assets (9,258) (17,746) (17,731) (37,586)
Increase (decrease) in accounts payable (16,024) 38,934
Decrease in accounts payable (63,306) (41,234)
Change in prepaid and accrued income taxes and utility revenue taxes (47,526) (53,666) (38,270) (38,123)
Decrease in defined benefit pension and other postretirement benefit plans liability (205) (47)
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability (498) 989
Change in other assets and liabilities (10,981) (1,050) (26,258) (9,419)
Net cash provided by operating activities 637
 53,501
 25,132
 111,702
Cash flows from investing activities  
  
  
  
Capital expenditures (64,462) (67,915) (145,734) (150,251)
Contributions in aid of construction 6,958
 11,710
 13,209
 17,188
Other —
 623
Net cash used in investing activities (57,504) (56,205) (132,525) (132,440)
Cash flows from financing activities  
  
  
  
Common stock dividends (22,707) (20,070) (44,246) (40,789)
Preferred stock dividends of Hawaiian Electric and subsidiaries (499) (499) (998) (998)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less 34,996
 43,052
 102,989
 53,992
Other (389) 2
 (457) (9)
Net cash provided by financing activities 11,401
 22,485
 57,288
 12,196
Net increase (decrease) in cash and cash equivalents (45,466) 19,781
Net decrease in cash and cash equivalents (50,105) (8,542)
Cash and cash equivalents, beginning of period 62,825
 17,159
 62,825
 17,159
Cash and cash equivalents, end of period $17,359
 $36,940
 $12,720
 $8,617
 
The accompanying notes are an integral part of these consolidated financial statements.


9


NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)

1 · Basis of presentation
The accompanying unaudited 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 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 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, 2013.
In the opinion of HEI’s and Hawaiian Electric's management, the accompanying unaudited consolidated financial statements contain all material adjustments required by GAAP to fairly state the Company’s and Hawaiian Electric's financial position as of March 31,June 30, 2014 and December 31, 2013, the results of its operations for the three and six months ended June 30, 2014 and 2013, and its cash flows for the threesix months ended March 31,June 30, 2014 and 2013. All such adjustments are of a normal recurring nature, unless otherwise disclosed in this Form 10-Q or other referenced material. Results of operations for interim periods are not necessarily indicative of results for the full year. When required, certain reclassifications are made to the prior period’s consolidated financial statements to conform to the current presentation.
Reclassifications and revisions. In the fourth quarter of 2013, Hawaiian Electric changed its consolidated statements of income for 2013 and prior comparative periods from a utility presentation to a commercial company presentation, under which all operating revenues and expenses (including non-regulated revenues and expenses) are included in the determination of operating income. Additionally, income tax expense, which was previously included partially in operating expenses and partially in other income (deductions), is now entirely presented directly above net income in income taxes and includes income taxes related to non-regulated revenues and expenses.
In making the change to a commercial company presentation, the Company discovered that interest on the Utilities’ uncollected revenue balancing accounts and the income tax gross-up adjustment for AFUDC-equityallowance for funds used during construction (AFUDC)-equity were incorrectly included in HEI consolidated revenues and is revising its previously filed quarterly Consolidated Statements of Income for 2013 to move the amounts to “Interest expense, net-other than on deposit liabilities and other bank borrowings” and income taxes, respectively. Such quarterly amounts were not considered to be material to previously filed financial statements.
The Company and the Utilities have also revised their property, plant and equipment as of December 31, 2013 to correct for an error that excluded Hawaiian Electric consolidated non-utility property plant and equipment amounts. These amounts were not considered to be material to previously filed financial statements.

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The table below illustrates the effects of the revisions on the previously filed financial statements:
  As previously
 As
    As previously
 As
  
(in thousands)  filed
 revised
  Difference
  filed
 revised
  Difference
HEI consolidated            
Three months ended March 31, 2013      
Consolidated Statements of Income            
Three months ended June 30, 2013      
Revenues $784,064
 $782,232
 $(1,832) $796,730
 $794,567
 $(2,163)
Operating income 70,657
 68,825
 (1,832) 82,370
 80,207
 (2,163)
Interest expense, net—other than on deposit liabilities and other bank borrowings (19,788) (18,731) 1,057
 (19,613) (18,442) 1,171
Income before income taxes 52,814
 52,039
 (775) 64,715
 63,723
 (992)
Income taxes 18,662
 17,887
 (775) 23,654
 22,662
 (992)
Six months ended June 30, 2013      
Revenues 1,580,794
 1,576,799
 (3,995)
Operating income 153,027
 149,032
 (3,995)
Interest expense, net—other than on deposit liabilities and other bank borrowings (39,401) (37,173) 2,228
Income before income taxes 117,529
 115,762
 (1,767)
Income taxes 42,316
 40,549
 (1,767)
Consolidated Balance Sheets      
December 31, 2013            
Consolidated Balance Sheets      
Property, plant and equipment, net of accumulated depreciation 3,858,947
 3,865,514
 6,567
 3,858,947
 3,865,514
 6,567
Accumulated depreciation (2,191,199) (2,192,422) (1,223) (2,191,199) (2,192,422) (1,223)
Other assets 519,194
 512,627
 (6,567) 519,194
 512,627
 (6,567)
Hawaiian Electric consolidated            
Consolidated Balance Sheets            
December 31, 2013      
Other assets 73,993
 67,426
 (6,567) 73,993
 67,426
 (6,567)

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The reclassifications and revisions made to prior periods’ financial statements for the three and six months ended March 31,June 30, 2013 and as of December 31, 2013 to conform to the presentation for the three and six months ended, and as of, March 31,June 30, 2014 did not affect previously reported net income and cash flows.flows and were not considered material to previously filed financial statements.

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2 · Segment financial information
 
(in thousands)  Electric utility Bank Other Total Electric utility Bank Other Total
Three months ended March 31, 2014  
  
  
  
Three months ended June 30, 2014  
  
  
  
Revenues from external customers $720,056
 $63,619
 $74
 $783,749
 $738,423
 $60,616
 $(382) $798,657
Intersegment revenues (eliminations) 6
 —
 (6) —
 6
 —
 (6) —
Revenues 720,062
 63,619
 68
 783,749
 738,429
 60,616
 (388) 798,657
Income (loss) before income taxes 57,166
 21,624
 (7,717) 71,073
 55,126
 17,048
 (8,011) 64,163
Income taxes (benefit) 21,247
 7,085
 (3,659) 24,673
 20,397
 5,372
 (3,500) 22,269
Net income (loss) 35,919
 14,539
 (4,058) 46,400
 34,729
 11,676
 (4,511) 41,894
Preferred stock dividends of subsidiaries 499
 —
 (26) 473
 499
 —
 (26) 473
Net income (loss) for common stock 35,420
 14,539
 (4,032) 45,927
 34,230
 11,676
 (4,485) 41,421
Assets (at March 31, 2014) 5,082,589
 5,371,483
 3,998
 10,458,070
Three months ended March 31, 2013  
  
  
  
        
Six months ended June 30, 2014  
  
  
  
Revenues from external customers $1,458,479
 $124,235
 $(308) $1,582,406
Intersegment revenues (eliminations) 12
 —
 (12) —
Revenues 1,458,491
 124,235
 (320) 1,582,406
Income (loss) before income taxes 112,292
 38,672
 (15,728) 135,236
Income taxes (benefit) 41,644
 12,457
 (7,159) 46,942
Net income (loss) 70,648
 26,215
 (8,569) 88,294
Preferred stock dividends of subsidiaries 998
 —
 (52) 946
Net income (loss) for common stock 69,650
 26,215
 (8,517) 87,348
Assets (at June 30, 2014) 5,199,841
 5,418,127
 (825) 10,617,143
        
Three months ended June 30, 2013  
  
  
  
Revenues from external customers $728,519
 $66,027
 $21
 $794,567
Intersegment revenues (eliminations) 6
 —
 (6) —
Revenues 728,525
 66,027
 15
 794,567
Income (loss) before income taxes 46,525
 24,705
 (7,507) 63,723
Income taxes (benefit) 17,333
 8,786
 (3,457) 22,662
Net income (loss) 29,192
 15,919
 (4,050) 41,061
Preferred stock dividends of subsidiaries 499
 —
 (26) 473
Net income (loss) for common stock 28,693
 15,919
 (4,024) 40,588
        
Six months ended June 30, 2013  
  
  
  
Revenues from external customers $717,435
 $64,756
 $41
 $782,232
 $1,445,954
 $130,783
 $62
 $1,576,799
Intersegment revenues (eliminations) 6
 —
 (6) —
 12
 —
 (12) —
Revenues 717,441
 64,756
 35
 782,232
 1,445,966
 130,783
 50
 1,576,799
Income (loss) before income taxes 38,547
 21,752
 (8,260) 52,039
 85,072
 46,457
 (15,767) 115,762
Income taxes (benefit) 13,619
 7,597
 (3,329) 17,887
 30,952
 16,383
 (6,786) 40,549
Net income (loss) 24,928
 14,155
 (4,931) 34,152
 54,120
 30,074
 (8,981) 75,213
Preferred stock dividends of subsidiaries 499
 —
 (26) 473
 998
 —
 (52) 946
Net income (loss) for common stock 24,429
 14,155
 (4,905) 33,679
 53,122
 30,074
 (8,929) 74,267
Assets (at December 31, 2013) 5,087,129
 5,243,824
 9,091
 10,340,044
 5,087,129
 5,243,824
 9,091
 10,340,044
 
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, the profit on such sales is nominal and the elimination of electric sales revenues and expenses could distort segment operating income and net income for common stock.
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, the profit on such fees is nominal and the elimination of bank fee income and expenses could distort segment operating income and net income for common stock.


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3 · Electric utility segment
 
Revenue taxes. The Utilities’ operating revenues include amounts for the recovery of various Hawaii state revenue taxes. Revenue taxes are generally recorded as an expense in the period the related revenues are recognized. However, the Utilities’ revenue tax payments to the taxing authorities in the period are based on the prior year’s billed revenues (in the case of public service company taxes and PUC fees) or on the current year’s cash collections from electric sales (in the case of franchise taxes). ForThe Utilities included in the threesecond quarters of 2014 and 2013 and the six months ended March 31,June 30, 2014 and 2013, the Utilities included approximately $64 million, $65 million, $65129 million and $64129 million, respectively, of revenue taxes in “operating revenues”"revenues" and in “taxes,"taxes, other than income taxes”taxes" expense.
Recent tax developments. In September 2013, the Internal Revenue Service (IRS) issued final regulations addressing the acquisition, production and improvement of tangible property, which were effective January 1, 2014. Management is currently evaluatingdoes not expect the impact of these new regulations but does not expect awill be material impact onto the UtilitiesUtilities' financial statements since specific guidance on network (i.e., transmission and distribution) assets and generation property had already been received. The IRS also proposed regulations addressing the disposition of property.
The Utilities adopted the safe harbor guidelines with respect to network assets in 2011 and in June 2013, the IRS released a revenue procedure relating to deductions for repairs of generation property, which provides some guidance (that is elective) for taxpayers that own steam or electric generation property. This guidance defines the relevant components of generation property

11


to be used in determining whether such component expenditures should be deducted as repairs or capitalized and depreciated by taxpayers. The revenue procedure also provides an extrapolation methodology that could be used by taxpayers in determining deductions for prior years’ repairs without going back to the specific documentation of those years. The guidance does not provide specific methods for determining the repairs amount. Management intends to adopt this guidance through an election in its 2014 tax return.return, which is expected to result in slightly improved cash flows.
In March 2014, HEI filed with the IRS an application, which requested a change in the method of accounting for revenues recorded to the Utilities’ revenue balancing accounts (RBAs) (from an accrual basis to a cash collectionsbilled basis) for income tax purposes. On April 28, 2014, the Utilities received approval for this change from the IRS, effective January 1, 2014. HEI expects to execute a consent agreement with the IRS and will include the effects of this change in its estimated income tax payments for 2014. This change will result in improved cash flows by deferring the payment of income taxes on the RBA revenues recognized until the revenues are collected andbilled but will reduce the interest to be accrued on the RBA balance as proposed by the Consumer Advocate.

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 absorb the majority of the variability of Trust III, Hawaiian Electric is not the primary beneficiary and does not consolidate Trust III in accordance with accounting rules on the consolidation of VIEs. Trust III’s balance sheetsheets as of March 31,June 30, 2014 and December 31, 2013 each consisted of $51.5 million of 2004 Debentures; $50$50.0 million of 2004 Trust Preferred Securities; and $1.5 million of trust common securities. Trust III’s income statementstatements for the threesix months ended March 31,June 30, 2014 and 2013 each consisted of $0.8$1.7 million of interest income received from the 2004 Debentures; $0.8$1.6 million of distributions to holders of the Trust Preferred Securities; and $25,000$0.1 million of common dividends on the trust common securities to Hawaiian Electric. SoAs 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.

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Power purchase agreements.  As of March 31,June 30, 2014, the Utilities had six PPAs for firm capacity and several other PPAs with variable generation independent power producers (IPPs) and Schedule Q providers (i.e., customers with cogeneration and/or small power production facilities with a capacity of 100 kilowatts (kWs) or less who buy power from or sell power to the Utilities), none of which are currently required to be consolidated as VIEs. Approximately 90% of the firm capacity is purchased fromThe PPAs with AES Hawaii, Inc. (AES Hawaii), Kalaeloa Partners, L.P. (Kalaeloa), Hamakua Energy Partners, L.P. (HEP) and HPOWER.HPOWER comprise approximately 90% of IPP contractual firm capacity available to the Utilities. Purchases from all IPPs were as follows:
 Three months ended March 31 Three months ended June 30 Six months ended June 30
(in millions) 2014 2013 2014 2013 2014 2013
AES Hawaii $33
 $23
 $36
 $37
 $69
 $60
Kalaeloa 67
 65
 74
 79
 141
 143
HEP 12
 12
 8
 9
 20
 20
HPOWER 16
 15
 16
 12
 32
 27
Other IPPs 37
 38
 54
 41
 91
 82
Total IPPs $165
 $153
 $188
 $178
 $353
 $332

12


 
Some of the IPPs provided sufficient information for Hawaiian Electric to determine that the IPP was not a VIE, or was either a “business” or “governmental organization,” and thus excluded from the scope of accounting standards for VIEs. Other IPPs, including the three largest, declined to provide the information necessary for Hawaiian Electric to determine the applicability of accounting standards for VIEs.
Since 2004, Hawaiian Electric has continued its efforts to obtain from the IPPs the information necessary to make the determinations required under accounting standards for VIEs. In each year from 2005 to 2013, 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 later agreed to provide the information pursuant to the amendments to its PPA (see below) and an entity owning a wind farm provided information as required under its PPA. Management has concluded that the consolidation of two entities owning wind farms was not required as Hawaii Electric Light and Maui Electric do not have variable interests in the entities because the PPAs do not require them to absorb any variability of the entities. If the requested information is ultimately received from the remaining IPPs, a possible outcome of future analyses of such information is the consolidation of one or more of such IPPs in the Consolidated Financial Statements. The consolidation of any significant IPP could have a material effect on the Consolidated Financial Statements, including the recognition of a significant amount of assets and liabilities and, if such a consolidated IPP were operating at a loss and had insufficient equity, the potential recognition of such losses. If the Utilities determine they are required to consolidate the financial statements of such an IPP and the consolidation has a material effect, the Utilities would retrospectively apply accounting standards for VIEs.
Kalaeloa Partners, L.P.  In October 1988, Hawaiian Electric entered into a PPA with Kalaeloa, subsequently approved by the PUC, which provided that Hawaiian Electric would purchase 180 megawatts (MW) of firm capacity for a period of 25 years beginning in May 1991. In October 2004, Hawaiian Electric and Kalaeloa entered into amendments to the PPA, subsequently approved by the PUC, which together effectively increased the firm capacity from 180 MW to 208 MW. The energy payments that Hawaiian Electric makes to Kalaeloa include: (1) a fuel component, with a fuel price adjustment based on the cost of low sulfur fuel oil, (2) a fuel additive component, with an adjustment based on changes in the Gross National Product Implicit Price Deflator, 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.
Pursuant to the current accounting standards for VIEs, Hawaiian Electric is deemed to have a variable interest in Kalaeloa by reason of the provisions of Hawaiian Electric’s PPA with Kalaeloa. However, management has concluded that Hawaiian Electric is not the primary beneficiary of Kalaeloa because Hawaiian Electric does not have the power to direct the activities that most significantly impact Kalaeloa’s economic performance nor the obligation to absorb Kalaeloa’s expected losses, if any, that could potentially be significant to Kalaeloa. Thus, Hawaiian Electric has not consolidated Kalaeloa in its consolidated financial statements. A significant factor affecting the level of expected losses Hawaiian Electric could potentially absorb is the fact that Hawaiian Electric’s exposure to fuel price variability is limited to the remaining term of the PPA as compared to the facility’s remaining useful life. Although Hawaiian Electric absorbs fuel price variability for the remaining term of the PPA, the PPA does not currently expose Hawaiian Electric to losses as the fuel and fuel related energy payments under the PPA have been approved by the PUC for recovery from customers through base electric rates and through Hawaiian Electric’s ECAC to

14


the extent the fuel and fuel related energy payments are not included in base energy rates. As of March 31,June 30, 2014, Hawaiian Electric’s accounts payable to Kalaeloa amounted to $23 million.
Commitments and contingencies.
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. In recent years, legislative, regulatory and governmental activities related to the environment, including proposals and rulemaking under the Clean Air Act (CAA) and Clean Water Act (CWA), have increased significantly and management anticipates that such activity will continue.
On April 20, 2011,May 19, 2014 the Federal Register published the federal Environmental Protection Agency’s (EPA’s) proposedAgency (EPA) released 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 proposed regulations wouldwill be effective 60 days after they are published in the Federal Register. They will apply to the cooling water systems for the steam generating units at Hawaiian Electric’s power plants on the island of Oahu. If adopted as proposed, management believes the proposedThe regulations would require significant capitalprescribe a process, including a number of required site-specific studies, for states to develop facility-specific entrainment and annual O&M expenditures. On June 11, 2012, the EPA published additional information on the section 316(b) rule making that indicates that the EPA is considering establishing lower cost compliance alternativesimpingement controls to be incorporated in the final rule. The EPA has delayed issuancefacility’s National Pollutant Discharge Elimination System permit. In the case of Hawaiian Electric's power plants, there are a number of studies that have yet to be completed before Hawaiian Electric and the Department of Health of the final section 316(b) rule.State of Hawaii (DOH) can determine what entrainment or impingement controls, if any, might be appropriate.

13


On February 16, 2012, the Federal Register published the EPA’s final rule establishing the EPA’s National Emission Standards for Hazardous Air Pollutants for fossil-fuel fired steam electrical generating units (EGUs). The final rule, known as the Mercury and Air Toxics Standards (MATS), applies to the 14 EGUs at Hawaiian Electric’s power plants. MATS establishes the Maximum Achievable Control Technology standards for the control of hazardous air pollutants emissions from new and existing EGUs. Based on a review of the final rule and the benefits and costs of alternative compliance strategies, Hawaiian Electric has selected a MATS compliance strategy based on switching to lower emission fuels. The use of lower emission fuels will provide for MATS compliance at lower overall costs and avoid the reduction in operational flexibility imposed by emissions control equipment. Hawaiian Electric requested and received a one-year extension, resulting in a MATS compliance date of April 16, 2016. Hawaiian Electric also has pending with the EPA a Petition for Reconsideration and Stay dated April 16, 2012, and a Request for Expedited Consideration dated August 14, 2013. The submittals ask the EPA to revise an emissions standard for non-continental oil-fired EGUs on the grounds that the promulgated standard was incorrectly derived. The Petition and Request submittals to the EPA included additional data to demonstrate that the existing standard is erroneous. Hawaiian Electric has been in contact with the EPA regarding the status of its Petition and does not expect a decision before the end of 2014.
On February 6, 2013, the EPA issued a guidance document titled “Next Steps for Area Designations and Implementation of the Sulfur Dioxide National Ambient Air Quality Standard,” which outlines a process that will provide the states additional flexibility and time for their development of one-hour sulfur dioxide (SO2) National Ambient Air Quality Standard (NAAQS) implementation plans. TheIn May 2014, the EPA expects to publishpublished a proposed data requirements rule for states to characterize their air quality in relation to the one-hour sulfur dioxideSO2 NAAQS. Under the proposed rule, the EPA expects to designate areas as attaining, or not attaining, the one-hour SO2 NAAQS in December 2017 or December 2020, depending on whether the Federal Register in May 2014.area was characterized through modeling or monitoring. Hawaiian Electric will work with the Department of Health ofDOH in implementing the State of Hawaii (DOH)one-hour SO2 NAAQS and the EPA in the rulemaking process for these implementation plans to ensure development ofdeveloping cost-effective strategies for NAAQS compliance. Based on the February 6, 2013 EPA guidance document, current estimates of the compliance, date for the one-hour sulfur dioxide NAAQS is in the 2022 or later timeframe. Pending litigation may result in an accelerated timeframe, but the impact of the litigation cannot be predicted at this time.if needed.
Depending upon the final outcome of the CWA 316(b) regulations, the specific measures required for compliance with the CWA 316(b) regulations and MATS, compliance, and the rules and guidance developed for implementation ofcompliance with the more stringent National Ambient Air Quality Standards,NAAQS, the Utilities may be required to incur material capital expenditures and other compliance costs, but such amounts and their timing are not determinable at this time. Additionally, the combined effects of these regulatory initiatives may result in a decision to retire or deactivate certain generating units earlier than anticipated.
Hawaiian Electric, Hawaii Electric Light and Maui Electric, like other utilities, periodically experienceencounter petroleum or other chemical releases into the environment associated with current or previous operations and 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 adverse effect, individually or in the aggregate, on Hawaiian Electric’s consolidated results of operations, financial condition or liquidity.
Potential Clean Air Act Enforcement.On July 1, 2013, Hawaii Electric Light and Maui Electric received a letter from the U.S. Department of Justice (DOJ) asserting potential violations of the Prevention of Significant Deterioration (PSD)

15


and Title V requirements of the Clean Air Act involving the Hill and Kahului Power Plants. The EPA referred the matter to the DOJ for enforcement based on Hawaii Electric Light’s and Maui Electric’s responses to information requests in 2010 and 2012. The letter expresses an interest in resolving the matter without the issuance of a notice of violation. The parties had preliminary discussions in February 2014, and plan to continue working toward resolving the matter. Hawaii Electric Light and Maui Electric cannot currently estimate the amount or effect of a settlement, if any.

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 EPA has since performed Brownfield assessments of the Site that identified environmental impacts in the subsurface. Although Maui Electric never operated at the Site and operations there had stopped four years before the merger, in discussions with the EPA and the 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 impacts of subsurface contaminants. 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, fuel oils, and other subsurface contaminants. In March 2012, Maui Electric accrued an additional $3.1 million (reserve balance of $3.6 million as of March 31,June 30, 2014) for 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. Maui Electric received DOH and EPA comments on a draft site investigation plan for site characterization in the fourth quarter of 2013. Management concluded that these comments did not require a change to the reserve balance. Maui Electric provided

14


written responses to the agencies’ comments in March 2014, and is currently awaiting approval of those responses by both agencies prior to revising the draft site investigation plan accordingly.
Pearl Harbor sediment study. The Navy is conducting a feasibility study for the remediation of contaminated sediment in Pearl Harbor. In the course of its study, the Navy has identified elevated levels of PCBs in the sediment offshore from the Waiau Power Plant. The results of the Navy’s study to date, including sampling data and possible remediation approaches, are undergoing further federal review. Hawaiian Electric is also reviewing the study in order to determine the scope of investigation needed to identify the potential source of contamination and develop appropriate remedial actions. 
The Navy recently notified Hawaiian Electric of the Navy’s determination that Hawaiian Electric is responsible for clean up of the area offshore of the Waiau Power Plant, and the costs incurred by the Navy to investigate the area. The Navy is asking Hawaiian Electric to engage in negotiations regarding the financing and undertaking of future response actions. The extent of the contamination, the appropriate remedial measures to address it, and Hawaiian Electric’s potential responsibility for any associated costs have not yet been determined.
Global climate change and greenhouse gas emissions reduction.  National and international concern about climate change and the contribution of greenhouse gas (GHG) emissions (including carbon dioxide emissions from the combustion of fossil fuels) to climate change have led to action by the State and to federal legislative and regulatory proposals to reduce GHG emissions.
In July 2007, Act 234, which requires a statewide reduction of GHG emissions by January 1, 2020 to levels at or below the statewide GHG emission levels in 1990, became law in Hawaii. The Utilities participated in a Task Force established underOn June 20, 2014, the Governor signed the final regulations required to implement Act 234 which was charged with developing a work plan and regulatory approach to reduce GHG emissions, as well as in initiatives aimed at reducing their GHG emissions, such as those being implemented under the Energy Agreement. On October 19, 2012, the DOH posted the proposed regulations required by Act 234 for public hearing and comment.went into effect on June 30, 2014. In general, the proposed regulations wouldwill require affected sources that have the potential to emit GHGs in excess of established thresholds to reduce GHG emissions by 25%16% below 2010 emission levels by 2020. The proposed regulations will also assess affected sources an annual fee based on tons per year of GHG emissions beginning with emissions in calendar year 2012.commencing on the effective date of the regulations, estimated to be approximately $0.4 million annually for the Utilities. The proposed DOH GHG ruleregulations also trackstrack the federal “Prevention of Significant Deterioration and Title V Greenhouse Gas Tailoring Rule” (GHG Tailoring Rule, see below) and would create new thresholds for GHG emissions from new and existing stationary source facilities. Hawaiian Electric submitted comments on the proposed regulations in January 2013. In October 2013, the DOH announced that it intends to issue a final rule that would change the required emission reduction from 25% to 16% and delay the accrual of GHG emissions fees until after the rule is promulgated, among other changes, but the final rule has not yet been formally approved or released. Hawaiian Electric continues to monitor this rulemaking proceeding and will participate in the further development of the regulations.
Several approaches (e.g., “cap and trade”) to GHG emission reduction have been either introduced or discussed in the U.S. Congress; however, no federal legislation has yet been enacted.
On September 22, 2009, the EPA issued its Final Mandatory Reporting of Greenhouse Gases Rule, which requires that sources emitting GHGs above certain threshold levels monitor and report GHG emissions. The Utilities have submitted the required reports for 2010 through 2013 to the EPA. In December 2009, the EPA made the finding that motor vehicle GHG emissions endanger public health or welfare. Since then, the EPA has also issued rules that begin to address GHG emissions from stationary sources, like the Utilities’ EGUs.
In June 2010, the EPA issued its GHG Tailoring Rule. Effective January 2, 2011, underRule covering the Prevention of Significant Deterioration program, permitting of new or modified stationary sources that have the potential to emit GHGs in greater quantities than the thresholds set forth in the rule, under the Prevention of

16


Significant Deterioration program. On June 23, 2014, the U.S. Supreme Court issued a decision that invalidated the GHG Tailoring Rule, will entailto the extent it regulated sources based solely on their GHG emissions. It also invalidated the GHG emissions evaluation, analysisthreshold for regulation. The current status of the GHG Tailoring Rule, and potentially, control requirements. any further regulatory action the EPA may take in light of this recent decision, are uncertain.
On January 8, 2014, the EPA published in the Federal Register its new proposal for New Source Performance Standards for GHG from new generating units. ThisThe proposed rule on GHG from new EGUs does not apply to oil-firedoil- fired combustion turbines or diesel engine generators, and is not otherwise expected to have significant impacts on the Utilities. President Obama also directed
On June 18, 2014, the EPA Administratorpublished in the Federal Register its proposed rule for GHG emissions from existing power plants. The rule sets interim and final state-wide, state-specific emission performance goals, expressed as lb CO2/MWh, that would apply to the state’s affected sources. The interim goal would apply as an average over the period 2020 through 2029, with the final goal to be met by 2030. On the same date, the EPA also published a separate rule for modified and reconstructed power plants. The EPA’s plan is to issue the final rules no later than June 1, 2015. Hawaiian Electric is still evaluating the proposed standards, regulations, or guidelinesrules for GHG emissions from existing, modified, and reconstructed power plants by no later than June 1, 2014,sources, and final standards no later than June 1, 2015.how they might relate to the recently issued State GHG rules. Hawaiian Electric will participate in the federal GHG rulemaking process.process, and in the implementation of the State GHG rules, to try to reconcile federal GHG regulation, state GHG regulation, and any action the EPA may take as a result of the recent U.S. Supreme Court opinion, to facilitate clear and cost-effective compliance. The Utilities will continue to evaluate the impact of proposed GHG rules and regulations as they develop. Final regulations may impose significant compliance costs, and may require reductions in fossil fuel use and the addition of renewable energy resources in excess of the requirements of the RPS law.
While the timing, extent and ultimate effects of climate change cannot be determined with any certainty, climate change is predicted to result in sea level rise, which could potentially impact coastal and other low-lying areas (where much of the Utilities’ electric infrastructure is sited), and could cause erosion of beaches, saltwater intrusion into aquifers and surface ecosystems, higher water tables and increased flooding and storm damage due to heavy rainfall. The effects of climate change on the weather (for example, floods or hurricanes), sea levels, and water availability and quality have the potential to materially adversely affect the results of operations, financial condition and liquidity of the Utilities. For example, severe weather could cause significant harm to the Utilities’ physical facilities.
The Utilities have taken, and continue to identify opportunities to take, direct action to reduce GHG emissions from their operations, including, but not limited to, supporting DSM programs that foster energy efficiency, using renewable resources for energy production and purchasing power from IPPs generated by renewable resources, burning renewable biodiesel in Hawaiian Electric’s CIP CT-1, using biodiesel for startup and shutdown of selected Maui Electric generating units, and testing biofuel blends in other Hawaiian Electric and Maui Electric generating units. The Utilities are also working with the State of Hawaii and other entities to pursue the use of liquefied natural gas as a cleaner and lower cost fuel to replace, at least in part, the petroleum oil that would otherwise be used. Management is unable to evaluate the ultimate impact on the Utilities’

15


operations of eventual comprehensive GHG regulation. However, management believes that the various initiatives it is undertaking will provide a sound basis for managing the Utilities’ carbon footprint and meeting GHG reduction goals that will ultimately emerge.
Asset retirement obligations.  Asset retirement obligations (AROs) represent legal obligations associated with the retirement of certain tangible long-lived assets, are measured as the present value of the projected costs for the future retirement of specific assets and are recognized in the period in which the liability is incurred if a reasonable estimate of fair value can be made. The Utilities' recognition of AROs have no impact on their earnings. The cost of the AROs is recovered over the life of the asset through depreciation. AROs recognized by the Utilities relate to obligations to retire plant and equipment, including removal of asbestos and other hazardous materials.
Changes to the ARO liability included in “Other liabilities” on Hawaiian Electric’s balance sheet were as follows:
 Three months ended March 31 Six months ended June 30
(in thousands) 2014 2013 2014 2013
Balance, beginning of period $43,106
 $48,431
 $43,106
 $48,431
Accretion expense 370
 124
 643
 363
Liabilities incurred —
 —
 —
 —
Liabilities settled (2,240) (642) (6,052) (1,506)
Revisions in estimated cash flows —
 —
 —
 (916)
Balance, end of period $41,236
 $47,913
 $37,697
 $46,372

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Decoupling. In 2010, the PUC issued an order approving decoupling, which was implemented by Hawaiian Electric on March 1, 2011, by Hawaii Electric Light on April 9, 2012 and by Maui Electric on May 4, 2012. Decoupling is a regulatory model that is intended to facilitate meeting the State of Hawaii’s goals to transition to a clean energy economy and achieve an aggressive renewable portfolio standard. The decoupling model implemented in Hawaii delinks revenues from sales and includes annual revenue adjustments for certain O&M expenses and rate base changes. The decoupling mechanism has three components: (1) a sales decoupling component via a revenue balancing account (RBA), (2) a revenue escalation component via a revenue adjustment mechanism (RAM) and (3) an earnings sharing mechanism, which would provide for a reduction of revenues between rate cases in the event the utility exceeds the ROACE allowed in its most recent rate case. Decoupling provides for more timely cost recovery and earning on investments. The implementation of decoupling has resulted in an improvement in the Utilities’ under-earning situation that has existed over the last several years. Prior to and during the transition to decoupling, however, the Utilities’ returns have been below PUC-allowed returns.
On May 31, 2013, as provided for in its original order issued in 2010 approving decoupling and citing three years of implementation experience for Hawaiian Electric, the PUC opened an investigative docket to review whether the decoupling mechanisms are functioning as intended, are fair to the Utilities and their ratepayers, and are in the public interest. The PUC affirmed its support for the continuation of the sales decoupling (RBA) mechanism and stated its interest in evaluating the RAM to ensure it provides the appropriate balance of risks, costs, incentives and performance requirements, as well as administrative efficiency, and whether the current interest rate applied to the outstanding RBA balance is reasonable. The Utilities and the Consumer Advocate arewere named as parties to this proceeding and filed a joint statement of position that any material changes to the current decoupling mechanism should be made prospectively after 2016, unless the Utilities and the Consumer Advocate mutually agree to the change in this proceeding. The PUC granted several parties’ motions to intervene. In October 2013, the PUC issued orders that bifurcated the proceeding (Schedule A and Schedule B) and identified issues and procedural schedules for both Schedules. The schedule B part of the proceeding is intended to take place over a longer period, with panel hearings scheduled for August 2014.
Schedule A issues include:
for the RBA, the reasonableness of the interest rate related to the carrying charge of the outstanding RBA balance and whether there should be a risk sharing adjustment to the RBA;
for the RAM, whether it is reasonable to true up all actual prior year baseline projects, which are those capital projects less than $2.5 million, at year end or implement alternative methods to calculate the RAM rate base;
whether a risk sharing mechanism should be incorporated into the RBA;
whether performance metrics should be determined and reported; and
whether other factors should be considered if potential changes to existing RBA and RAM provisions are required.
Schedule B issues include:
whether performance metrics and incentives (rewards or penalties) should be implemented to control costs and encourage the Utilities to make necessary or appropriate changes to strategic and action plans;

16


whether the allocation of risk as a result of the decoupling mechanism is fairly reflected in the cost of capital allowed in rates;
changes or alternatives to the existing RAM; and
changes to ratemaking procedures to improve efficiency and/or effectiveness.
Oral arguments on Schedule A issues were held in January 2014. On February 7, 2014, the PUC issued a D&O on the Schedule A issues, which made certain modifications to the decoupling mechanism. Specifically, the D&O requires:
An adjustment to the Rate Base RAM Adjustment to include 90% of the amount of the current RAM Period Rate Base RAM Adjustment that exceeds the Rate Base RAM Adjustment from the prior year, to be effective with the Utilities’ 2014 decoupling filing.
Effective March 1, 2014, the interest rate to be applied on the outstanding RBA balances to be the short term debt rate used in each Utilities last rate case (ranging from 1.25% to 3.25%), instead of the 6% that had been previously approved.
The D&O requiresrequired the Utilities to immediately investigate the possibility of deferring the payment of income taxes on the accrued amounts of decoupling revenue, and to report the results with recommendations to the PUC within 120 days.PUC. The PUC reservesreserved the right to determine in the next decoupling and rate case filings whether each Utilities’ allowed income taxes should be adjusted for this change.
As required, the Utilities developed websites to present certain Schedule A performance metrics and proposed additional performance metrics, which are all currently being reviewed by the PUC and the parties and, after PUC approval, will be available to the public. The Utilities also updated the PUC on their progress in investigating the tax treatment of the revenues included in the RBA balances and provided information to the PUC concerning the application to the IRS for an accounting methods change.change to recognize RBA revenues for tax purposes when amounts are billed. On April 28, 2014, the Utilities received approval for this change from the IRS, effective January 1, 2014. HEI expects to execute a consent agreement with the IRS and will include the effects of this change in its estimated income tax payments for 2014. This change will reduce the amount of interest to be accrued on the RBA balance as proposed by the Consumer Advocate (see "Recent tax developments" above).

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As required, the Utilities developed websites to present certain Schedule A performance metrics and proposed additional performance metrics. These metrics are all currently being reviewed by the PUC and, if approved, will be available to the public.
The Schedule A issues on whether it is reasonable to automatically include all actual prior year capital expenditures on baseline projects in the Rate Base RAM and whether a risk sharing mechanism should be incorporated into the RBA, particularly with respect to the PUC’s concerns regarding maintaining and enhancing the Utilities' incentives to control costs and appropriately allocating risk and compensation for risk, will be addressed in the Schedule B proceedings.
On May 20, 2014, the Utilities and other parties filed their respective initial statements of position for the Schedule B issues in this proceeding. Specifically, the Utilities concluded that (1) the existing RAM provision can be modified to address concerns stated by the PUC regarding the review of baseline capital projects and the growth in plant additions, and (2) targeted incentives can be crafted to incentivize the activities identified by the PUC.
The Utilities and other parties are scheduled to file their respective reply statements of position for Schedule B issues in September 2014. The second part of this proceeding will continue with panel hearings scheduled for October 2014.
Management cannot predict the outcome of the proceedings or the ultimate impact of the proceedings on the results of operation of the Utilities.
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 four orders are 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 also terminated the Utilities' integrated resource planning (IRP) cycle, including the filing of a mid-cycle evaluation report, and formally concluded the IRP advisory group. The PUC directed each of Hawaiian Electric and Maui Electric to file within 120 days its respective Power Supply Improvement Plans (PSIPs). The PSIPs will be reviewed by the PUC in a new docket. The PUC also directed the Utilities to file within 90 days aan integrated Demand Response Portfolio Plan. The Utilities’ Plan was filed in July 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 (and in some cases the Kauai Island Utility Cooperative (KIUC)) 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 which include the following:
Distributed Generation Interconnection Plan to be filed within 120 days.
Plan to implement an on-going distribution circuit monitoring program to measure real-time voltage and other power quality parameters to be filed within 60 days. The plan shall achieve full implementation of the distribution circuit monitoring program within 180 days. The Utilities' Plan was filed in June 2014.
Action Plan for improving efficiencies in the interconnection requirements studies to be filed within 30 days. The Utilities' Plan was filed in May 2014.
The Utilities are to file monthly reports providing details about interconnection requirements studies.
Proposal to implement an integrated interconnection queue for each distribution circuit for each island grid to be filed within 120 days.

17


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 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.
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 within 90 days an integrated Demand Response Portfolio Plan that will enhance system operations and reduce costs to customers. The Utilities’ Plan was filed in July 2014.
Maui Electric Company 2012 Test Year Rate Case. The PUC acknowledged the extensive analyses provided by Maui Electric in its System Improvement and Curtailment Reduction Plan filed in September 2013. The PUC stated that it is encouraged by the changes in Maui Electric’s operations that have led to a significant reduction in the curtailment of

19


renewables, but stated that Maui Electric has not set forth a clearly defined path that addresses integration and curtailment of additional renewables. The PUC directed Maui Electric to present a PSIP within 120 days to address present and future system operations so as to not only reduce curtailment, but to optimize the operation of its system for its customers’ benefit.
Collectively, these orders confirm the energy policy and operational priorities that will guide the Utilities' strategies and plans going forward.

Subsequent event. In August 2014, Hawaiian Electric entered into a 15-year agreement with Fortis BC Energy Inc. (Fortis) for liquefaction capacity for liquefied natural gas (LNG) under tariffed rates approved by the British Columbia Utilities Commission. The agreement, which is subject to Hawaii PUC approval, other regulatory approvals and permits, and other conditions precedent before it becomes effective, provides for LNG liquefaction capacity purchases of 800,000 tonnes per year for the first five years, 700,000 tonnes per year for the next five years, and 600,000 tonnes per year for the last five years. Fortis must also obtain regulatory and other approvals for the agreement to become effective. The Fortis agreement is assignable and can be assigned to the selected bidder in the Utilities’ RFP for the supply of containerized LNG and will help ensure that liquefaction capacity is available at pricing that management believes will lower customer bills.
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 HECO Capital Trust III (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.

18


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Income (unaudited)
Three months ended March 31, 2014
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries Consolidating adjustments Hawaiian Electric
Consolidated
Revenues $512,455
 104,931
 102,693
 —
 (17) $720,062
Expenses            
Fuel oil 203,547
 31,500
 51,253
 —
 —
 286,300
Purchased power 123,969
 29,491
 11,456
 —
 —
 164,916
Other operation and maintenance 58,515
 14,047
 16,044
 —
 —
 88,606
Depreciation 27,301
 8,975
 5,327
 —
 —
 41,603
Taxes, other than income taxes 48,184
 9,763
 10,024
 —
 —
 67,971
   Total expenses 461,516
 93,776
 94,104
 —
 —
 649,396
Operating income 50,939
 11,155
 8,589
 —
 (17) 70,666
Allowance for equity funds used during construction 1,472
 65
 72
 —
 —
 1,609
Equity in earnings of subsidiaries 8,917
 —
 —
 —
 (8,917) —
Interest expense and other charges, net (10,487) (2,748) (2,505) —
 17
 (15,723)
Allowance for borrowed funds used during construction 559
 25
 30
 —
 —
 614
Income before income taxes 51,400
 8,497
 6,186
 —
 (8,917) 57,166
Income taxes 15,710
 3,202
 2,335
 —
 —
 21,247
Net income 35,690
 5,295
 3,851
 —
 (8,917) 35,919
Preferred stock dividends of subsidiaries —
 134
 95
 —
 —
 229
Net income attributable to Hawaiian Electric 35,690
 5,161
 3,756
 —
 (8,917) 35,690
Preferred stock dividends of Hawaiian Electric 270
 —
 —
 —
 —
 270
Net income for common stock $35,420
 5,161
 3,756
 —
 (8,917) $35,420

Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Comprehensive Income (Loss) (unaudited)
Three months ended March 31, 2014
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric 
Other
subsidiaries
 
Consolidating
adjustments
 Hawaiian Electric
Consolidated
Net income for common stock $35,420
 5,161
 3,756
 —
 (8,917) $35,420
Other comprehensive income (loss), net of taxes:  
  
  
  
  
  
Retirement benefit plans:  
  
  
  
  
  
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits 2,519
 344
 253
 —
 (597) 2,519
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes (2,510) (344) (253) —
 597
 (2,510)
Other comprehensive income, net of taxes 9
 —
 —
 —
 —
 9
Comprehensive income attributable to common shareholder $35,429
 5,161
 3,756
 —
 (8,917) $35,429

1920


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Income (unaudited)
Three months ended March 31, 2013June 30, 2014

(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 $507,058
 106,012
 104,399
 —
 (28) $717,441
 $530,991
 103,544
 103,916
 —
 (22) $738,429
Expenses                        
Fuel oil 221,967
 32,936
 50,197
 —
 —
 305,100
 195,549
 31,179
 43,529
 —
 —
 270,257
Purchased power 111,155
 30,122
 12,087
 —
 —
 153,364
 140,805
 28,170
 19,348
 —
 —
 188,323
Other operation and maintenance 72,418
 14,888
 14,507
 —
 —
 101,813
 68,992
 14,817
 14,755
 —
 —
 98,564
Depreciation 24,707
 8,547
 5,026
 —
 —
 38,280
 27,300
 8,976
 5,317
 —
 —
 41,593
Taxes, other than income taxes 48,144
 9,691
 9,928
 —
 —
 67,763
 49,949
 9,757
 9,918
 —
 —
 69,624
Total expenses 478,391
 96,184
 91,745
 —
 —
 666,320
 482,595
 92,899
 92,867
 —
 —
 668,361
Operating income 28,667
 9,828
 12,654
 —
 (28) 51,121
 48,396
 10,645
 11,049
 —
 (22) 70,068
Allowance for equity funds used during construction 983
 138
 94
 —
 —
 1,215
 1,417
 121
 (151) —
 —
 1,387
Equity in earnings of subsidiaries 10,985
 —
 —
 —
 (10,985) —
 9,859
 —
 —
 —
 (9,859) —
Interest expense and other charges, net (9,590) (2,855) (2,102) —
 28
 (14,519) (11,553) (2,852) (2,469) —
 22
 (16,852)
Allowance for borrowed funds used during construction 568
 92
 70
 —
 —
 730
 535
 47
 (59) —
 —
 523
Income before income taxes 31,613
 7,203
 10,716
 —
 (10,985) 38,547
 48,654
 7,961
 8,370
 —
 (9,859) 55,126
Income taxes 6,914
 2,649
 4,056
 —
 —
 13,619
 14,154
 2,982
 3,261
 —
 —
 20,397
Net income 24,699
 4,554
 6,660
 —
 (10,985) 24,928
 34,500
 4,979
 5,109
 —
 (9,859) 34,729
Preferred stock dividends of subsidiaries —
 134
 95
 —
 —
 229
 —
 133
 96
 —
 —
 229
Net income attributable to Hawaiian Electric 24,699
 4,420
 6,565
 —
 (10,985) 24,699
 34,500
 4,846
 5,013
 —
 (9,859) 34,500
Preferred stock dividends of Hawaiian Electric 270
 —
 —
 —
 —
 270
 270
 —
 —
 —
 —
 270
Net income for common stock $24,429
 4,420
 6,565
 —
 (10,985) $24,429
 $34,230
 4,846
 5,013
 —
 (9,859) $34,230

Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Comprehensive Income (unaudited)
Three months ended June 30, 2014
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric 
Other
subsidiaries
 
Consolidating
adjustments
 Hawaiian Electric
Consolidated
Net income for common stock $34,230
 4,846
 5,013
 —
 (9,859) $34,230
Other comprehensive income, net of taxes:  
  
  
  
  
  
Retirement benefit plans:  
  
  
  
  
  
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits 2,588
 292
 292
 —
 (584) 2,588
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes (2,575) (292) (292) —
 584
 (2,575)
Other comprehensive income, net of taxes 13
 —
 —
 —
 —
 13
Comprehensive income attributable to common shareholder $34,243
 4,846
 5,013
 —
 (9,859) $34,243

21


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Income (unaudited)
Three months ended June 30, 2013
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries Consolidating adjustments Hawaiian Electric
Consolidated
Revenues $521,576
 106,361
 100,627
 —
 (39) $728,525
Expenses            
Fuel oil 203,379
 33,569
 52,330
 —
 —
 289,278
Purchased power 135,271
 29,278
 13,895
 —
 —
 178,444
Other operation and maintenance 68,558
 14,477
 11,361
 1
 —
 94,397
Depreciation 25,001
 8,547
 5,042
 —
 —
 38,590
Taxes, other than income taxes 49,357
 9,965
 9,519
 —
 —
 68,841
   Total expenses 481,566
 95,836
 92,147
 1
 —
 669,550
Operating income (loss) 40,010
 10,525
 8,480
 (1) (39) 58,975
Allowance for equity funds used during construction 1,247
 192
 121
 —
 —
 1,560
Equity in earnings of subsidiaries 8,667
 —
 —
 —
 (8,667) —
Interest expense and other charges, net (9,250) (2,791) (2,406) —
 39
 (14,408)
Allowance for borrowed funds used during construction 342
 43
 13
 —
 —
 398
Income (loss) before income taxes 41,016
 7,969
 6,208
 (1) (8,667) 46,525
Income taxes 12,053
 2,956
 2,324
 —
 —
 17,333
Net income (loss) 28,963
 5,013
 3,884
 (1) (8,667) 29,192
Preferred stock dividends of subsidiaries —
 133
 96
 —
 —
 229
Net income (loss) attributable to Hawaiian Electric 28,963
 4,880
 3,788
 (1) (8,667) 28,963
Preferred stock dividends of Hawaiian Electric 270
 —
 —
 —
 —
 270
Net income (loss) for common stock $28,693
 4,880
 3,788
 (1) (8,667) $28,693

Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Comprehensive Income (Loss) (unaudited)
Three months ended March 31,June 30, 2013
(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 $24,429
 4,420
 6,565
 —
 (10,985) $24,429
Net income (loss) for common stock $28,693
 4,880
 3,788
 (1) (8,667) $28,693
Other comprehensive income (loss), net of taxes:  
  
  
  
  
  
  
  
  
  
  
  
Retirement benefit plans:  
  
  
  
  
  
  
  
  
  
  
  
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits 5,331
 759
 657
 —
 (1,416) 5,331
 5,016
 681
 622
 —
 (1,303) 5,016
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes (5,313) (761) (656) —
 1,417
 (5,313) (4,999) (680) (623) —
 1,303
 (4,999)
Other comprehensive income (loss), net of taxes 18
 (2) 1
 —
 1
 18
 17
 1
 (1) —
 —
 17
Comprehensive income attributable to common shareholder $24,447
 4,418
 6,566
 —
 (10,984) $24,447
Comprehensive income (loss) attributable to common shareholder $28,710
 4,881
 3,787
 (1) (8,667) $28,710


2022


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Income (unaudited)
Six months ended June 30, 2014
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries Consolidating adjustments Hawaiian Electric
Consolidated
Revenues $1,043,446
 208,475
 206,609
 —
 (39) $1,458,491
Expenses            
Fuel oil 399,096
 62,679
 94,782
 —
 —
 556,557
Purchased power 264,774
 57,661
 30,804
 —
 —
 353,239
Other operation and maintenance 127,507
 28,864
 30,799
 —
 —
 187,170
Depreciation 54,601
 17,951
 10,644
 —
 —
 83,196
Taxes, other than income taxes 98,133
 19,520
 19,942
 —
 —
 137,595
   Total expenses 944,111
 186,675
 186,971
 —
 —
 1,317,757
Operating income 99,335
 21,800
 19,638
 —
 (39) 140,734
Allowance for equity funds used during construction 2,889
 186
 (79) —
 —
 2,996
Equity in earnings of subsidiaries 18,776
 —
 —
 —
 (18,776) —
Interest expense and other charges, net (22,040) (5,600) (4,974) —
 39
 (32,575)
Allowance for borrowed funds used during construction 1,094
 72
 (29) —
 —
 1,137
Income before income taxes 100,054
 16,458
 14,556
 —
 (18,776) 112,292
Income taxes 29,864
 6,184
 5,596
 —
 —
 41,644
Net income 70,190
 10,274
 8,960
 —
 (18,776) 70,648
Preferred stock dividends of subsidiaries —
 267
 191
 —
 —
 458
Net income attributable to Hawaiian Electric 70,190
 10,007
 8,769
 —
 (18,776) 70,190
Preferred stock dividends of Hawaiian Electric 540
 —
 —
 —
 —
 540
Net income for common stock $69,650
 10,007
 8,769
 —
 (18,776) $69,650

Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Comprehensive Income (unaudited)
Six months ended June 30, 2014
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric 
Other
subsidiaries
 
Consolidating
adjustments
 Hawaiian Electric
Consolidated
Net income for common stock $69,650
 10,007
 8,769
 —
 (18,776) $69,650
Other comprehensive income, net of taxes:  
  
  
  
  
  
Retirement benefit plans:  
  
  
  
  
  
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits 5,107
 636
 545
 —
 (1,181) 5,107
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes (5,085) (636) (545) —
 1,181
 (5,085)
Other comprehensive income, net of taxes 22
 —
 —
 —
 —
 22
Comprehensive income attributable to common shareholder $69,672
 10,007
 8,769
 —
 (18,776) $69,672

23


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Income (unaudited)
Six months ended June 30, 2013

(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric Other subsidiaries Consolidating adjustments Hawaiian Electric
Consolidated
Revenues $1,028,634
 212,373
 205,026
 —
 (67) $1,445,966
Expenses            
Fuel oil 425,346
 66,505
 102,527
 —
 —
 594,378
Purchased power 246,426
 59,400
 25,982
 —
 —
 331,808
Other operation and maintenance 140,976
 29,365
 25,868
 1
 —
 196,210
Depreciation 49,708
 17,094
 10,068
 —
 —
 76,870
Taxes, other than income taxes 97,501
 19,656
 19,447
 —
 —
 136,604
   Total expenses 959,957
 192,020
 183,892
 1
 —
 1,335,870
Operating income (loss) 68,677
 20,353
 21,134
 (1) (67) 110,096
Allowance for equity funds used during construction 2,230
 330
 215
 —
 —
 2,775
Equity in earnings of subsidiaries 19,652
 —
 —
 —
 (19,652) —
Interest expense and other charges, net (18,840) (5,646) (4,508) —
 67
 (28,927)
Allowance for borrowed funds used during construction 910
 135
 83
 —
 —
 1,128
Income (loss) before income taxes 72,629
 15,172
 16,924
 (1) (19,652) 85,072
Income taxes 18,967
 5,605
 6,380
 —
 —
 30,952
Net income (loss) 53,662
 9,567
 10,544
 (1) (19,652) 54,120
Preferred stock dividends of subsidiaries —
 267
 191
 —
 —
 458
Net income (loss) attributable to Hawaiian Electric 53,662
 9,300
 10,353
 (1) (19,652) 53,662
Preferred stock dividends of Hawaiian Electric 540
 —
 —
 —
 —
 540
Net income (loss) for common stock $53,122
 9,300
 10,353
 (1) (19,652) $53,122

Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Comprehensive Income (Loss) (unaudited)
Six months ended June 30, 2013
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric 
Other
subsidiaries 
 
Consolidating
adjustments
 Hawaiian Electric
Consolidated
Net income (loss) for common stock
 $53,122
 9,300
 10,353
 (1) (19,652) $53,122
Other comprehensive income (loss), net of taxes:  
  
  
  
  
  
Retirement benefit plans:  
  
  
  
  
  
Less: amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits 10,347
 1,440
 1,279
 —
 (2,719) 10,347
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets, net of taxes (10,312) (1,441) (1,279) —
 2,720
 (10,312)
Other comprehensive income (loss), net of taxes 35
 (1) —
 —
 1
 35
Comprehensive income (loss) attributable to common shareholder $53,157
 9,299
 10,353
 (1) (19,651) $53,157

24


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Balance Sheet (unaudited)
March 31,June 30, 2014
(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 $43,367
 5,462
 3,016
 —
 —
 $51,845
 $43,530
 5,464
 3,016
 —
 —
 $52,010
Plant and equipment 3,606,787
 1,141,789
 1,014,323
 —
 —
 5,762,899
 3,655,958
 1,147,841
 1,026,924
 —
 —
 5,830,723
Less accumulated depreciation (1,234,520) (459,712) (440,228) —
 —
 (2,134,460) (1,239,994) (465,966) (444,953) —
 —
 (2,150,913)
Construction in progress 127,187
 9,657
 11,758
 —
 —
 148,602
 139,149
 14,669
 14,462
 —
 —
 168,280
Utility property, plant and equipment, net 2,542,821
 697,196
 588,869
 —
 —
 3,828,886
 2,598,643
 702,008
 599,449
 —
 —
 3,900,100
Nonutility property, plant and equipment, less accumulated depreciation 4,953
 82
 1,531
 —
 —
 6,566
 4,951
 82
 1,531
 —
 —
 6,564
Total property, plant and equipment, net 2,547,774
 697,278
 590,400
 —
 —
 3,835,452
 2,603,594
 702,090
 600,980
 —
 —
 3,906,664
Investment in wholly owned subsidiaries, at equity 526,020
 —
 —
 —
 (526,020) —
 529,461
 —
 —
 —
 (529,461) —
Current assets  
  
  
  
  
  
  
  
  
  
  
  
Cash and cash equivalents 12,952
 2,442
 1,864
 101
 —
 17,359
 8,106
 1,754
 2,759
 101
 —
 12,720
Advances to affiliates 19,500
 100
 —
 —
 (19,600) —
 23,600
 —
 —
 —
 (23,600) —
Customer accounts receivable, net 114,517
 26,004
 23,495
 —
 —
 164,016
 122,400
 27,465
 25,769
 —
 —
 175,634
Accrued unbilled revenues, net 96,721
 17,330
 17,813
 —
 —
 131,864
 106,694
 17,452
 17,723
 —
 —
 141,869
Other accounts receivable, net 19,007
 4,320
 2,840
 —
 (9,477) 16,690
 20,095
 6,415
 2,052
 —
 (9,647) 18,915
Fuel oil stock, at average cost 134,673
 13,012
 20,662
 —
 —
 168,347
 123,070
 12,517
 25,706
 —
 —
 161,293
Materials and supplies, at average cost 37,707
 7,270
 15,112
 —
 —
 60,089
 37,606
 7,129
 16,144
 —
 —
 60,879
Prepayments and other 17,931
 2,707
 12,958
 —
 (1,297) 32,299
 43,057
 7,185
 11,900
 —
 (251) 61,891
Regulatory assets 62,643
 6,958
 7,854
 —
 —
 77,455
 64,210
 6,947
 7,788
 —
 —
 78,945
Total current assets 515,651
 80,143
 102,598
 101
 (30,374) 668,119
 548,838
 86,864
 109,841
 101
 (33,498) 712,146
Other long-term assets  
  
  
  
  
  
  
  
  
  
  
  
Regulatory assets 378,608
 64,379
 59,521
 —
 —
 502,508
 380,993
 64,159
 58,548
 —
 —
 503,700
Unamortized debt expense 6,195
 1,533
 1,396
 —
 —
 9,124
 6,020
 1,532
 1,353
 —
 —
 8,905
Other 42,110
 11,351
 13,925
 —
 —
 67,386
 42,662
 11,565
 14,199
 —
 —
 68,426
Total other long-term assets 426,913
 77,263
 74,842
 —
 —
 579,018
 429,675
 77,256
 74,100
 —
 —
 581,031
Total assets $4,016,358
 854,684
 767,840
 101
 (556,394) $5,082,589
 $4,111,568
 866,210
 784,921
 101
 (562,959) $5,199,841
Capitalization and liabilities  
  
  
  
  
  
  
  
  
  
  
  
Capitalization  
  
  
  
  
  
  
  
  
  
  
  
Common stock equity $1,606,283
 277,022
 248,897
 101
 (526,020) $1,606,283
 $1,618,987
 278,995
 250,365
 101
 (529,461) $1,618,987
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 830,546
 189,999
 186,000
 —
 —
 1,206,545
 830,546
 189,999
 186,000
 —
 —
 1,206,545
Total capitalization 2,459,122
 474,021
 439,897
 101
 (526,020) 2,847,121
 2,471,826
 475,994
 441,365
 101
 (529,461) 2,859,825
Current liabilities  
  
  
  
  
  
  
  
  
  
  
  
Current portion of long-term debt —
 11,400
 —
 —
 —
 11,400
 —
 11,400
 —
 —
 —
 11,400
Short-term borrowings from non-affiliates 34,996
 —
 —
 —
 —
 34,996
 102,989
 —
 —
 —
 —
 102,989
Short-term borrowings from affiliate 100
 —
 19,500
 —
 (19,600) —
 —
 3,400
 20,200
 —
 (23,600) —
Accounts payable 151,818
 18,953
 12,055
 —
 —
 182,826
 114,803
 18,434
 20,506
 —
 —
 153,743
Interest and preferred dividends payable 16,400
 3,882
 3,826
 —
 (8) 24,100
 14,827
 4,177
 2,755
 —
 (8) 21,751
Taxes accrued 133,801
 31,545
 29,685
 —
 (1,297) 193,734
 150,709
 33,058
 32,858
 —
 (251) 216,374
Regulatory liabilities 1,135
 —
 302
 —
 —
 1,437
 453
 —
 336
 —
 —
 789
Other 47,374
 9,950
 14,621
 —
 (9,469) 62,476
 49,370
 9,391
 15,447
 —
 (9,639) 64,569
Total current liabilities 385,624
 75,730
 79,989
 —
 (30,374) 510,969
 433,151
 79,860
 92,102
 —
 (33,498) 571,615
Deferred credits and other liabilities  
  
  
  
  
  
  
  
  
  
  
  
Deferred income taxes 365,668
 80,454
 68,919
 —
 —
 515,041
 399,826
 84,147
 73,083
 —
 —
 557,056
Regulatory liabilities 236,468
 78,142
 34,869
 —
 —
 349,479
 240,533
 79,990
 33,668
 —
 —
 354,191
Unamortized tax credits 46,658
 14,457
 14,429
 —
 —
 75,544
 48,386
 14,668
 14,659
 —
 —
 77,713
Defined benefit pension and other postretirement benefit plans liability 199,070
 27,750
 30,781
  
 —
 257,601
 195,599
 26,952
 30,234
  
 —
 252,785
Other 61,762
 13,985
 13,067
 —
 —
 88,814
 57,397
 13,821
 13,059
 —
 —
 84,277
Total deferred credits and other liabilities 909,626
 214,788
 162,065
 —
 —
 1,286,479
 941,741
 219,578
 164,703
 —
 —
 1,326,022
Contributions in aid of construction 261,986
 90,145
 85,889
 —
 —
 438,020
 264,850
 90,778
 86,751
 —
 —
 442,379
Total capitalization and liabilities $4,016,358
 854,684
 767,840
 101
 (556,394) $5,082,589
 $4,111,568
 866,210
 784,921
 101
 (562,959) $5,199,841

2125


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Balance Sheet (unaudited)
December 31, 2013
(in thousands) Hawaiian Electric Hawaii Electric Light Maui Electric 
Other
subsidiaries
 
Consoli-
dating
adjustments
 Hawaiian Electric
Consolidated
Assets  
  
  
  
  
  
Property, plant and equipment            
Utility property, plant and equipment  
  
  
  
  
  
Land $43,407
 5,460
 3,016
 —
 —
 $51,883
Plant and equipment 3,558,569
 1,136,923
 1,006,383
 —
 —
 5,701,875
Less accumulated depreciation (1,222,129) (453,721) (435,379) —
 —
 (2,111,229)
Construction in progress 124,494
 7,709
 11,030
 —
 —
 143,233
Utility property, plant and equipment, net 2,504,341
 696,371
 585,050
 —
 —
 3,785,762
Nonutility property, plant and equipment, less accumulated depreciation 4,953
 82
 1,532
 —
 —
 6,567
Total property, plant and equipment, net 2,509,294
 696,453
 586,582
 —
 —
 3,792,329
Investment in wholly owned subsidiaries, at equity
 523,674
 —
 —
 —
 (523,674) —
Current assets  
  
  
  
  
  
Cash and cash equivalents 61,245
 1,326
 153
 101
 —
 62,825
Advances to affiliates 6,839
 1,000
 —
 —
 (7,839) —
Customer accounts receivable, net 121,282
 28,088
 26,078
 —
 —
 175,448
Accrued unbilled revenues, net 107,752
 17,100
 19,272
 —
 —
 144,124
Other accounts receivable, net 16,373
 4,265
 2,451
 —
 (9,027) 14,062
Fuel oil stock, at average cost 99,613
 14,178
 20,296
 —
 —
 134,087
Materials and supplies, at average cost 37,377
 6,883
 14,784
 —
 —
 59,044
Prepayments and other 29,798
 8,334
 16,140
 —
 (1,415) 52,857
Regulatory assets 54,979
 6,931
 7,828
 —
 —
 69,738
Total current assets 535,258
 88,105
 107,002
 101
 (18,281) 712,185
Other long-term assets  
  
  
  
  
  
Regulatory assets 381,346
 64,552
 60,288
 —
 —
 506,186
Unamortized debt expense 6,051
 1,580
 1,372
 —
 —
 9,003
Other 42,163
 11,270
 13,993
 —
 —
 67,426
Total other long-term assets 429,560
 77,402
 75,653
 —
 —
 582,615
Total assets $3,997,786
 861,960
 769,237
 101
 (541,955) $5,087,129
Capitalization and liabilities  
  
  
  
  
  
Capitalization  
  
  
  
  
  
Common stock equity $1,593,564
 274,802
 248,771
 101
 (523,674) $1,593,564
Cumulative preferred stock—not subject to mandatory redemption 22,293
 7,000
 5,000
 —
 —
 34,293
Long-term debt, net 830,547
 189,998
 186,000
 —
 —
 1,206,545
Total capitalization 2,446,404
 471,800
 439,771
 101
 (523,674) 2,834,402
Current liabilities  
  
  
  
  
  
Current portion of long-term debt —
 11,400
 —
 —
 —
 11,400
Short-term borrowings from affiliate 1,000
 —
 6,839
 —
 (7,839) —
Accounts payable 145,062
 24,383
 20,114
 —
 —
 189,559
Interest and preferred dividends payable 15,190
 3,885
 2,585
 —
 (8) 21,652
Taxes accrued 175,790
 37,899
 37,171
 —
 (1,415) 249,445
Regulatory liabilities 1,705
 —
 211
 —
 —
 1,916
Other 48,443
 9,033
 15,424
 —
 (9,019) 63,881
Total current liabilities 387,190
 86,600
 82,344
 —
 (18,281) 537,853
Deferred credits and other liabilities  
  
  
  
  
  
Deferred income taxes 359,621
 79,947
 67,593
 —
 —
 507,161
Regulatory liabilities 235,786
 76,475
 35,122
 —
 —
 347,383
Unamortized tax credits 44,931
 14,245
 14,363
 —
 —
 73,539
Defined benefit pension and other postretirement benefit plans liability 202,396
 28,427
 31,339
 —
 —
 262,162
Other 63,374
 14,703
 13,658
 —
 —
 91,735
Total deferred credits and other liabilities 906,108
 213,797
 162,075
 —
 —
 1,281,980
Contributions in aid of construction 258,084
 89,763
 85,047
 —
 —
 432,894
Total capitalization and liabilities $3,997,786
 861,960
 769,237
 101
 (541,955) $5,087,129

2226


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Changes in Common Stock Equity (unaudited)
ThreeSix months ended March 31,June 30, 2014
 
(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, 2013 $1,593,564
 274,802
 248,771
 101
 (523,674) $1,593,564
 $1,593,564
 274,802
 248,771
 101
 (523,674) $1,593,564
Net income for common stock 35,420
 5,161
 3,756
 —
 (8,917) 35,420
 69,650
 10,007
 8,769
 —
 (18,776) 69,650
Other comprehensive income, net of taxes 9
 —
 —
 —
 —
 9
 22
 —
 —
 —
 —
 22
Common stock dividends (22,707) (2,941) (3,629) —
 6,570
 (22,707) (44,246) (5,813) (7,175) —
 12,988
 (44,246)
Common stock issuance expenses (3) —
 (1) —
 1
 (3) (3) (1) —
 —
 1
 (3)
Balance, March 31, 2014 $1,606,283
 277,022
 248,897
 101
 (526,020) $1,606,283
Balance, June 30, 2014 $1,618,987
 278,995
 250,365
 101
 (529,461) $1,618,987
 
Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Changes in Common Stock Equity (unaudited)
ThreeSix months ended March 31,June 30, 2013
 
(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, 2012 $1,472,136
 268,908
 228,927
 104
 (497,939) $1,472,136
 $1,472,136
 268,908
 228,927
 104
 (497,939) $1,472,136
Net income for common stock 24,429
 4,420
 6,565
 —
 (10,985) 24,429
Net income (loss) for common stock 53,122
 9,300
 10,353
 (1) (19,652) 53,122
Other comprehensive income (loss), net of taxes 18
 (2) 1
 —
 1
 18
 35
 (1) —
 —
 1
 35
Common stock dividends (20,070) (3,610) (3,442) —
 7,052
 (20,070) (40,789) (7,194) (7,008) —
 14,202
 (40,789)
Balance, March 31, 2013 $1,476,513
 269,716
 232,051
 104
 (501,871) $1,476,513
Balance, June 30, 2013 $1,484,504
 271,013
 232,272
 103
 (503,388) $1,484,504

2327


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Cash Flows (unaudited)
ThreeSix months ended March 31,June 30, 2014
(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 $35,690
 5,295
 3,851
 —
 (8,917) $35,919
 $70,190
 10,274
 8,960
 —
 (18,776) $70,648
Adjustments to reconcile net income to net cash provided by (used in) operating activities:  
  
  
  
  
  
Adjustments to reconcile net income to net cash provided by operating activities:  
  
  
  
  
  
Equity in earnings of subsidiaries (8,942) —
 —
 —
 8,917
 (25) (18,826) —
 —
 —
 18,776
 (50)
Common stock dividends received from subsidiaries 6,595
 —
 —
 —
 (6,570) 25
 13,038
 —
 —
 —
 (12,988) 50
Depreciation of property, plant and equipment 27,301
 8,975
 5,327
 —
 —
 41,603
 54,601
 17,951
 10,644
 —
 —
 83,196
Other amortization 235
 501
 885
 —
 —
 1,621
 554
 1,299
 1,744
 —
 —
 3,597
Increase in deferred income taxes 17,123
 862
 2,359
 —
 —
 20,344
 34,976
 4,478
 5,932
 —
 —
 45,386
Change in tax credits, net 1,741
 217
 74
 —
 —
 2,032
 3,482
 434
 311
 —
 —
 4,227
Allowance for equity funds used during construction (1,472) (65) (72) —
 —
 (1,609) (2,889) (186) 79
 —
 —
 (2,996)
Change in cash overdraft —
 —
 (1,038) —
 —
 (1,038) —
 —
 (1,038) —
 —
 (1,038)
Changes in assets and liabilities:  
  
  
  
  
  
  
  
  
  
  
  
Decrease in accounts receivable 4,131
 2,029
 2,194
 —
 450
 8,804
Decrease (increase) in accounts receivable (4,840) (1,527) 708
 —
 620
 (5,039)
Decrease (increase) in accrued unbilled revenues 11,031
 (230) 1,459
 —
 —
 12,260
 1,058
 (352) 1,549
 —
 —
 2,255
Decrease (increase) in fuel oil stock (35,060) 1,166
 (366) —
 —
 (34,260) (23,457) 1,661
 (5,410) —
 —
 (27,206)
Increase in materials and supplies (330) (387) (328) —
 —
 (1,045) (229) (246) (1,360) —
 —
 (1,835)
Increase in regulatory assets (8,188) (881) (189) —
 —
 (9,258) (15,893) (1,640) (198) —
 —
 (17,731)
Decrease in accounts payable (837) (6,032) (9,155) —
 —
 (16,024) (54,777) (5,621) (2,908) —
 —
 (63,306)
Decrease in prepaid and accrued income and utility revenue taxes (39,581) (2,791) (5,154) —
 —
 (47,526)
Change in prepaid and accrued income and utility revenue taxes (33,867) (3,709) (694) —
 —
 (38,270)
Decrease in defined benefit pension and other postretirement benefit plans liability (103) —
 (102) —
 —
 (205) (281) —
 (217) —
 —
 (498)
Change in other assets and liabilities (10,874) 1,041
 (698) —
 (450) (10,981) (19,897) (2,586) (3,155) —
 (620) (26,258)
Net cash provided by (used in) operating activities (1,540) 9,700
 (953) —
 (6,570) 637
Net cash provided by operating activities 2,943
 20,230
 14,947
 —
 (12,988) 25,132
Cash flows from investing activities  
  
  
  
  
  
  
  
  
  
  
  
Capital expenditures (49,432) (7,530) (7,500) —
 —
 (64,462) (104,710) (20,567) (20,457) —
 —
 (145,734)
Contributions in aid of construction 4,541
 1,121
 1,296
 —
 —
 6,958
 8,520
 2,493
 2,196
 —
 —
 13,209
Advances from (to) affiliates (12,661) 900
 —
 —
 11,761
 —
 (16,761) 1,000
 —
 —
 15,761
 —
Net cash used in investing activities (57,552) (5,509) (6,204) —
 11,761
 (57,504) (112,951) (17,074) (18,261) —
 15,761
 (132,525)
Cash flows from financing activities  
  
  
  
  
  
  
  
  
  
  
  
Common stock dividends (22,707) (2,941) (3,629) —
 6,570
 (22,707) (44,246) (5,813) (7,175) —
 12,988
 (44,246)
Preferred stock dividends of Hawaiian Electric and subsidiaries (270) (134) (95) —
 —
 (499) (540) (267) (191) —
 —
 (998)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less 34,096
 —
 12,661
 —
 (11,761) 34,996
 101,989
 3,400
 13,361
 —
 (15,761) 102,989
Other (320) —
 (69) —
 —
 (389) (334) (48) (75) —
 —
 (457)
Net cash provided by (used in) financing activities 10,799
 (3,075) 8,868
 —
 (5,191) 11,401
 56,869
 (2,728) 5,920
 —
 (2,773) 57,288
Net increase (decrease) in cash and cash equivalents (48,293) 1,116
 1,711
 —
 —
 (45,466) (53,139) 428
 2,606
 —
 —
 (50,105)
Cash and cash equivalents, beginning of period 61,245
 1,326
 153
 101
 —
 62,825
 61,245
 1,326
 153
 101
 —
 62,825
Cash and cash equivalents, end of period $12,952
 2,442
 1,864
 101
 —
 $17,359
 $8,106
 1,754
 2,759
 101
 —
 $12,720

2428


Hawaiian Electric Company, Inc. and Subsidiaries
Consolidating Statement of Cash Flows (unaudited)
ThreeSix months ended March 31,June 30, 2013
(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 $24,699
 4,554
 6,660
 —
 (10,985) $24,928
Adjustments to reconcile net income to net cash provided by operating activities:  
  
  
  
  
  
Net income (loss) $53,662
 9,567
 10,544
 (1) (19,652) $54,120
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:  
  
  
  
  
  
Equity in earnings of subsidiaries (11,010) —
 —
 —
 10,985
 (25) (19,702) —
 —
 —
 19,652
 (50)
Common stock dividends received from subsidiaries 7,052
 —
 —
 —
 (7,052) —
 14,227
 —
 —
 —
 (14,202) 25
Depreciation of property, plant and equipment 24,707
 8,547
 5,026
 —
 —
 38,280
 49,708
 17,094
 10,068
 —
 —
 76,870
Other amortization (8) 358
 607
 —
 —
 957
 (160) 716
 2,328
 —
 —
 2,884
Increase in deferred income taxes 13,572
 2,755
 1,648
 —
 —
 17,975
 27,560
 5,584
 5,636
 —
 —
 38,780
Change in tax credits, net 1,299
 (17) 100
 —
 —
 1,382
 2,598
 70
 329
 —
 —
 2,997
Allowance for equity funds used during construction (983) (138) (94) —
 —
 (1,215) (2,230) (330) (215) —
 —
 (2,775)
Changes in assets and liabilities:  
  
  
  
  
  
  
  
  
  
  
  
Decrease (increase) in accounts receivable 34,652
 (13) 3,495
 —
 569
 38,703
 35,431
 (2,281) (318) —
 (579) 32,253
Decrease (increase) in accrued unbilled revenues (1,707) (2,091) 2,481
 —
 —
 (1,317) (2,095) (2,848) 54
 —
 —
 (4,889)
Decrease (increase) in fuel oil stock (30,155) 2,056
 (1,173) —
 —
 (29,272) 38,428
 5,812
 (266) —
 —
 43,974
Increase in materials and supplies (1,853) (614) (878) —
 —
 (3,345) (4,069) (1,480) (1,590) —
 —
 (7,139)
Increase in regulatory assets (13,071) (2,464) (2,211) —
 —
 (17,746) (25,647) (4,852) (7,087) —
 —
 (37,586)
Increase (decrease) in accounts payable 44,887
 (903) (5,050) —
 —
 38,934
Decrease in accounts payable (36,971) (2,513) (1,750) —
 —
 (41,234)
Change in prepaid and accrued income and utility revenue taxes (41,093) (8,078) (4,495) —
 —
 (53,666) (25,831) (6,171) (6,121) —
 —
 (38,123)
Increase (decrease) in defined benefit pension and other postretirement benefit plans liability —
 (57) 10
 —
 —
 (47) 1,163
 (128) (46) —
 —
 989
Change in other assets and liabilities (4,413) 2,464
 1,493
 —
 (569) (1,025) (12,731) (3,171) 5,929
 —
 579
 (9,394)
Net cash provided by operating activities 46,575
 6,359
 7,619
 —
 (7,052) 53,501
Net cash provided by (used in) operating activities 93,341
 15,069
 17,495
 (1) (14,202) 111,702
Cash flows from investing activities  
  
  
  
  
  
  
  
  
  
  
  
Capital expenditures (47,709) (10,118) (10,088) —
 —
 (67,915) (104,846) (22,367) (23,038) —
 —
 (150,251)
Contributions in aid of construction 7,816
 3,432
 462
 —
 —
 11,710
 11,924
 4,270
 994
 —
 —
 17,188
Other 623
 —
 —
 —
   623
Advances from (to) affiliates (3,600) 1,400
 —
 —
 2,200
 —
 (8,600) 8,450
 —
 —
 150
 —
Net cash used in investing activities (43,493) (5,286) (9,626) —
 2,200
 (56,205) (100,899) (9,647) (22,044) —
 150
 (132,440)
Cash flows from financing activities  
  
  
  
  
    
  
  
  
  
  
Common stock dividends (20,070) (3,610) (3,442) —
 7,052
 (20,070) (40,789) (7,194) (7,008) —
 14,202
 (40,789)
Preferred stock dividends of Hawaiian Electric and subsidiaries (270) (134) (95) —
 —
 (499) (540) (267) (191) —
 —
 (998)
Net increase in short-term borrowings from non-affiliates and affiliate with original maturities of three months or less 41,652
 —
 3,600
 —
 (2,200) 43,052
 45,542
 —
 8,600
 —
 (150) 53,992
Other 2
 —
 —
 —
 —
 2
 (6) (1) (2) —
 —
 (9)
Net cash provided by (used in) financing activities 21,314
 (3,744) 63
 —
 4,852
 22,485
 4,207
 (7,462) 1,399
 —
 14,052
 12,196
Net increase (decrease) in cash and cash equivalents 24,396
 (2,671) (1,944) —
 —
 19,781
Net decrease in cash and cash equivalents (3,351) (2,040) (3,150) (1) —
 (8,542)
Cash and cash equivalents, beginning of period 8,265
 5,441
 3,349
 104
 —
 17,159
 8,265
 5,441
 3,349
 104
 —
 17,159
Cash and cash equivalents, end of period $32,661
 2,770
 1,405
 104
 —
 $36,940
 $4,914
 3,401
 199
 103
 —
 $8,617



2529


4 · Bank segment
Selected financial information
American Savings Bank, F.S.B.
Statements of Income Data
 Three months ended 
 March 31		 Three months  
 ended June 30		 Six months  
 ended June 30
(in thousands) 2014 2013 2014 2013 2014 2013
Interest and dividend income  
  
  
  
  
  
Interest and fees on loans $43,682
 $42,603
 $43,851
 $43,624
 $87,533
 $86,227
Interest and dividends on investment and mortgage-related securities 3,035
 3,464
 2,950
 3,234
 5,985
 6,698
Total interest and dividend income 46,717
 46,067
 46,801
 46,858
 93,518
 92,925
Interest expense  
  
  
  
  
  
Interest on deposit liabilities 1,225
 1,312
 1,237
 1,296
 2,462
 2,608
Interest on other borrowings 1,405
 1,164
 1,420
 1,178
 2,825
 2,342
Total interest expense 2,630
 2,476
 2,657
 2,474
 5,287
 4,950
Net interest income 44,087
 43,591
 44,144
 44,384
 88,231
 87,975
Provision for loan losses 995
 1,858
Net interest income after provision for loan losses 43,092
 41,733
Provision (credit) for loan losses 1,021
 (959) 2,016
 899
Net interest income after provision (credit) for loan losses 43,123
 45,343
 86,215
 87,076
Noninterest income  
  
  
  
  
  
Fees from other financial services 5,128
 7,643
 5,217
 7,996
 10,345
 15,639
Fee income on deposit liabilities 4,421
 4,314
 4,645
 4,433
 9,066
 8,747
Fee income on other financial products 2,290
 1,794
 2,064
 1,780
 4,354
 3,574
Mortgage banking income 628
 3,346
 246
 2,003
 874
 5,349
Gain on sale of securities 2,847
 —
 —
 1,226
 2,847
 1,226
Other income, net 1,588
 1,592
 1,643
 1,731
 3,231
 3,323
Total noninterest income 16,902
 18,689
 13,815
 19,169
 30,717
 37,858
Noninterest expense  
  
  
  
  
  
Compensation and employee benefits 20,286
 20,088
 19,872
 20,063
 40,158
 40,151
Occupancy 3,953
 4,123
 4,489
 4,219
 8,442
 8,342
Data processing 3,060
 2,987
 2,971
 2,827
 6,031
 5,814
Services 2,273
 2,103
 2,855
 2,328
 5,128
 4,431
Equipment 1,645
 1,774
 1,609
 1,870
 3,254
 3,644
Other expense 7,153
 7,595
 8,094
 8,500
 15,247
 16,095
Total noninterest expense 38,370
 38,670
 39,890
 39,807
 78,260
 78,477
Income before income taxes 21,624
 21,752
 17,048
 24,705
 38,672
 46,457
Income taxes 7,085
 7,597
 5,372
 8,786
 12,457
 16,383
Net income $14,539
 $14,155
 $11,676
 $15,919
 $26,215
 $30,074
American Savings Bank, F.S.B.
Statements of Comprehensive Income Data
 Three months  
 ended March 31		 Three months  
 ended June 30		 Six months  
 ended June 30
(in thousands) 2014 2013 2014 2013 2014 2013
Net income $14,539
 $14,155
 $11,676
 $15,919
 $26,215
 $30,074
Other comprehensive income (loss), net of taxes:  
  
  
  
  
  
Net unrealized gains (losses) on securities:  
  
  
  
  
  
Net unrealized gains (losses) on securities arising during the period, net of (taxes) benefits, of ($1,664) and $547 for the respective periods 2,520
 (828)
Less: reclassification adjustment for net realized gains included in net income, net of taxes, of $1,132 and nil for the respective periods (1,715) —
Net unrealized gains (losses) on securities arising during the period, net of (taxes) benefits of ($1,679), $5,485, ($3,343) and $6,032 for the respective periods 2,543
 (8,307) 5,063
 (9,135)
Less: reclassification adjustment for net realized gains included in net income, net of taxes of nil, $488, $1,132 and $488 for the respective periods —
 (738) (1,715) (738)
Retirement benefit plans:  
  
  
  
  
  
Less: amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits of $144 and $1,424 for the respective periods 219
 2,157
Other comprehensive income, net of taxes 1,024
 1,329
Less: amortization of prior service credit and net losses recognized during the period in net periodic benefit cost, net of tax benefits of $142, $308, $286 and $1,732 for the respective periods 215
 466
 434
 2,623
Other comprehensive income (loss), net of taxes 2,758
 (8,579) 3,782
 (7,250)
Comprehensive income $15,563
 $15,484
 $14,434
 $7,340
 $29,997
 $22,824

2630



American Savings Bank, F.S.B.
Balance Sheets Data
 
(in thousands) March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
Assets  
  
  
  
  
  
  
  
Cash and cash equivalents (including $40 million of securities purchased under resale agreements at March 31, 2014)  
 $251,083
  
 $156,603
Cash and cash equivalents  
 $174,950
  
 $156,603
Available-for-sale investment and mortgage-related securities  
 517,534
  
 529,007
  
 549,321
  
 529,007
Investment in stock of Federal Home Loan Bank of Seattle  
 86,697
  
 92,546
  
 80,863
  
 92,546
Loans receivable held for investment  
 4,188,460
  
 4,150,229
  
 4,287,612
  
 4,150,229
Allowance for loan losses  
 (40,923)  
 (40,116)  
 (42,372)  
 (40,116)
Loans receivable held for investment, net  
 4,147,537
  
 4,110,113
  
 4,245,240
  
 4,110,113
Loans held for sale, at lower of cost or fair value  
 4,363
  
 5,302
  
 956
  
 5,302
Other  
 282,079
  
 268,063
  
 284,607
  
 268,063
Goodwill  
 82,190
  
 82,190
  
 82,190
  
 82,190
Total assets  
 $5,371,483
  
 $5,243,824
  
 $5,418,127
  
 $5,243,824
                
Liabilities and shareholder’s equity  
  
  
  
  
  
  
  
Deposit liabilities—noninterest-bearing  
 $1,284,957
  
 $1,214,418
  
 $1,301,758
  
 $1,214,418
Deposit liabilities—interest-bearing  
 3,193,030
  
 3,158,059
  
 3,223,102
  
 3,158,059
Other borrowings  
 244,642
  
 244,514
  
 242,455
  
 244,514
Other  
 120,324
  
 105,679
  
 116,953
  
 105,679
Total liabilities  
 4,842,953
  
 4,722,670
  
 4,884,268
  
 4,722,670
Commitments and contingencies (see “Litigation” below)  
  
  
  
  
  
  
  
Common stock  
 336,617
  
 336,054
  
 337,262
  
 336,054
Retained earnings  
 203,086
  
 197,297
  
 205,012
  
 197,297
Accumulated other comprehensive loss, net of tax benefits  
  
  
  
  
  
  
  
Net unrealized losses on securities $(2,858)  
 $(3,663)  
 $(315)  
 $(3,663)  
Retirement benefit plans (8,315) (11,173) (8,534) (12,197) (8,100) (8,415) (8,534) (12,197)
Total shareholder’s equity  
 528,530
  
 521,154
  
 533,859
  
 521,154
Total liabilities and shareholder’s equity  
 $5,371,483
  
 $5,243,824
  
 $5,418,127
  
 $5,243,824
                
Other assets  
  
  
  
  
  
  
  
Bank-owned life insurance  
 $130,977
  
 $129,963
  
 $131,959
  
 $129,963
Premises and equipment, net  
 67,628
  
 67,766
  
 68,254
  
 67,766
Prepaid expenses  
 4,617
  
 3,616
  
 3,878
  
 3,616
Accrued interest receivable  
 13,119
  
 13,133
  
 13,354
  
 13,133
Mortgage-servicing rights  
 11,757
  
 11,687
  
 11,605
  
 11,687
Low-income housing equity investments   24,730
   14,543
   23,820
   14,543
Real estate acquired in settlement of loans, net  
 542
  
 1,205
  
 1,045
  
 1,205
Other  
 28,709
  
 26,150
  
 30,692
  
 26,150
  
 $282,079
  
 $268,063
  
 $284,607
  
 $268,063
Other liabilities  
  
  
  
  
  
  
  
Accrued expenses  
 $26,003
  
 $19,989
  
 $24,440
  
 $19,989
Federal and state income taxes payable  
 43,110
  
 37,807
  
 38,940
  
 37,807
Cashier’s checks  
 25,363
  
 21,110
  
 21,286
  
 21,110
Advance payments by borrowers  
 6,084
  
 9,647
  
 9,852
  
 9,647
Other  
 19,764
  
 17,126
  
 22,435
  
 17,126
  
 $120,324
  
 $105,679
  
 $116,953
  
 $105,679
 

27


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.

31


ASB invests, as a limited partner, in Low-Income Housing Tax Credit (LIHTC) investment partnerships formed for the purpose of providing funding for affordable multifamily rental properties. These properties are rented to qualified low-income tenants, pursuant to Section 42 of the Internal Revenue Code, allowing the properties to be eligible for federal and, for some properties, state tax credits. ASB realizes a return on its investment through reductions in income tax expense that result from tax credits and the deductibility of the operating losses of these partnerships. The partnership agreements are typically structured to meet a required 15-year period of occupancy by qualified low-income tenants. ASB’s maximum exposure to loss is limitedequal to the amount of its investment.

legally binding equity commitments adjusted for recorded impairment, partnership results, and/or proportional amortization for qualifying low income housing tax credit investments, where applicable.
Other borrowings consisted of securities sold under agreements to repurchase and advances from the Federal Home Loan Bank (FHLB) of Seattle of $145142 million and $100 million, respectively, as of March 31,June 30, 2014 and $145 million and $100 million, respectively, as of December 31, 2013.
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 balance sheet. All such agreements are subject to master netting arrangements, which provide for 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
Repurchase agreements  
  
  
March 31, 2014 $145
 $—
 $145
December 31, 2013 145
 —
 145
  Gross amount not offset in the Balance Sheet
(in millions) 
Net amount of 
liabilities presented
in the Balance Sheet
 
Financial
instruments
 
Cash
collateral
pledged
 Net amount
March 31, 2014  
  
  
  
Financial institution $50
 $50
 $—
 $—
Commercial account holders 95
 95
 —
 —
Total $145
 $145
 $—
 $—
         
December 31, 2013  
  
  
  
Financial institution $51
 $51
 $—
 $—
Commercial account holders 94
 94
 —
 —
Total $145
 $145
 $—
 $—
Investment and mortgage-related securities portfolio.
Available-for-sale securities.  The book value (amortized cost), gross unrealized gains and losses, estimated fair value and gross unrealized losses (fair value and amount by duration of time in which positions have been held in a continuous loss position) for securities held in ASB’s “available-for-sale” portfolio by major security type were as follows:

28


 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
(in thousands) Fair value Amount Fair value Amount Fair value Amount Fair value Amount
March 31, 2014  
  
  
  
  
  
  
  
June 30, 2014  
  
  
  
  
  
  
  
U.S. Treasury and federal agency obligations $87,916
 $489
 $(1,885) $86,520
 $44,700
 $(1,508) $4,402
 $(377) $102,472
 $889
 $(1,332) $102,029
 $14,950
 $(79) $29,443
 $(1,253)
Mortgage-related securities- FNMA, FHLMC and GNMA 434,364
 4,769
 (8,119) 431,014
 229,667
 (5,807) 49,547
 (2,312) 447,373
 6,529
 (6,610) 447,292
 72,721
 (443) 154,149
 (6,167)
Municipal bonds —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 $522,280
 $5,258
 $(10,004) $517,534
 $274,367
 $(7,315) $53,949
 $(2,689)
                 $549,845
 $7,418
 $(7,942) $549,321
 $87,671
 $(522) $183,592
 $(7,420)
December 31, 2013                                
Federal agency obligations $83,193
 $174
 $(2,394) $80,973
 $70,779
 $(2,394) $—
 $—
 $83,193
 $174
 $(2,394) $80,973
 $70,779
 $(2,394) $—
 $—
Mortgage-related securities- FNMA, FHLMC and GNMA 374,993
 4,911
 (10,460) 369,444
 228,543
 (8,819) 19,655
 (1,641) 374,993
 4,911
 (10,460) 369,444
 228,543
 (8,819) 19,655
 (1,641)
Municipal bonds 76,904
 1,826
 (140) 78,590
 14,478
 (140) —
 —
 76,904
 1,826
 (140) 78,590
 14,478
 (140) —
 —
 $535,090
 $6,911
 $(12,994) $529,007
 $313,800
 $(11,353) $19,655
 $(1,641) $535,090
 $6,911
 $(12,994) $529,007
 $313,800
 $(11,353) $19,655
 $(1,641)
The unrealized losses on ASB’s investments in mortgage-related securities and obligations issued by federal agencies were caused by interest rate movements. The contractual terms of these investments do not permit the issuer to settle the securities at a price less than the amortized cost basis of the investments. Because ASB does not intend to sell the securities and has determined it is more likely than not that it will not be required to sell the investments before recovery of their amortized costscost basis, which may be at maturity, ASB did not consider these investments to be other-than-temporarily impaired at March 31,June 30, 2014.
The fair values of ASB’s investment securities could decline if interest rates rise or spreads widen.
The following table details the contractual maturities of available-for-sale securities. All positions with variable maturities (e.g. callable debentures and mortgage-related securities) are disclosed based upon the bond’s contractual maturity. Actual maturities will likely differ from these contractual maturities because borrowers have the right to prepay obligations with or without prepayment penalties.
March 31, 2014 Amortized cost Fair value
June 30, 2014 Amortized cost Fair value
(in thousands)        
Due in one year or less $—
 $—
 $—
 $—
Due after one year through five years 34,456
 34,446
 44,492
 44,538
Due after five years through ten years 32,321
 32,370
 32,303
 32,839
Due after ten years 21,139
 19,704
 25,677
 24,652
 87,916
 86,520
 102,472
 102,029
Mortgage-related securities-FNMA,FHLMC and GNMA 434,364
 431,014
 447,373
 447,292
Total available-for-sale securities $522,280
 $517,534
 $549,845
 $549,321

32


Allowance for loan losses.ASB must maintainmaintains an allowance for loan losses that it believes is adequate to absorb estimated probable credit losses associated withinherent in its loan portfolio. The level of allowance for loan losses is based on a continuing assessment of existing risks in the loan portfolio, historical loss experience, changes in collateral values and current conditions (e.g., economic conditions, real estate market conditions and interest rate environment). The allowance for loan losses consists of anis allocated portion, which estimates credit losses for specifically identified loans and poolsto loan types using both a formula-based approach applied to groups of loans and an unallocated portion.analysis of certain individual loans for impairment. The formula-based approach emphasizes loss factors primarily derived from actual historical default and loss rates, which are combined with an assessment of certain qualitative factors to determine the allowance amounts allocated to the various loan categories. Adverse changes in any of these factors could result in higher charge-offs and provision for loan losses.
ASB disaggregates its portfolio loans into portfolio segments for purposes of determining the allowance for loan losses. Commercial and commercial real estate loans are defined as non-homogeneous loans and ASB utilizes a risk rating system for evaluating the credit quality of the loans. Loans are rated based on the degree of risk at origination and periodically thereafter, as appropriate. Values are applied separately to the probability of default (borrower risk) and loss given default (transaction risk). ASB’s credit review department performs an evaluation of these loan portfolios to ensure compliance with the internal risk rating system and timeliness of rating changes. Non-homogeneous loans are categorized into the regulatory asset quality classifications—Pass, Special Mention, Substandard, Doubtful, and Loss based on credit quality. For loans classified as substandard, an analysis is done to determine if the loan is impaired. A loan is deemed impaired when it is probable that ASB will be unable to collect all amounts due according to the contractual terms of the loan agreement. Once a loan is deemed impaired, ASB applies a valuation methodology to determine whether there is an impairment shortfall. The measurement of impairment may be based on (i) the present value of the expected future cash flows of the impaired loan discounted at the loan’s original effective interest rate, (ii) the observable market price of the impaired loan, or (iii) the fair value of the collateral, net of costs to sell. For all loans collateralized by real estate whose repayment is dependent on the sale of the underlying collateral property, ASB measures impairment by utilizing the fair value of the collateral, net of costs to sell; for other loans that are not considered collateral dependent, generally the discounted cash flow method is used to measure impairment. For loans collateralized by real estate that are classified as troubled debt restructured loans, the present value of the expected future cash flows of the loans may also be used to measure impairment as these loans are expected to perform according to their restructured terms. Impairment shortfalls are charged to the provision for loan losses and included in the allowance for loan losses. However, impairment shortfalls that are deemed to be confirmed losses (uncollectible) are charged off, with the loan written down by the amount of the confirmed loss.
Residential, consumer and credit scored business loans are considered homogeneous loans, which are typically underwritten based on common, uniform standards, and are generally classified as to the level of loss exposure based on delinquency status. The homogeneous loan portfolios are stratified into individual products with common risk characteristics and segmented into various secured and unsecured loan product types. For the homogeneous portfolio, the quality of the loan is best indicated by the repayment performance of an individual borrower. ASB does supplement performance data with an 11-risk rating retail credit model that assigns a probability of default to each borrower based primarily on the borrower's current Fair Isaac Corporation (FICO) score and for the home equity line of credit (HELOC) and unsecured consumer products, the bankruptcy score (BK).  Current FICO and BK data is purchased and appended to all homogeneous loans on a quarterly basis and used to estimate the borrower’s probability of default and the loss given default.
ASB also considers the following qualitative factors for all loans in estimating the allowance for loan losses:
changes in lending policies and procedures;
changes in economic and business conditions and developments that affect the collectability of the portfolio;
changes in the nature, volume and terms of the loan portfolio;
changes in lending management and other relevant staff;
changes in loan quality (past due, non-accrual, classified loans);
changes in the quality of the loan review system;
changes in the value of underlying collateral;
effect of, and changes in the level of, any concentrations of credit; and
effect of other external and internal factors.
ASB’s methodology for determining the allowance for loan losses was generally based on historic loss rates using various look-back periods. During the second quarter 2014, ASB implemented enhancements to the loss rate calculation for estimating the allowance for loan losses that included several refinements to determining the probability of default and the loss given default for the various segments of the loan portfolio that are more statistically sound than those previously employed. The result is an estimated loss rate established for each borrower. ASB also updated its measurement of the loss emergence period in the calculation of the allowance for loan losses. The loss emergence period is broadly defined as the period that it takes, on average, for the lender to identify the specific borrower and amount of loss incurred by the bank for a loan that has suffered from a loss-causing event. In most cases, the loss emergence period was within a twelve month period; however, as credit

2933


quality and conditions improve, management has observed that the loss emergence period has extended and has incorporated this observed change in the estimate of the allowance for loan losses. Management believes these enhancements will improve the precision in estimating the allowance for loan losses. The enhancement did not have a material effect on the total allowance for loan losses or the provision for loan losses for the second quarter 2014. The enhancement did result in the full allocation of the previously unallocated portion of the allowance for loan losses.
In conjunction with the above enhancement, management also adopted an enhanced risk rating system for monitoring and managing credit risk in the non-homogenous loan portfolios, that measures general creditworthiness at the borrower level. The numerical-based, risk rating “PD Model” takes into consideration fiscal year-end financial information of the borrower and identified financial attributes including retained earnings, operating cash flows, interest coverage, liquidity and leverage that demonstrate a strong correlation with default to assign default probabilities at the borrower level. In addition, a loss given default (LGD) value is assigned to each loan to measure loss in the event of default based on loan specific features such as collateral that mitigates the amount of loss in the event of default. Together the PD Model and LGD construct provide a more quantitative, data driven and consistent framework for measuring risk within the portfolio, on a loan by loan basis and for the ultimate collectability of each loan. Management believes its allowance for loan losses adequately estimates actual loan losses that will ultimately be incurred. However, such estimates are based on currently available information and historical experience, and future adjustments may be required from time to time to the allowance for loan losses based on new information and changes that occur (e.g., due to changes in economic conditions, particularly in Hawaii). Actual losses could differ from management’s estimates, and these differences and subsequent adjustments could be material.

34


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 Unallocated Total 
Residential
1-4 family
 
Commercial real
estate
 Home
equity line of credit		 Residential land Commercial construction Residential construction Commercial loans Consumer loans Unallocated Total
Three months ended March 31, 2014  
  
  
  
�� 
  
  
  
  
  
Three months ended
June 30, 2014		  
  
  
  
  
  
  
  
  
  
Allowance for loan losses:  
  
  
  
  
  
  
  
  
  
Beginning balance $5,475
 $5,715
 $5,969
 $1,575
 $3,063
 $24
 $15,592
 $2,316
 $1,194
 $40,923
Charge-offs (94) —
 (136) (47) —
 —
 (246) (461) —
 (984)
Recoveries 555
 —
 314
 77
 —
 —
 225
 241
 —
 1,412
Provision (269) 1,515
 934
 232
 327
 2
 (427) (99) (1,194) 1,021
Ending balance $5,667
 $7,230
 $7,081
 $1,837
 $3,390
 $26
 $15,144
 $1,997
 $—
 $42,372
Three months ended
June 30, 2013		  
  
  
  
  
  
  
  
  
  
Allowance for loan losses:  
  
  
  
  
  
  
  
  
  
Beginning balance $6,011
 $6,656
 $4,557
 $2,743
 $1,872
 $12
 $14,963
 $3,655
 $2,261
 $42,730
Charge-offs (846) —
 (68) (8) —
 —
 (924) (759) —
 (2,605)
Recoveries 1,033
 —
 62
 363
 —
 —
 220
 160
 —
 1,838
Provision 159
 (2,539) 458
 (911) 433
 2
 2,048
 (657) 48
 (959)
Ending balance $6,357
 $4,117
 $5,009
 $2,187
 $2,305
 $14
 $16,307
 $2,399
 $2,309
 $41,004
Six months ended
June 30, 2014		  
  
  
  
  
  
  
  
  
  
Allowance for loan losses:  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
Beginning balance $5,534
 $5,059
 $5,229
 $1,817
 $2,397
 $19
 $15,803
 $2,367
 $1,891
 $40,116
 $5,534
 $5,059
 $5,229
 $1,817
 $2,397
 $19
 $15,803
 $2,367
 $1,891
 $40,116
Charge-offs (266) —
 —
 (6) —
 —
 (124) (561) —
 (957) (360) —
 (136) (53) —
 —
 (370) (1,022) —
 (1,941)
Recoveries 341
 —
 11
 86
 —
 —
 100
 231
 —
 769
 896
 —
 325
 163
 —
 —
 325
 472
 —
 2,181
Provision (134) 656
 729
 (322) 666
 5
 (187) 279
 (697) 995
 (403) 2,171
 1,663
 (90) 993
 7
 (614) 180
 (1,891) 2,016
Ending balance $5,475
 $5,715
 $5,969
 $1,575
 $3,063
 $24
 $15,592
 $2,316
 $1,194
 $40,923
 $5,667
 $7,230
 $7,081
 $1,837
 $3,390
 $26
 $15,144
 $1,997
 $—
 $42,372
Ending balance: individually evaluated for impairment $906
 $1,544
 $—
 $1,102
 $—
 $—
 $2,133
 $—
 $—
 $5,685
 $969
 $941
 $14
 $1,202
 $—
 $—
 $1,239
 $5
 $—
 $4,370
Ending balance: collectively evaluated for impairment $4,569
 $4,171
 $5,969
 $473
 $3,063
 $24
 $13,459
 $2,316
 $1,194
 $35,238
 $4,698
 $6,289
 $7,067
 $635
 $3,390
 $26
 $13,905
 $1,992
 $—
 $38,002
Financing Receivables:  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
Ending balance $1,985,812
 $452,303
 $764,483
 $15,906
 $66,578
 $16,474
 $786,611
 $108,202
 $—
 $4,196,369
 $2,019,092
 $476,116
 $790,837
 $17,189
 $80,312
 $17,441
 $782,804
 $111,254
 $—
 $4,295,045
Ending balance: individually evaluated for impairment $20,141
 $4,558
 $1,164
 $10,351
 $—
 $—
 $19,399
 $18
 $—
 $55,631
 $17,978
 $4,512
 $612
 $9,320
 $—
 $—
 $18,042
 $17
 $—
 $50,481
Ending balance: collectively evaluated for impairment $1,965,671
 $447,745
 $763,319
 $5,555
 $66,578
 $16,474
 $767,212
 $108,184
 $—
 $4,140,738
 $2,001,114
 $471,604
 $790,225
 $7,869
 $80,312
 $17,441
 $764,762
 $111,237
 $—
 $4,244,564
Three months ended March 31, 2013  
  
  
  
  
  
  
  
  
  
Six months ended
June 30, 2013		  
  
  
  
  
  
  
  
  
  
Allowance for loan losses:  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
  
Beginning balance $6,068
 $2,965
 $4,493
 $4,275
 $2,023
 $9
 $15,931
 $4,019
 $2,202
 $41,985
 $6,068
 $2,965
 $4,493
 $4,275
 $2,023
 $9
 $15,931
 $4,019
 $2,202
 $41,985
Charge-offs (210) —
 (670) (227) —
 —
 (426) (645) —
 (2,178) (1,056) —
 (738) (235) —
 —
 (1,350) (1,404) —
 (4,783)
Recoveries 192
 —
 194
 137
 —
 —
 392
 150
 —
 1,065
 1,225
 —
 256
 500
 —
 —
 612
 310
 —
 2,903
Provision (39) 3,691
 540
 (1,442) (151) 3
 (934) 131
 59
 1,858
 120
 1,152
 998
 (2,353) 282
 5
 1,114
 (526) 107
 899
Ending balance $6,011
 $6,656
 $4,557
 $2,743
 $1,872
 $12
 $14,963
 $3,655
 $2,261
 $42,730
 $6,357
 $4,117
 $5,009
 $2,187
 $2,305
 $14
 $16,307
 $2,399
 $2,309
 $41,004
Ending balance: individually evaluated for impairment $454
 $3,169
 $—
 $1,943
 $—
 $—
 $2,285
 $—
 $—
 $7,851
 $944
 $820
 $—
 $1,641
 $—
 $—
 $3,367
 $—
 $—
 $6,772
Ending balance: collectively evaluated for impairment $5,557
 $3,487
 $4,557
 $800
 $1,872
 $12
 $12,678
 $3,655
 $2,261
 $34,879
 $5,413
 $3,297
 $5,009
 $546
 $2,305
 $14
 $12,940
 $2,399
 $2,309
 $34,232
Financing Receivables:  
  
  
  
  
  
  
  
  
 0
  
  
  
  
  
  
  
  
  
 0
Ending balance $1,915,207
 $391,679
 $648,904
 $23,894
 $40,698
 $8,275
 $699,918
 $127,260
 $—
 $3,855,835
 $2,001,035
 $382,735
 $673,727
 $21,836
 $50,114
 $9,664
 $719,519
 $104,759
 $—
 $3,963,389
Ending balance: individually evaluated for impairment $25,320
 $10,662
 $1,259
 $17,618
 $—
 $—
 $19,302
 $21
 $—
 $74,182
 $21,417
 $3,811
 $837
 $16,041
 $—
 $—
 $21,431
 $20
 $—
 $63,557
Ending balance: collectively evaluated for impairment $1,889,887
 $381,017
 $647,645
 $6,276
 $40,698
 $8,275
 $680,616
 $127,239
 $—
 $3,781,653
 $1,979,618
 $378,924
 $672,890
 $5,795
 $50,114
 $9,664
 $698,088
 $104,739
 $—
 $3,899,832

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 and industrial, commercial real estate and commercial construction loans.

A dual ten-point risk rating system
35


Each loan is usedassigned an Asset Quality Rating (AQR) reflecting the likelihood of repayment or orderly liquidation of that loan transaction pursuant to reflect the probability of default (borrower risk rating)regulatory credit classifications:  Pass, Special Mention, Substandard, Doubtful, and loss given default (transaction risk rating).Loss. The borrower risk rating addresses risk presented by the individual borrower and is based on the overall assessment of the borrower’s financial and operating strength including earnings, operating cash flow, debt service capacity, asset and liability structure, competitive issues, experience and quality of management, financial reporting quality and industry/economic factors. Separately, the transaction risk rating addresses risk in the transaction andAQR is a function of specific loan attributesthe PD Model rating, the LGD, and possible non-model factors which impact the ultimate collectability of the loan such as collateral, loan structure, guarantees, and other structural support or enhancements to the loan.
The numerical representationcharacter of the risk categories are:
1- Substantially risk free6- Acceptable risk
2- Minimal risk7- Special mention
3- Modest risk8- Substandard
4- Better than average risk9- Doubtful
5- Average risk10- Loss

30


Grades 1 through 6 are considered pass grades.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.
The credit risk profile by internally assigned grade for loans was as follows:
 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
(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 $393,888
 $66,578
 $708,268
 $375,217
 $52,112
 $703,053
 $413,902
 $63,454
 $723,201
 $375,217
 $52,112
 $703,053
Special mention 25,651
 —
 20,315
 33,436
 —
 17,634
 28,488
 16,858
 16,185
 33,436
 —
 17,634
Substandard 29,014
 —
 55,079
 28,020
 —
 59,663
 29,995
 —
 40,366
 28,020
 —
 59,663
Doubtful 3,750
 —
 2,949
 3,770
 —
 3,038
 3,731
 —
 3,052
 3,770
 —
 3,038
Loss —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Total $452,303
 $66,578
 $786,611
 $440,443
 $52,112
 $783,388
 $476,116
 $80,312
 $782,804
 $440,443
 $52,112
 $783,388

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
March 31, 2014  
  
  
  
  
  
  
June 30, 2014  
  
  
  
  
  
  
Real estate loans:  
  
  
  
  
  
  
  
  
  
  
  
  
  
Residential 1-4 family $4,209
 $1,635
 $14,321
 $20,165
 $1,965,647
 $1,985,812
 $—
 $5,161
 $2,233
 $14,739
 $22,133
 $1,996,959
 $2,019,092
 $—
Commercial real estate 71
 —
 3,750
 3,821
 448,482
 452,303
 —
 —
 —
 3,731
 3,731
 472,385
 476,116
 —
Home equity line of credit 640
 98
 928
 1,666
 762,817
 764,483
 —
 956
 545
 364
 1,865
 788,972
 790,837
 —
Residential land 96
 191
 2,223
 2,510
 13,396
 15,906
 52
 230
 —
 145
 375
 16,814
 17,189
 52
Commercial construction —
 —
 —
 —
 66,578
 66,578
 —
 —
 —
 —
 —
 80,312
 80,312
 —
Residential construction —
 —
 —
 —
 16,474
 16,474
 —
 —
 —
 —
 —
 17,441
 17,441
 —
Commercial loans 1,794
 5,050
 2,406
 9,250
 777,361
 786,611
 —
 266
 52
 2,717
 3,035
 779,769
 782,804
 —
Consumer loans 431
 187
 163
 781
 107,421
 108,202
 —
 551
 301
 173
 1,025
 110,229
 111,254
 —
Total loans $7,241
 $7,161
 $23,791
 $38,193
 $4,158,176
 $4,196,369
 $52
 $7,164
 $3,131
 $21,869
 $32,164
 $4,262,881
 $4,295,045
 $52
December 31, 2013  
  
  
  
  
  
  
  
  
  
  
  
  
  
Real estate loans:  
  
  
  
  
  
  
  
  
  
  
  
  
  
Residential 1-4 family $2,728
 $622
 $15,411
 $18,761
 $1,987,246
 $2,006,007
 $—
 $2,728
 $622
 $15,411
 $18,761
 $1,987,246
 $2,006,007
 $—
Commercial real estate —
 —
 3,770
 3,770
 436,673
 440,443
 —
 —
 —
 3,770
 3,770
 436,673
 440,443
 —
Home equity line of credit 765
 312
 960
 2,037
 737,294
 739,331
 —
 765
 312
 960
 2,037
 737,294
 739,331
 —
Residential land 184
 48
 2,756
 2,988
 13,188
 16,176
 —
 184
 48
 2,756
 2,988
 13,188
 16,176
 —
Commercial construction —
 —
 —
 —
 52,112
 52,112
 —
 —
 —
 —
 —
 52,112
 52,112
 —
Residential construction —
 —
 —
 —
 12,774
 12,774
 —
 —
 —
 —
 —
 12,774
 12,774
 —
Commercial loans 1,668
 612
 3,026
 5,306
 778,082
 783,388
 —
 1,668
 612
 3,026
 5,306
 778,082
 783,388
 —
Consumer loans 436
 158
 304
 898
 107,824
 108,722
 —
 436
 158
 304
 898
 107,824
 108,722
 —
Total loans $5,781
 $1,752
 $26,227
 $33,760
 $4,125,193
 $4,158,953
 $—
 $5,781
 $1,752
 $26,227
 $33,760
 $4,125,193
 $4,158,953
 $—


36


The credit risk profile based on nonaccrual loans and accruing loans 90 days or more past due was as follows:

31


 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
(in thousands) 
Nonaccrual
loans
 
Accruing loans
90 days or
more past due
 
Nonaccrual
loans
 
Accruing loans
90 days or
more past due
 
Nonaccrual
loans
 
Accruing loans
90 days or
more past due
 
Nonaccrual
loans
 
Accruing loans
90 days or
more past due
Real estate loans:  
  
  
  
  
  
  
  
Residential 1-4 family $18,795
 $—
 $19,679
 $—
 $20,769
 $—
 $19,679
 $—
Commercial real estate 4,395
 —
 4,439
 —
 4,351
 —
 4,439
 —
Home equity line of credit 2,060
 —
 2,060
 —
 1,197
 —
 2,060
 —
Residential land 3,136
 52
 3,161
 —
 2,879
 52
 3,161
 —
Commercial construction —
 —
 —
 —
 —
 —
 —
 —
Residential construction —
 —
 —
 —
 —
 —
 —
 —
Commercial loans 17,641
 —
 18,781
 —
 14,391
 —
 18,781
 —
Consumer loans 310
 —
 401
 —
 306
 —
 401
 —
Total $46,337
 $52
 $48,521
 $—
 $43,893
 $52
 $48,521
 $—

The total carrying amount and the total unpaid principal balance of impaired loans, with and without recorded allowance for loan losses and combined, were as follows:
 March 31, 2014 Three months ended 
 March 31, 2014		 June 30, 2014 Three months ended 
 June 30, 2014		 Six months ended 
 June 30, 2014
(in thousands) 
Recorded
investment
 
Unpaid
principal
balance
 
Related
Allowance
 
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  
  
  
  
  
  
  
  
  
  
  
  
Real estate loans:  
  
  
  
  
  
  
  
  
  
  
  
Residential 1-4 family $9,573
 $11,874
 $—
 $10,480
 $88
 $5,529
 $7,267
 $—
 $8,232
 $71
 $9,356
 $159
Commercial real estate —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Home equity line of credit 641
 1,205
 —
 649
 3
 150
 331
 —
 426
 1
 537
 4
Residential land 3,080
 4,047
 —
 3,016
 56
 2,876
 3,759
 —
 2,844
 42
 2,930
 98
Commercial construction —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Residential construction —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Commercial loans 3,320
 4,613
 —
 3,381
 —
 2,278
 3,673
 —
 2,903
 16
 3,142
 16
Consumer loans 18
 18
 —
 18
 —
 —
 —
 —
 12
 —
 15
 —
 16,632
 21,757
 —
 17,544
 147
 10,833
 15,030
 —
 14,417
 130
 15,980
 277
With an allowance recorded  
  
  
  
  
  
  
  
  
  
  
  
Real estate loans:  
  
  
  
  
  
  
  
  
  
  
  
Residential 1-4 family 6,764
 6,784
 906
 5,605
 103
 10,264
 10,352
 969
 8,219
 88
 6,912
 191
Commercial real estate 4,558
 4,668
 1,543
 4,573
 2
 4,512
 4,650
 941
 4,527
 1
 4,550
 3
Home equity line of credit —
 —
 —
 —
 —
 207
 248
 14
 69
 1
 35
 1
Residential land 7,271
 7,442
 1,102
 7,168
 132
 6,445
 6,523
 1,202
 6,509
 88
 6,838
 220
Commercial construction —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Residential construction —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Commercial loans 16,079
 19,235
 2,134
 16,550
 44
 15,764
 19,116
 1,239
 15,649
 50
 16,099
 94
Consumer loans —
 —
 —
 —
 —
 17
 17
 5
 5
 —
 3
 —
 34,672
 38,129
 5,685
 33,896
 281
 37,209
 40,906
 4,370
 34,978
 228
 34,437
 509
Total  
  
  
  
  
  
  
  
  
  
  
  
Real estate loans:  
  
  
  
  
  
  
  
  
  
  
  
Residential 1-4 family 16,337
 18,658
 906
 16,085
 191
 15,793
 17,619
 969
 16,451
 159
 16,268
 350
Commercial real estate 4,558
 4,668
 1,543
 4,573
 2
 4,512
 4,650
 941
 4,527
 1
 4,550
 3
Home equity line of credit 641
 1,205
 —
 649
 3
 357
 579
 14
 495
 2
 572
 5
Residential land 10,351
 11,489
 1,102
 10,184
 188
 9,321
 10,282
 1,202
 9,353
 130
 9,768
 318
Commercial construction —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Residential construction —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
 —
Commercial loans 19,399
 23,848
 2,134
 19,931
 44
 18,042
 22,789
 1,239
 18,552
 66
 19,241
 110
Consumer loans 18
 18
 —
 18
 —
 17
 17
 5
 17
 —
 18
 —
 $51,304
 $59,886
 $5,685
 $51,440
 $428
 $48,042
 $55,936
 $4,370
 $49,395
 $358
 $50,417
 $786


3237



  December 31, 2013 Year ended December 31, 2013
(in thousands) 
Recorded
investment
 
Unpaid
principal
balance
 
Related
allowance
 
Average
recorded
investment
 
Interest
income
recognized*
With no related allowance recorded  
  
  
  
  
Real estate loans:  
  
  
  
  
Residential 1-4 family $9,708
 $12,144
 $—
 $11,674
 $386
Commercial real estate —
 —
 —
 802
 —
Home equity line of credit 672
 1,227
 —
 623
 2
Residential land 2,622
 3,612
 —
 6,675
 482
Commercial construction —
 —
 —
 —
 —
Residential construction —
 —
 —
 —
 —
Commercial loans 3,466
 4,715
 —
 4,837
 12
Consumer loans 19
 19
 —
 20
 —
  16,487
 21,717
 —
 24,631
 882
With an allowance recorded  
  
  
  
  
Real estate loans:  
  
  
  
  
Residential 1-4 family 6,216
 6,236
 642
 6,455
 372
Commercial real estate 4,604
 4,686
 1,118
 5,745
 152
Home equity line of credit —
 —
 —
 —
 —
Residential land 7,452
 7,623
 1,332
 6,844
 409
Commercial construction —
 —
 —
 —
 —
Residential construction —
 —
 —
 —
 —
Commercial loans 17,759
 20,640
 2,246
 15,635
 139
Consumer loans —
 —
 —
 —
 —
  36,031
 39,185
 5,338
 34,679
 1,072
Total  
  
  
  
  
Real estate loans:  
  
  
  
  
Residential 1-4 family 15,924
 18,380
 642
 18,129
 758
Commercial real estate 4,604
 4,686
 1,118
 6,547
 152
Home equity line of credit 672
 1,227
 —
 623
 2
Residential land 10,074
 11,235
 1,332
 13,519
 891
Commercial construction —
 —
 —
 —
 —
Residential construction —
 —
 —
 —
 —
Commercial loans 21,225
 25,355
 2,246
 20,472
 151
Consumer loans 19
 19
 —
 20
 —
  $52,518
 $60,902
 $5,338
 $59,310
 $1,954
 
*                Since loan was classified as impaired.
 
Troubled debt restructurings.  A loan modification is deemed to be a troubled debt restructuring (TDR) when ASB grants a concession it would not otherwise consider were it not for the borrower’s financial difficulty. 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 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.
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 of principal payments. ASB generally does not reduce the interest rate on commercial loan TDR modifications. Occasionally, additional collateral and/or guaranties are obtained.

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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 costcosts 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 were as follows for the indicated periods: 
 Three months ended March 31, 2014 Three months ended March 31, 2013 Three months ended June 30, 2014 Six months ended June 30, 2014
 Number of Outstanding recorded investment Number of Outstanding recorded investment Number of Outstanding recorded investment Number of Outstanding recorded investment
(dollars in thousands) contracts Pre-modification Post-modification contracts Pre-modification Post-modification contracts Pre-modification Post-modification contracts Pre-modification Post-modification
Troubled debt restructurings    
  
    
  
    
  
    
  
Real estate loans:    
  
    
  
    
  
    
  
Residential 1-4 family 5 $921
 $935
 4 $1,122
 $1,063
 7 $2,194
 $2,212
 12 $3,115
 $3,147
Commercial real estate — —
 —
 — —
 —
 — —
 —
 — —
 —
Home equity line of credit — —
 —
 4 462
 215
 — —
 —
 — —
 —
Residential land 7 1,133
 1,133
 3 924
 868
 9 2,915
 2,915
 16 4,048
 4,048
Commercial loans 3 473
 473
 — —
 —
 2 754
 754
 5 1,227
 1,227
Consumer loans — —
 —
 — —
 —
 — —
 —
 — —
 —
 15 $2,527
 $2,541
 11 $2,508
 $2,146
 18 $5,863
 $5,881
 33 $8,390
 $8,422

  Three months ended June 30, 2013 Six months ended June 30, 2013
  Number of Outstanding recorded investment Number of Outstanding recorded investment
(dollars in thousands) contracts Pre-modification Post-modification contracts Pre-modification Post-modification
Troubled debt restructurings    
  
    
  
Real estate loans:    
  
    
  
Residential 1-4 family 14 $4,645
 $4,775
 18 $5,767
 $5,838
Commercial real estate — —
 —
 — —
 —
Home equity line of credit — —
 —
 4 462
 215
Residential land 4 1,116
 1,163
 7 2,040
 2,031
Commercial loans 3 714
 714
 3 714
 714
Consumer loans — —
 —
 — —
 —
  21 $6,475
 $6,652
 32 $8,983
 $8,798
Loans modified in TDRs that experienced a payment default of 90 days or more for the indicated periods, and for which the payment default occurred within one year of the modification, were as follows: 
  Three months ended June 30, 2014 Six months ended June 30, 2014
(dollars in thousands) Number of contracts Recorded investment Number of contracts Recorded investment
Troubled debt restructurings that
 subsequently defaulted
        
Real estate loans:    
    
Residential 1-4 family 1 $390
 1 $390
Commercial real estate — —
 — —
Home equity line of credit — —
 — —
Residential land — —
 — —
Commercial loans — —
 — —
Consumer loans — —
 — —
  1 $390
 1 $390
There were no loans modified in TDRs that experienced a payment default of 90 days or more in the first quarterssecond quarter of 20142013 and six months ended June 30, 2013, and for which the payment default occurred within one year of the modification.
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

39


carrying value of the loan. CommitmentsThere were no commitments to lend additional funds to borrowers whose loans have been designated impaired or whose terms have been modified in TDRs totaled $0.3 millionas of March 31,June 30, 2014.

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 balance sheet. All such agreements are subject to master netting arrangements, which provide for 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
Repurchase agreements  
  
  
June 30, 2014 $142
 $—
 $142
December 31, 2013 145
 —
 145
  Gross amount not offset in the Balance Sheet
(in millions) 
Net amount of 
liabilities presented
in the Balance Sheet
 
Financial
instruments
 
Cash
collateral
pledged
 Net amount
June 30, 2014  
  
  
  
Financial institution $50
 $50
 $—
 $—
Commercial account holders 92
 92
 —
 —
Total $142
 $142
 $—
 $—
         
December 31, 2013  
  
  
  
Financial institution $51
 $51
 $—
 $—
Commercial account holders 94
 94
 —
 —
Total $145
 $145
 $—
 $—
Amortized intangible assets. The table below presents the gross carrying amount, accumulated amortization, valuation allowance and net carrying amount of ASB’s mortgage servicing assets as of March 31,June 30, 2014 and 2013:
March 31 2014 2013
June 30 2014 2013
(in thousands) Gross
carrying amount		 Accumulated amortization Valuation allowance Net
carrying amount		 Gross
carrying amount		 Accumulated amortization Valuation allowance Net
carrying amount		 Gross
carrying amount		 Accumulated amortization Valuation allowance Net
carrying amount		 Gross
carrying amount		 Accumulated amortization Valuation allowance Net
carrying amount
Mortgage servicing assets $26,097
 (14,138) (202) $11,757
 $24,150
 (12,399) (351) $11,400
 $26,357
 (14,578) (174) $11,605
 $24,508
 (12,866) (279) $11,363
Changes in the valuation allowance for mortgage servicing assets were as follows:
(in thousands) 2014
 2013
 2014
 2013
Valuation allowance, January 1 $251
 $498
 $251
 $498
Provision (recovery) (35) (107) (37) (98)
Other-than-temporary impairment (14) (40) (40) (121)
Valuation allowance, March 31 $202
 $351
Valuation allowance, June 30 $174
 $279
ASB recognizes a mortgage servicing asset when a mortgage loan is sold with servicing rights retained. This mortgage servicing right (MSR) is initially capitalized at its presumed 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. The MSR is amortized in proportion to and over the period of estimated net servicing income and assessed for impairment at each reporting date.

ASB stratifies the MSR 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 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.


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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 ASB’s noninterest 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 the bank’s mortgage servicing rights were as follows:
 March 31, 2014
 March 31, 2013
 June 30, 2014
 June 30, 2013
Unpaid principal balance (000s) $1,382,731
 $1,305,811
 $1,392,590
 $1,300,370
Weighted average note-rate 4.07% 4.11% 4.08% 4.08%
Weighted average discount rate 9.8% 9.7% 9.6% 10.1%
Weighted average prepayment speed 8.7% 10.8% 8.3% 9.7%
Derivative Financial Instruments.financial instruments. ASB enters into interest rate lock commitments 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 risk associated with selling loans.
ASB enters into interest rate lock commitments (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.
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 as of March 31,June 30, 2014 and December 31, 2013 were as follows:
 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
(dollars in thousands) Notional amount Fair value Notional amount Fair value Notional amount Fair value Notional amount Fair value
Interest rate lock commitments $17,871
 $194
 $25,070
 $464
 $6,932
 $—
 $25,070
 $464
Forward commitments 19,693
 33
 26,018
 139
 7,887
 —
 26,018
 139
The following table presents ASB’s derivative financial instruments, their fair values, and balance sheet location as of March 31,June 30, 2014 and December 31, 2013:
Derivative Financial Instruments Not Designated                
as Hedging Instruments 1
 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
(dollars in thousands)  Derivative asset  Derivative liability  Derivative asset  Derivative liability  Derivative asset  Derivative liability  Derivative asset  Derivative liability
Interest rate lock commitments $199
 $5
 $488
 $24
 $—
 $—
 $488
 $24
Forward commitments 35
 2
 141
 2
 —
 —
 141
 2
 $234
 $7
 $629
 $26
 $—
 $—
 $629
 $26
1 Derivative assets are included in other assets and derivative liabilities 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 the statements of income for the threesix months ended March 31,June 30, 2014 and 2013.

3541


Derivative Financial Instruments Not DesignatedLocation of net gains    Location of net gains    
as Hedging Instruments(losses) recognized in Three months ended March 31(losses) recognized in Six months ended June 30
(dollars in thousands)the Statement of Income 2014 2013the Statement of Income 2014 2013
Interest rate lock commitmentsMortgage banking income $(270) $—
Mortgage banking income $(464) $(262)
Forward commitmentsMortgage banking income (106) —
Mortgage banking income (139) 900
 $(376) $—
 $(603) $638
Litigation.  In March 2011, a purported class action lawsuit was filed in the First Circuit Court of the state of Hawaii by a customer who claimed that ASB had improperly charged overdraft fees on debit card transactions. The lawsuit is still in its preliminary stage. ASB filed a motion to dismiss the lawsuit on the basis that as a bank chartered under federal law, ASB believes its business practices are governed by federal regulations established for federal savings banks and not by state law. In July 2011, the Circuit Court denied ASB’s motion and ASB appealed that decision. ASB’s appeal is currently pending before the Hawaii Supreme Court. The probable outcome and range of reasonably possible loss remains indeterminable at this time.
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.
5 · Retirement benefits
Defined benefit pension and other postretirement benefit plans information.  For the first threesix months of 2014, the Company contributed $1530 million ($1429 million by the Utilities) to its pension and other postretirement benefit plans, compared to $2142 million ($2141 million by the Utilities) in the first threesix months of 2013. The Company’s current estimate of contributions to its pension and other postretirement benefit plans in 2014 is $59$60 million ($5859 million by the Utilities, $1 million by HEI and nil by ASB), compared to $83 million ($81 million by the Utilities, $2 million by HEI and nil by ASB) in 2013. In addition, the Company expects to pay directly $2 million ($1 million by the Utilities) of benefits in 2014, compared to $2 million ($1 million by the Utilities) paid in 2013.
On July 6, 2012, President Obama signed the Moving Ahead for Progress in the 21st Century Act (MAP-21), which included provisions related to the funding and administration of pension plans. This law does not affect the Company’s or the Utilities' accounting for pension benefits; therefore, the net periodic benefit costs disclosed for the plans were not affected. The Company elected to apply MAP-21 for 2012, which improved the plans’ Adjusted Funding Target Attainment Percentage (AFTAP) for funding and benefit distribution purposes and thereby reduced the 2012 minimum funding requirement and lifted the restrictions on accelerated distribution options (which restrictions were in effect from April 1, 2011 to September 30, 2012) for HEI and the Utilities. MAP-21 caused the minimum required funding under Employee Retirement Income Security Act of 1974 (as amended) to be less than the net periodic cost for 2013 and is expected to have the same effect in 2014; therefore, to satisfy the requirements of the Utilities pension and OPEB tracking mechanisms, the Utilities expect towill contribute the net periodic cost in 2014.
The Pension Protection Act provides that if a pension plan’s funded status falls below certain levels, more conservative assumptions must be used to value obligations under the pension plan. The HEI Retirement Plan met the threshold requirements in each of 2012 and 2013 so that the more conservative assumptions did not apply for either the 2013 or 2014 valuation of plan liabilities for purposes of calculating the minimum required contribution. Other factors could cause changes to the required contribution levels.

3642


The components of net periodic benefit cost for HEI consolidated and Hawaiian Electric consolidated were as follows:
 Pension benefits Other benefits Three months ended June 30 Six months ended June 30
Three months ended March 31 2014 2013 2014 2013
 Pension benefits Other benefits Pension benefits Other benefits
(in thousands)         2014 2013 2014 2013 2014 2013 2014 2013
HEI consolidated                        
Service cost $12,127
 $14,089
 $883
 $1,049
 $12,525
 $14,121
 $866
 $1,103
 $24,652
 $28,210
 $1,749
 $2,152
Interest cost 18,001
 16,106
 2,160
 1,931
 18,113
 16,307
 2,117
 1,855
 36,114
 32,413
 4,277
 3,786
Expected return on plan assets (20,347) (18,085) (2,708) (2,562) (20,334) (18,182) (2,748) (2,521) (40,681) (36,267) (5,456) (5,083)
Amortization of net prior service loss (gain) 22
 (24) (448) (448) 22
 (25) (449) (449) 44
 (49) (897) (897)
Amortization of net actuarial loss (gain) 5,038
 9,819
 (3) 521
 5,138
 9,499
 (3) 284
 10,176
 19,318
 (6) 805
Net periodic benefit cost (credit) 14,841
 21,905
 (116) 491
 15,464
 21,720
 (217) 272
 30,305
 43,625
 (333) 763
Impact of PUC D&Os (3,011) (8,866) 445
 (397) (3,651) (10,724) 543
 (187) (6,662) (19,590) 988
 (584)
Net periodic benefit cost (adjusted for impact of PUC D&Os) $11,830
 $13,039
 $329
 $94
 $11,813
 $10,996
 $326
 $85
 $23,643
 $24,035
 $655
 $179
Hawaiian Electric consolidated                        
Service cost $11,697
 $13,603
 $856
 $1,014
 $12,101
 $13,638
 $840
 $1,067
 $23,798
 $27,241
 $1,696
 $2,081
Interest cost 16,436
 14,676
 2,079
 1,861
 16,553
 14,883
 2,038
 1,783
 32,989
 29,559
 4,117
 3,644
Expected return on plan assets (18,171) (16,090) (2,663) (2,520) (18,158) (16,185) (2,707) (2,480) (36,329) (32,275) (5,370) (5,000)
Amortization of net prior service loss (gain) 15
 (116) (451) (451) 16
 (116) (451) (451) 31
 (232) (902) (902)
Amortization of net actuarial loss 4,560
 8,790
 —
 504
 4,669
 8,509
 —
 268
 9,229
 17,299
 —
 772
Net periodic benefit cost (credit) 14,537
 20,863
 (179) 408
 15,181
 20,729
 (280) 187
 29,718
 41,592
 (459) 595
Impact of PUC D&Os (3,011) (8,866) 445
 (397) (3,651) (10,724) 543
 (187) (6,662) (19,590) 988
 (584)
Net periodic benefit cost (adjusted for impact of PUC D&Os) $11,526
 $11,997
 $266
 $11
 $11,530
 $10,005
 $263
 $—
 $23,056
 $22,002
 $529
 $11
HEI consolidated recorded retirement benefits expense of $817 million ($816 million by the Utilities) and $1018 million ($915 million by the Utilities) in the first threesix months of 2014 and 2013, respectively, and charged the remaining net periodic benefit cost primarily to electric utility plant.
The Company and the Utilities have revised their prior year disclosures to correct the amount disclosed for the “Impact of PUC D&Os.” The misstatement was not considered to be material to previously issued financial statements. The table below illustrates the effects of this revision on the previous disclosures (the revised disclosures had no impact on the Company’s and the Utilities' Consolidated Balance Sheets, Consolidated Statements of Income or Consolidated Statements of Cash Flows):
 HEI consolidated Hawaiian Electric consolidated HEI consolidated Hawaiian Electric consolidated
Three months ended March 31, 2013  As previously
      As previously
    

  As previously
      As previously
    
(in thousands)  filed
  As revised
  Difference
  filed
  As revised
  Difference
  filed
  As revised
  Difference
  filed
  As revised
  Difference
Three months ended June 30, 2013            
Pension benefits:                        
Impact of PUC D&Os $(7,436) $(8,866) $(1,430) $(7,436) $(8,866) $(1,430) $(5,286) $(10,724) $(5,438) $(5,286) $(10,724) $(5,438)
Net periodic benefit cost (adjusted                        
for impact of PUC D&Os) 14,469
 13,039
 (1,430) 13,427
 11,997
 (1,430) 16,434
 10,996
 (5,438) 15,443
 10,005
 (5,438)
                        
Six months ended June 30, 2013            
Pension benefits:            
Impact of PUC D&Os (12,722) (19,590) (6,868) (12,722) (19,590) (6,868)
Net periodic benefit cost (adjusted            
for impact of PUC D&Os) 30,903
 24,035
 (6,868) 28,870
 22,002
 (6,868)
(in millions)  
  
  
  
  
  
  
  
  
  
  
  
Retirement benefits expense $11
 $10
 $(1) $10
 $9
 $(1) $23
 $18
 $(5) $21
 $15
 $(6)
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

43


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 threesix months of 2014 and 2013, the Company’s expense for its defined contribution pension plans under the Hawaiian Electric Industries Retirement Savings Plan (HEIRSP) and the ASB 401(k) Plan was $1.12.2 million and $1.02.0 million, respectively, and cash contributions were $2.83.5 million and $2.43.0 million, respectively. For the first threesix months of 2014 and 2013, the Utilities’ expense for its defined contribution pension plan was $0.2$0.4 million and $0.3 million, respectively, and cash contributions were $0.2 million.$0.4 million and $0.3 million, respectively.

37


6 · Share-based compensation
Under the 2010 Equity and Incentive Plan, (EIP) HEI can issue shares of common stock as incentive compensation to selected employees in the form of stock options, stock appreciation rights (SARs), restricted shares, restricted stock units, performance shares and other share-based and cash-based awards. The 2010 Equity and Incentive Plan was amended and restated (EIP) effective March 1, 2014 and an additional 1.5 million shares was added to the shares available for issuance under these programs.
As of March 31,June 30, 2014, there wereapproximately 3.23.6 million shares remainingwere available for future issuance under the terms of the EIP, assuming recycling of whichshares withheld to satisfy minimum statutory tax liabilities relating to EIP awards, including an estimated 2.91.1 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 (based on the assumption(assuming that long-term incentive plan (LTIP) awardssuch performance goals are achieved at maximum levels).
Under the 1987 Stock Option and Incentive Plan, as amended (SOIP), there are possible future issuances of an estimated 1,000 shares upon the exercise of outstanding SARs and dividend equivalents,equivalents; however, based on the market price of shares on March 31,June 30, 2014., the SARS had no intrinsic value. As of May 11, 2010 (when the EIP2010 Equity and Incentive Plan became effective), no new awards may be granted under the SOIP. After the shares of common stock for the outstanding SOIP grants and awards are issued or such grants and awards expire, the remaining shares registered under the SOIP will be deregistered and delisted.
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 March 31,June 30, 2014, there were 202,460169,290 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 March 31 Three months ended June 30 Six months ended June 30
(in millions) 2014 2013 2014 2013 2014 2013
HEI consolidated            
Share-based compensation expense 1
 $2.4
 $2.1
 $2.8
 $1.3
 $5.2
 $3.5
Income tax benefit 0.8
 0.8
 1.1
 0.5
 1.9
 1.3
Hawaiian Electric consolidated            
Share-based compensation expense 1
 0.7
 0.7
 $0.9
 $0.3
 1.6
 1.1
Income tax benefit 0.3
 0.3
 $0.3
 $0.1
 0.6
 0.4
1 
$0.040.03 million and $0.03$0.02 million of this share-based compensation expense was capitalized in the three months ended March 31,second quarter of 2014 and 2013, respectively. $0.07 million and $0.05 million of this share-based compensation expense was capitalized in the six months ended June 30, 2014 and 2013, respectively.
The Company has revised its prior year disclosure to correct for an error that excluded from the disclosure amounts for stock awards to non-employee directors of HEI, Hawaiian Electric and ASB. The amounts excluded from the disclosure were not considered to be material to previously issued financial statements. The table below illustrates the effects of this revision on the previous disclosure (the revised disclosure had no impact on the Company’s Consolidated Balance Sheets, Consolidated Statements of Income or Consolidated Statements of Cash Flows):
  Three months ended June 30, 2013 Six months ended June 30, 2013
(in millions) As previously filed
 As revised
 Difference
 As previously filed
 As revised
 Difference
Share-based compensation expense $1.1
 $1.3
 $0.2
 $3.0
 $3.5
 $0.5
Income tax benefit 0.4
 0.5
 0.1
 1.1
 1.3
 0.2

44


Stock awards. In the second quarter of each year, HEI grants sharesgranted HEI common stock to nonemployee directors of HEI, Hawaiian Electric and ASB under the 2011 Director Plan. Plan as follows:
 Six months ended June 30
($ in millions)2014 2013
Shares granted33,170
 33,184
Fair value$0.8
 $0.8
Income tax benefit0.3
 0.3
The number of shares issued to each nonemployee director of HEI, Hawaiian Electric and ASB is determined based on the closing price of HEI Common Stock on the grant date.

Nonqualified stock options. Since April 9, 2013, there were no nonqualified stock options (NQSOs) outstanding.
NQSO activity and statistics were as follows:
(dollars in thousands, except prices) Three months ended 
 March 31, 2013		 Three months ended June 30, 2013 Six months ended 
 June 30, 2013
Shares exercised 2,000
 12,000
 14,000
Weighted-average exercise price $20.49
 $20.49
 $20.49
Cash received from exercise $41
 $246
 $287
Intrinsic value of shares exercised 1
 $15
 $113
 $128
Tax benefit realized for the deduction of exercises $6
 $44
 $50
 

1          Intrinsic value is the amount by which the fair market value of the underlying stock and the related dividend equivalents exceeds the exercise price of the option.


38


Stock appreciation rights.  Information about HEI’s SARs was as follows:
March 31, 2014 Outstanding & Exercisable (Vested)
June 30, 2014June 30, 2014Outstanding & Exercisable (Vested)
Year of
grant
 
Range of
exercise prices
 
Number of shares
underlying SARs
 
Weighted-average
remaining
contractual life
 
Weighted-average
exercise price
 
Number of shares
underlying SARs
 
Weighted-average
remaining
contractual life
 
Weighted-average
exercise price
2004 $26.02 62,000
 0.1 $26.02
2005 26.18 102,000
 1.0 26.18
 102,000
 0.8 $26.18
 $26.02-26.18 164,000
 0.7 $26.12
As of December 31, 2013, the shares underlying SARs outstanding totaled 164,000, with a weighted-average exercise price of $26.12. As of March 31,June 30, 2014, all SARs outstanding were exercisable and had no aggregate intrinsic value. In April 2014, the shares underlying SARs totaling 62,000, with a weighted-average exercise price of $26.02, expired.
Restricted shares.As of March 31,June 30, 2014 and December 31, 2013, the outstanding restricted shares totaled 4,503 with a weighted-average exercise price of $22.21. For the first quarterssix months of 2014 and 2013, there was no activity relating to restricted shares. As of March 31,June 30, 2014, there was $0.1 million46,000 of total unrecognized compensation cost related to nonvested restricted shares and restricted stock awards. The cost is expected to be recognized over a weighted-average period of 0.70.4 years.
Restricted stock units.  Information about HEI’s grants of restricted stock units was as follows:
 Three months ended March 31Three months ended June 30 Six months ended June 30
 2014 20132014 2013 2014 2013
 Shares (1) Shares (1)Shares (1) Shares (1) Shares (1) Shares (1)
Outstanding, beginning of period 288,151
 $25.17
 315,094
 $22.82
332,158
 $25.04
 301,145
 $25.15
 288,151
 $25.17
 315,094
 $22.82
Granted 115,036

25.19
 107,231

26.89
—

—
 —
 —
 115,036

25.19
 107,231

26.89
Vested (71,029) 25.79
 (113,212) 20.30
(67,832) 22.31
 (832) 26.60
 (138,861) 24.09
 (114,044) 20.34
Forfeited —
 —
 (7,968) 25.26
—
 —
 —
 —
 —
 —
 (7,968) 25.26
Outstanding, end of period 332,158
 $25.04
 301,145
 $25.15
264,326
 $25.74
 300,313
 $25.15
 264,326
 $25.74
 300,313
 $25.15
Total weighted-average grant-date fair value of shares granted ($ millions) $2.9
   $2.9
  $—
   $—
   $2.9
   $2.9
  
(1)Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.
As of March 31,June 30, 2014, there was $6.35.6 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 3.02.8 years.

45


For the first threesix months of 2014 and 2013, total restricted stock units that vested and related dividends had a grant-date fair value of $2.04.0 million and $3.5 million, respectively, and the related tax benefits were $0.71.3 million and $1.11.0 million, respectively.
LTIP payable in stock.  The 2012-2014 LTIP, 2013-2015 LTIP and 2014-2016 LTIP, provide for performance awards under the EIP of shares of HEI common stock based on the satisfaction of performance goals considered to be a market condition and service conditions. The number of shares of HEI common stock that may be awarded is fixed on the date the grants are made subject to the achievement of specified performance levels. The potential payout varies from 0% to 200% of the number of target shares depending on achievement of the goals. The LTIP performance goals for the LTIP periods include awards with a market goal based on total return to shareholders (TRS) of HEI stock as a percentile to the Edison Electric Institute Index over the applicable three-year period. In addition, the 2012-2014 LTIP, 2013-2015 LTIP and 2014-2016 LTIP have performance goals related to levels of HEI consolidated net income, HEI consolidated return on average common equity (ROACE), Hawaiian Electric consolidated net income, Hawaiian Electric consolidated ROACE, ASB net income and ASB return on assets — all based on the applicable three-year averages.

39


LTIP linked to TRS.  Information about HEI’s LTIP grants linked to TRS was as follows:
 Three months ended March 31Three months ended June 30 Six months ended June 30
 2014 20132014 2013 2014 2013
 Shares (1) Shares (1)Shares (1) Shares (1) Shares (1) Shares (1)
Outstanding, beginning of period 232,127
 $32.88
 239,256
 $29.12
258,243
 $28.46
 235,064
 $32.87
 232,127
 $32.88
 239,256
 $29.12
Granted (target level) 96,793
 22.95
 89,533

32.69
731
 22.95
 —
 —
 97,524
 22.95
 89,533

32.69
Vested (issued or unissued and cancelled) (70,189) 35.46
 (87,753) 22.45
—
 —
 —
 —
 (70,189) 35.46
 (87,753) 22.45
Forfeited (488) 32.13
 (5,972) 32.96
(1,018) 26.50
 —
 —
 (1,506) 28.32
 (5,972) 32.96
Outstanding, end of period 258,243
 $28.46
 235,064
 $32.87
257,956
 $28.45
 235,064
 $32.87
 257,956
 $28.45
 235,064
 $32.87
Total weighted-average grant-date fair value of shares granted ($ millions) $2.2
   $2.9
  $—
   $—
   $2.2
   $2.9
  
(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 TRS and the resulting fair value of LTIP awards granted:
 2014 2013
Risk-free interest rate0.66% 0.38%
Expected life in years3
 3
Expected volatility17.8% 19.4%
Range of expected volatility for Peer Group12.4% to 23.3%
 12.4% to 25.3%
Grant date fair value (per share)$22.95
 $32.69
 For the threesix months ended March 31,June 30, 2014 and 2013, total vested LTIP awards linked to TRS and related dividends had a fair value of nil and $2.2 million, respectively, and the related tax benefits were nil and $0.9 million, respectively. For the threesix months ended March 31,June 30, 2014, all of the shares vested (which were granted at target level based on the satisfaction of TRS performance) for the 2011-2013 LTIP lapsed.
As of March 31,June 30, 2014, there was $3.83.3 million of total unrecognized compensation cost related to the nonvested performance awards payable in shares linked to TRS. The cost is expected to be recognized over a weighted-average period of 1.81.6 years.

46


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 March 31Three months ended June 30 Six months ended June 30
 2014 20132014 2013 2014 2013
 Shares (1) Shares (1)Shares (1) Shares (1) Shares (1) Shares (1)
Outstanding, beginning of period 296,843
 $26.14
 247,175
 $25.04
360,070
 $26.01
 341,824
 $26.00
 296,843
 $26.14
 247,175
 $25.04
Granted (target level) 128,873
 25.19
 118,895

26.89
730
 23.34
 —

—
 129,603
 25.18
 118,895

26.89
Vested (issued) (65,089) 24.95
 (18,275) 18.95
—
 —
 —
 —
 (65,089) 24.95
 (18,275) 18.95
Cancelled—
 —
 (37,351) 24.96
 —
 —
 (37,351) 24.96
Forfeited (557) 26.55
 (5,971) 25.94
(1,018) 25.81
 —
 —
 (1,575) 26.07
 (5,971) 25.94
Outstanding, end of period 360,070
 $26.01
 341,824
 $26.00
359,782
 $26.01
 304,473
 $26.12
 359,782
 $26.01
 304,473
 $26.12
Total weighted-average grant-date fair value of shares granted (at target performance levels) ($ millions) $3.2
   $3.2
  $—
   $—
   $3.3
   $3.2
  
(1)Weighted-average grant-date fair value per share based on the average price of HEI common stock on the date of grant.

40


For the threesix months ended March 31,June 30, 2014 and 2013, total vested LTIP awards linked to other performance conditions and related dividends had a fair value of $1.9 million and $0.6 million and the related tax benefits were $0.8 million and $0.2 million, respectively.
As of March 31,June 30, 2014, there was $5.54.8 million of total unrecognized compensation cost related to the nonvested shares linked to performance conditions other than TRS. The cost is expected to be recognized over a weighted-average period of 1.81.5 years.
7 · Earnings per share and shareholders’ equity
Earnings per share. Under the two-class method of computing earnings per share (EPS), EPS was comprised as follows for both participating securities and unrestricted common stock:
 Three months ended March 31Three months ended June 30 Six months ended June 30
 2014 201320142013 2014 2013
 Basic and
diluted		 
Basic and
diluted
Basic and
diluted		 
Basic and
diluted
 Basic and
diluted		 
Basic and
diluted
Distributed earnings $0.31
 $0.31
$0.31
 $0.31
 $0.62
 $0.62
Undistributed earnings 0.14
 0.03
0.10
 0.10
 0.24
 0.13
 $0.45
 $0.34
$0.41
 $0.41
 $0.86
 $0.75
As of March 31,June 30, 2014 and June 30, 2013, the antidilutive effects of SARs ofon 102,000 shares of HEI common stock for(for which the exercise prices were greater than the closing market price of HEI’s common stock on such dates) were not included in the computation of dilutive EPS. As of March 31, 2013, there were no shares that were antidilutive.
Shareholders’ equity.
Equity forward transaction.  On March 19, 2013, HEI entered into an equity forward transaction in connection with a public offering on that date of 6.1 million shares of HEI common stock at $26.75 per share. On March 19, 2013, HEI common stock closed at $27.01 per share. On March 20, 2013, the underwriters exercised their over-allotment option in full and HEI entered into an equity forward transaction in connection with the resulting additional 0.9 million shares of HEI common stock.
The use of an equity forward transaction substantially eliminates future equity market price risk by fixing a common equity offering sales price under the then existing market conditions, while mitigating immediate share dilution resulting from the offering by postponing the actual issuance of common stock until funds are needed in accordance with the Company’s capital investment plans. Pursuant to the terms of these transactions, a forward counterparty borrowed 7 million shares of HEI’s common stock from third parties and sold them to a group of underwriters for $26.75 per share, less an underwriting discount equal to $1.00312 per share. Under the terms of the equity forward transactions, to the extent that the transactions are physically settled, HEI would be required to issue and deliver shares of HEI common stock to the forward counterparty at the then applicable forward sale price. The forward sale price was initially determined to be $25.74688 per share at the time the equity forward transactions were entered into, and the amount of cash to be received by HEI upon physical settlement of the equity forward is subject to certain adjustments in accordance with the terms of the equity forward transactions. The equity forward transactions must be settled fully by March 25, 2015. Except in specified circumstances or events that would require

47


physical settlement, HEI is able to elect to settle the equity forward transactions by means of physical, cash or net share settlement, in whole or in part, at any time on or prior to March 25, 2015.
The equity forward transactions had no initial fair value since they were entered into at the then market price of the common stock. HEI receives proceeds from the sale of common stock when the equity forward transactions are settled and records the proceeds at that time in equity. HEI concluded that the equity forward transactions were equity instruments based on the accounting guidance in ASC 480, "Distinguishing Liabilities from Equity," and ASC 815, "Derivatives and Hedging," and that they qualified for an exception from derivative accounting under ASC 815 because the forward sale transactions were indexed to its own stock. On December 19, 2013, HEI settled 1.3 million shares under the equity forward for proceeds of $32.1 million (net of the underwriting discount of $1.3 million), which funds were ultimately used to purchase Hawaiian Electric shares. HEI anticipates settling the remaining 5.7 million shares remaining under the equity forward transactions through physical settlement.
At March 31,June 30, 2014, the equity forward transactions could have been settled with physical delivery of the shares to the forward counterparty of (a) 5.7 million shares in exchange for cash of $139$136 million,. At March 31, 2014, the shares remaining under the equity forward transactions could also have been cash settled, with delivery of (b) cash of approximately $6$5 million (which amount includes $6 million of underwriting discount) to the forward counterparty,, or net share(c) approximately 188,000 shares.
On July 14, 2014, HEI settled with delivery of approximately 220,0001.0 million shares of common stockthe remaining 5.7 million shares under the equity forward for proceeds of $23.9 million, which funds will be used primarily later in 2014 to invest in Hawaiian Electric to fund its capital expenditures, to repay short-term borrowings incurred to finance or refinance such capital expenditures and/or for reimbursement of funds used for payment of capital expenditures and in the forward counterparty.interim have been applied by HEI to repay its short-term borrowings and for working capital and general corporate purposes.

41


Prior to their settlement, the shares remaining under the equity forward transactions will be reflected in HEI’s diluted EPS calculations using the treasury stock method. Under this method, the number of shares of HEI’s common stock used in calculating diluted EPS for a reporting period would be increased by the number of shares, if any, that would be issued upon physical settlement of the equity forward transactions less the number of shares that could be purchased by HEI in the market (based on the average market price during that reporting period) using the proceeds receivable upon settlement of the equity forward transactions (based on the adjusted forward sale price at the end of that reporting period). The excess number of shares is weighted for the portion of the reporting period in which the equity forward transactions are outstanding.
Accordingly, before physical or net share settlement of the equity forward transactions, and subject to the occurrence of certain events, HEI anticipates that the forward sale agreement and additional forward sale agreement will have a dilutive effect on HEI’s EPS only during periods when the applicable average market price per share of HEI’s common stock is above the per share adjusted forward sale price, as described above. However, if HEI decides to physically or net share settle the forward sale agreement and additional forward sale agreement, any delivery by HEI of shares upon settlement could result in dilution to HEI’s EPS.
For the threesix months ended March 31,June 30, 2014, the equity forward transactions did not have a material dilutive effect on HEI’s EPS.
Accumulated other comprehensive income.  Changes in the balances of each component of accumulated other comprehensive income/(loss) (AOCI) were as follows:
HEI Consolidated Hawaiian Electric ConsolidatedHEI Consolidated Hawaiian Electric Consolidated
(in thousands) Net unrealized losses on securities  Unrealized losses on derivatives  Retirement benefits plans AOCI  AOCI -retirement benefit plans Net unrealized gains (losses) on securities  Unrealized losses on derivatives  Retirement benefit plans AOCI  AOCI -retirement benefit plans
Balance, December 31, 2013$(3,663) $(525) $(12,562) $(16,750) $608
$(3,663) $(525) $(12,562) $(16,750) $608
Current period other comprehensive income805
 59
 303
 1,167
 9
3,348
 118
 601
 4,067
 22
Balance, March 31, 2014$(2,858) $(466) $(12,259) $(15,583) $617
Balance, June 30, 2014$(315) $(407) $(11,961) $(12,683) $630
                  
Balance, December 31, 2012$10,761
 $(760) $(36,424) $(26,423) $(970)$10,761
 $(760) $(36,424) $(26,423) $(970)
Current period other comprehensive income(828) 59
 708
 (61) 18
Balance, March 31, 2013$9,933
 $(701) $(35,716) $(26,484) $(952)
Current period other comprehensive income (loss)(9,873) 118
 1,389
 (8,366) 35
Balance, June 30, 2013$888
 $(642) $(35,035) $(34,789) $(935)

4248


Reclassifications out of AOCI were as follows:
Amount reclassified from AOCI   Amount reclassified from AOCI  
 Three months  
 ended March 31		   Three months  
 ended June 30		 Six months  
 ended June 30		  
(in thousands) 2014 2013 Affected line item in the Statement of Income 2014 2013 2014 2013 Affected line item in the Statement of Income
HEI consolidated              
Net realized gains on securities $(1,715) $—
 Revenues-bank (net gains on sales of securities) $—
 $(738) $(1,715) $(738) Revenues-bank (net gains on sales of securities)
Derivatives qualified as cash flow hedges  
  
    
  
  
  
  
Interest rate contracts (settled in 2011) 59
 59
 Interest expense 59
 59
 118
 118
 Interest expense
Retirement benefit plan items  
  
    
  
  
  
  
Amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost 2,813
 6,021
 See Note 5 for additional details 2,873
 5,680
 5,686
 11,701
 See Note 5 for additional details
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets (2,510) (5,313) See Note 5 for additional details (2,575) (4,999) (5,085) (10,312) See Note 5 for additional details
Total reclassifications $(1,353) $767
   $357
 $2
 $(996) $769
  
Hawaiian Electric consolidated              
Retirement benefit plan items    
      
    
  
Amortization of transition obligation, prior service credit and net losses recognized during the period in net periodic benefit cost $2,519
 $5,331
 See above $2,588
 $5,016
 $5,107
 $10,347
 See Note 5 for additional details
Less: reclassification adjustment for impact of D&Os of the PUC included in regulatory assets (2,510) (5,313) See above (2,575) (4,999) (5,085) (10,312) See Note 5 for additional details
Total reclassifications $9
 $18
   $13
 $17
 $22
 $35
  

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

4349


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

The Company and/or the Utilities used the following methods and assumptions to estimate the fair value of each applicable class of financial instruments for which it is practicable to estimate that value:
Short term borrowings—other than bank.  The carrying amount approximated fair value because of the short maturity of these instruments.
Investment and mortgage-related securities.  To determine the fair value of investment securities held in ASB’s available-for-sale portfolio, independent third-party vendor or broker pricing is used on an unadjusted basis. Prices for investments and mortgage-related securities are based on observable inputs, including historical trading levels or sector yields, using market-based valuation techniques. The third party pricing service uses applications, models and pricing matrices that correlate security prices to benchmark securities which are adjusted for various inputs. Inputs include: benchmark yields, reported trades, broker/dealer quotes, issuer spreads, two-sided markets, benchmark security bids and offers, TBA (to be announced) prices, monthly payment information, and reference data including market research. The pricing service may prioritize inputs differently on any given day for any security, and not all inputs are available for use in the evaluation process on any given day or for each security.  The pricing vendor corroborates its finding on an on-going basis by monitoring market activity and events.
Third party pricing services provide security prices in good faith using rigorous methodologies; however, they do not warrant or guarantee the adequacy or accuracy of their information. Therefore, ASB utilizes a separate third party pricing vendor to corroborate security pricing of the first pricing vendor. If the pricing differential between the two pricing sources exceeds an established threshold, a pricing inquiry will be sent to both vendors or to an independent broker to determine a price that can be supported based on observable inputs found in the market. Such challenges to pricing are required infrequently and are generally resolved using additional security-specific information that was not available to a specific vendor.
Loans receivable.  The estimated fair value of loans receivable is determined based on characteristics such as loan category, repricing features and remaining maturity, and includes prepayment estimates.
For residential real estate loans, fair values were estimated by discounting estimated cash flows using discount rates based on current industry pricing for loans with similar contractual characteristics and remaining maturity.
For other types of loans, fair values were estimated by discounting contractual cash flows using discount rates that reflect current industry pricing for loans with similar characteristics and remaining maturity. Where industry pricing is not available, discount rates are based on ASB’s current pricing for loans with similar characteristics and remaining maturity.
The fair value of all loans was adjusted to reflect current assessments of loan collectability. Also see “Fair value measurements on a nonrecurring basis” below.
Deposit liabilities.  The fair value of savings, negotiable orders of withdrawal, demand and money market deposits was the amount payable on demand at the reporting date. 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 bank borrowings.  Fair value was estimated by discounting the future cash flows using the current rates available for borrowings with similar credit terms and remaining maturities.
Long-term debt.  Fair value 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 remaining maturities.
Derivative financial instruments.  See “Fair value measurements on a recurring basis” below.
Off-balance sheet financial instruments. The fair value of loans serviced for others was calculated by discounting expected net income streams using discount rates that reflect industry pricing for similar assets. Expected net income streams were estimated based on industry assumptions regarding prepayment speeds and income and expenses associated with servicing residential mortgage loans for others. The fair value of commitments to originate loans was estimated based on the change in current primary market prices of new commitments. Since lines of credit can expire without being drawn and customers are under no obligation to utilize the lines, no fair value was assigned to unused lines of credit. The fair value of letters of credit was estimated based on the fees currently charged to enter into similar agreements, taking into account the remaining terms of the agreements.

4450


The estimated fair values of certain of the Company’s and the Utilities' financial instruments were as follows: 
   Estimated fair value   Estimated fair value
 
Carrying or
notional amount
 
Quoted
 prices in
active markets
for identical assets
 
Significant
 other observable
 inputs
 
Significant
unobser-vable
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
March 31, 2014  
  
  
  
  
June 30, 2014  
  
  
  
  
Financial assets  
  
  
  
  
  
  
  
  
  
Money market funds $10
 $—
 $10
 $—
 $10
 $10
 $—
 $10
 $—
 $10
Available-for-sale investment and mortgage-related securities 517,534
 —
 517,534
 —
 517,534
 549,321
 —
 549,321
 —
 549,321
Investment in stock of Federal Home Loan Bank of Seattle 86,697
 —
 86,697
 —
 86,697
 80,863
 —
 80,863
 —
 80,863
Loans receivable, net 4,151,900
 —
 —
 4,259,181
 4,259,181
 4,246,196
 —
 —
 4,398,639
 4,398,639
Derivative assets 34,442
 22
 212
 —
 234
 6,932
 —
 —
 —
 —
Financial liabilities  
  
  
  
    
  
  
  
  
Deposit liabilities 4,477,987
 —
 4,479,848
 —
 4,479,848
 4,524,860
 —
 4,526,690
 —
 4,526,690
Short-term borrowings—other than bank 136,369
 —
 136,369
 —
 136,369
 185,175
 —
 185,175
 —
 185,175
The Utilities' short-term borrowings (included in amount above) 34,996
 —
 34,996
 —
 34,996
 102,989
 —
 102,989
 —
 102,989
Other bank borrowings 244,642
 —
 255,357
 —
 255,357
 242,455
 —
 252,868
 —
 252,868
Long-term debt, net—other than bank 1,492,945
 —
 1,564,394
 —
 1,564,394
 1,517,945
 —
 1,636,175
 —
 1,636,175
The Utilities' long-term debt, net (included in amount above) 1,217,945
 —
 1,282,346
 —
 1,282,346
 1,217,945
 —
 1,325,102
 —
 1,325,102
Derivative liabilities 3,122
 —
 7
 —
 7
 7,887
 —
 —
 —
 —
December 31, 2013  
  
  
  
  
  
  
  
  
  
Financial assets  
  
  
  
  
  
  
  
  
  
Money market funds $10
 $—
 $10
 $—
 $10
 $10
 $—
 $10
 $—
 $10
Available-for-sale investment and mortgage-related securities 529,007
 —
 529,007
 —
 529,007
 529,007
 —
 529,007
 —
 529,007
Investment in stock of Federal Home Loan Bank of Seattle 92,546
 —
 92,546
 —
 92,546
 92,546
 —
 92,546
 —
 92,546
Loans receivable, net 4,115,415
 —
 —
 4,211,290
 4,211,290
 4,115,415
 —
 —
 4,211,290
 4,211,290
Derivative assets 46,356
 98
 531
 —
 629
 46,356
 98
 531
 —
 629
Financial liabilities  
  
  
  
    
  
  
  
  
Deposit liabilities 4,372,477
 —
 4,374,377
 —
 4,374,377
 4,372,477
 —
 4,374,377
 —
 4,374,377
Short-term borrowings—other than bank 105,482
 —
 105,482
 —
 105,482
 105,482
 —
 105,482
 —
 105,482
Other bank borrowings 244,514
 —
 256,029
 —
 256,029
 244,514
 —
 256,029
 —
 256,029
Long-term debt, net—other than bank 1,492,945
 —
 1,508,425
 —
 1,508,425
 1,492,945
 —
 1,508,425
 —
 1,508,425
The Utilities' long-term debt, net (included in amount above) 1,217,945
 —
 1,228,966
 —
 1,228,966
 1,217,945
 —
 1,228,966
 —
 1,228,966
Derivative liabilities 4,732
 —
 26
 —
 26
 4,732
 —
 26
 —
 26
 As of March 31,June 30, 2014 and December 31, 2013, loan commitments and unused lines and letters of credit issued by ASB had notional amounts of $1.7 billion and $1.6 billion, respectively, and their estimated fair value on such dates were $0.60.5 million and $0.2 million, respectively. As of March 31,June 30, 2014 and December 31, 2013, loans serviced by ASB for others had notional amounts of $1.4 billion, and the estimated fair value of the servicing rights for such loans was $15.9 million and $15.7 million, respectively. 

Fair value measurements on a recurring basis.
Securities. While securities held in ASB’s investment portfolio trade in active markets, they do not trade on listed exchanges nor do the specific holdings trade in quoted markets by dealers or brokers. All holdings are valued using market-based approaches that are based on exit prices that are taken from identical or similar market transactions, even in situations

45


where trading volume may be low when compared with prior periods. Inputs to these valuation techniques reflect the

51


assumptions that consider credit and nonperformance risk that market participants would use in pricing the asset based on market data obtained from independent sources. Available-for-sale securities were comprised of federal agency obligations and mortgage-backed securities and municipal bonds.
Derivative financial instruments. ASB enters into interest rate lock commitments (IRLC) 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. 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.
ASB utilizes forward commitments as economic hedges against potential changes in the values of the IRLCs and loans held for sale. To reduce the impact of price fluctuations of IRLC and mortgage loans held for sale, ASB will purchase to be announced (TBA) mortgage-backed securities forward commitments, mandatory and best effort commitments. These commitments help protect ASB's loan sale profit margin from fluctuations in interest rates.  The changes in the fair value of these commitments are recognized as part of mortgage banking income on the consolidated statements of income. TBA 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 similarly to the IRLCs using quoted prices in the market place that are observable and are classified as Level 2 measurements.
Assets and liabilities measured at fair value on a recurring basis were as follows:
 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
 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) $—
 $10
 $—
 $—
 $10
 $—
 $—
 $10
 $—
 $—
 $10
 $—
Available-for-sale securities (bank segment)  
  
  
  
  
  
  
  
  
  
  
  
Mortgage-related securities-FNMA, FHLMC and GNMA $—
 $431,014
 $—
 $—
 $369,444
 $—
 $—
 $447,292
 $—
 $—
 $369,444
 $—
U.S. Treasury and federal agency obligations —
 86,520
 —
 —
 80,973
 —
 —
 102,029
 —
 —
 80,973
 —
Municipal bonds —
 —
 —
 —
 78,590
 —
 —
 —
 —
 —
 78,590
 —
 $—
 $517,534
 $—
 $—
 $529,007
 $—
 $—
 $549,321
 $—
 $—
 $529,007
 $—
Derivative assets 1
  
  
  
  
  
  
  
  
  
  
  
  
Interest rate lock commitments $—
 $199
 $—
 $—
 $488
 $—
 $—
 $—
 $—
 $—
 $488
 $—
Forward commitments 22
 13
 —
 98
 43
 —
 —
 —
 —
 98
 43
 —
 $22
 $212
 $—
 $98
 $531
 $—
 $—
 $—
 $—
 $98
 $531
 $—
Derivative liabilities 1
                        
Interest rate lock commitments $—
 $5
 $—
 $—
 $24
 $—
 $—
 $—
 $—
 $—
 $24
 $—
Forward commitments —
 2
 —
 —
 2
 —
 —
 —
 —
 —
 2
 —
 $—
 $7
 $—
 $—
 $26
 $—
 $—
 $—
 $—
 $—
 $26
 $—
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.
 
Fair value measurements on a nonrecurring basis.  From time to time, the Company and the Utilities may be required to measure certain assets at fair value on a nonrecurring basis in accordance with GAAP. These adjustments to fair value usually result from the writedowns of individual assets. ASB does not record loans at fair value on a recurring basis. However, from time to time, ASB records nonrecurring fair value adjustments based on the current appraised value of the collateral securing impaired loans or unobservable market assumptions. Unobservable assumptions reflect ASB’s own estimate of the fair value of collateral used in valuing impaired loans. ASB may also be required to measure goodwill at fair value on a nonrecurring basis. During the first threesix months of 2014, it was not required that a measurement of the fair value of goodwill be calculated and goodwill was not measured at fair value.

4652


Assets measured at fair value on a nonrecurring basis were as follows:
   Fair value measurements   Fair value measurements
(in millions)  Balance Level 1 Level 2 Level 3 Balance Level 1 Level 2 Level 3
Loans  
  
  
  
  
  
  
  
March 31, 2014 $5
 $—
 $—
 $5
June 30, 2014 $3
 $—
 $—
 $3
December 31, 2013 4
 —
 —
 4
 4
 —
 —
 4
 At March 31,June 30, 2014 and 2013, there were no adjustments to fair value for ASB’s loans held for sale.
Residential loans.  The fair value of ASB’s residential loans that were written down due to impairment was determined based on third party appraisals, which include the appraisers’ assumptions and judgment, and therefore, is classified as a Level 3 measurement.
Home equity lines of credit. The fair value of ASB’s home equity lines of credit that were written down due to impairment was determined based on third party appraisals, which include the appraisers’ assumptions and judgment, and therefore, is classified as a Level 3 measurement.
Commercial loans.  The fair value of ASB’s commercial loans that were written down due to impairment was determined based on the value placed on the assets of the business, and therefore, is classified as a Level 3 measurement.
For loans classified as Level 3 as of March 31,June 30, 2014, the significant unobservable inputs used in the fair value measurement were as follows:
 
   
Significant unobservable
 input value 1
   
Significant unobservable
 input value 1
($ in thousands) Fair value Valuation technique Significant unobservable input Range 
Weighted
Average
 Fair value Valuation technique Significant unobservable input Range 
Weighted
Average
March 31, 2014   
June 30, 2014   
Residential loans $3,040
 Fair value of property or collateral Appraised value less 7% selling costs 60-96% 86% $2,519
 Fair value of property or collateral Appraised value less 7% selling costs 61-96% 85%
Home equity lines of credit 169
 Fair value of property or collateral Appraised value less 7% selling costs 43-50% 49%
Commercial loans 217
 Fair value of property or collateral Fair value of business assets 19% 336
 Fair value of property or collateral Fair value of business assets 19-49% 25%
Commercial loans 1,632
 Discounted cash flow Present value of expected future cash flows 57%
   Discount rate 4.5%
Total loans $5,058
        $2,855
       
December 31, 2013      
Residential loans $2,361
 Fair value of property or collateral Appraised value less 7% selling costs 44-96% 87% $2,361
 Fair value of property or collateral Appraised value less 7% selling costs 44-96% 87%
Home equity lines of credit 170
 Fair value of property or collateral Appraised value less 7% selling costs 45-50% 50% 170
 Fair value of property or collateral Appraised value less 7% selling costs 45-50% 50%
Commercial loans 217
 Fair value of property or collateral Fair value of business assets 19% 217
 Fair value of property or collateral Fair value of business assets 19%
Commercial loans 1,668
 Discounted cash flow Present value of expected future cash flows 58% 1,668
 Discounted cash flow Present value of expected future cash flows 58%
   Discount rate 4.5%   Discount rate 4.5%
Total loans $4,416
        $4,416
       
 1 Represent percent of outstanding principal balance.

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


4753


9 · Cash flows
Three months ended March 31 2014 2013
Six months ended June 30 2014 2013
(in millions)        
Supplemental disclosures of cash flow information  
  
  
  
HEI consolidated        
Interest paid to non-affiliates $20
 $21
 $44
 $43
Income taxes paid/(refunded) (18) (3)
Income taxes paid 22
 5
Income taxes refunded 24
 4
Hawaiian Electric consolidated        
Interest paid 13
 14
 31
 30
Income taxes paid/(refunded) (8) (26)
Income taxes paid 6
 6
Income taxes refunded 8
 32
Supplemental disclosures of noncash activities  
  
  
  
HEI consolidated        
Common stock dividends reinvested in HEI common stock 1
 —
 6
 —
 12
Increases in common stock related to director and officer compensatory plans 1
 —
 2
 1
Real estate acquired in settlement of loans 1
 1
 2
 3
Loans transferred from held-for-investment to held-for-sale —
 25
Obligations to fund low income housing investments 10
 —
 8
 —
HEI consolidated and Hawaiian Electric consolidated        
Additions to electric utility property, plant and equipment - unpaid invoices and other 9
 3
 28
 5

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. As of March 6, 2014, HEI began satisfying the share purchase requirements of the DRIP through open market purchases of its common stock rather than through new issuances.

10 · Recent accounting pronouncements
Obligations resulting from joint and several liability.  In February 2013, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2013-04, “Liabilities (Topic 405): Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation Is Fixed at the Reporting Date,” which provides guidance for the recognition, measurement and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. The guidance requires entities to measure these obligations as the sum of the amount the entity has agreed with co-obligors to pay and any additional amount it expects to pay on behalf of its co-obligors. The guidance also requires an entity to disclose the nature and amount of the obligation as well as other information.
The Company and the Utilities retrospectively adopted ASU No. 2013-04 in the first quarter of 2014 and it did not have a material impact on the Company’s or the Utilities' results of operations, financial condition or liquidity.
Unrecognized tax benefits (UTBs).  In July 2013, the FASB issued ASU No. 2013-11, “Income Taxes (Topic 740): Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists,” which requires the netting of UTBs against a deferred tax asset for a loss or other carryforward that would apply in settlement of the uncertain tax positions. UTBs should be netted against all available same-jurisdiction loss or other tax carryforwards that would be utilized, rather than only against carryforwards that are created by the UTBs.
The Company and the Utilities prospectively adopted ASU No. 2013-11 in the first quarter of 2014 and it did not have a material impact on the Company’s or the Utilities' results of operations, financial condition or liquidity.
Investments in Qualified Affordable Housing Projects. In January 2014, the FASB issued ASU No. 2014-01, Investments-Equity Method and Joint Ventures (Topic 323): Accounting for Investments in Qualified Affordable Housing Projects,” which permits entities to make an accounting policy election to account for their investments in qualified affordable housing projects using the proportional amortization method if certain conditions are met. The amendments also require additional disclosures.
The Company has not determined whether it will retrospectively adopt ASU No. 2014-01 in 2014 or the first quarter of 2015, as early adoption is permitted. The Companypermitted, nor has notit determined the impact of adoption on its results of operations, financial condition or liquidity.

54


Reclassification of loans upon foreclosure. In January 2014, the FASB issued ASU No. 2014-04, "Receivables-Troubled Debt Restructurings by Creditors (Subtopic 310-40): Reclassification of Residential Real Estate Collateralized Consumer

48


Mortgage Loans upon Foreclosure,” which clarifies when an in substance repossession or foreclosure occurs, and a creditor is considered to have received physical possession of residential real estate property collateralizing a consumer loan. A creditor is considered to have received physical possession of residential real estate property collateralizing a consumer loan upon either: (1) the creditor obtaining legal title to the residential real estate property upon completion of a foreclosure; or (2) the borrower conveying all interest in the residential real estate property to the creditor to satisfy that loan through a deed in lieu of foreclosure or through a similar legal agreement. The amendment also requires additional disclosures.
The Company plans to prospectively adopt ASU No. 2014-04 in the first quarter of 2015 and does not believe that such adoption will have a material impact on the Company’s results of operations, financial condition or liquidity.
Revenues from contracts.  In May 2014, the FASB issued 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 apply the following steps:  (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.
        The Company will adopt ASU No. 2014-09 in the first quarter of 2017, but has not determined the method of adoption (full or modified retrospective application) nor the impact of adoption on its results of operations, financial condition or liquidity.
Repurchase agreements. In June 2014, the FASB issued ASU No. 2014-11, “Transfers and Servicing (Topic 860): Repurchase-to-Maturity Transactions, Repurchase Financings, and Disclosure,” which changes the accounting for repurchase-to-maturity transactions and repurchase financing arrangements. It also requires additional disclosures about repurchase agreements and other similar transactions. The ASU requires a new disclosure for transactions economically similar to repurchase agreements in which the transferor retains substantially all of the exposure to the economic return on the transferred financial assets throughout the term of the transaction. The ASU also requires expanded disclosures about the nature of collateral pledged in repurchase agreements and similar transactions accounted for as secured borrowings.
The Company will adopt ASU No. 2014-11 in the first quarter of 2015 and does not believe that such adoption will have a material impact on its results of operations, financial condition or liquidity.
11 · Credit agreements and long-term debt
Credit agreements.
HEI. On April 2, 2014, HEI and a syndicate of nine financial institutions entered into an amended and restated revolving non-collateralized credit agreement (HEI Facility). The HEI Facility increased HEI’s line of credit to $150 million from $125 million, extended the term of the facility to April 2, 2019, and provided improved pricing compared to HEI’s originalprior facility. Under the HEI Facility, draws would generally bear interest, based on HEI’s current long-term credit ratings, at the “Adjusted LIBO Rate,” as defined in the agreement, plus 137.5 basis points and annual fees on undrawn commitments of 20 basis points. The HEI Facility contains updated provisions for pricing adjustments in the event of a long-term ratings change based on the HEI Facility’s ratings-based pricing grid. Certain modifications were made to incorporate some updated terms and conditions customary for facilities of this type. In addition, the HEI Consolidated Net Worth covenant, as defined in the original facility, was removed from the HEI Facility, leaving only one financial covenant (relating to HEI’s ratio of funded debt to total capitalization, each on a non-consolidated basis). Under the credit agreement, it is an event of default if HEI fails to maintain an unconsolidated “Capitalization Ratio” (funded debt) of 50% or less (actual ratio of 18% as of March 31,June 30, 2014, as calculated under the agreement) or if HEI no longer owns Hawaiian Electric. The HEI Facility does not contain clauses that would affect access to the facility by reason of a ratings downgrade, nor does it have broad “material adverse change” clauses, but it continues to contain customary conditions which must be met in order to draw on it, including compliance with covenants (such as covenants preventing HEI’s subsidiaries from entering into agreements that restrict the ability of the subsidiaries to pay dividends to, or to repay borrowings from, HEI).
The facility will be maintained to support the issuance of commercial paper, but also may be drawn to repay HEI’s short-term and long-term indebtedness, to make investments in or loans to subsidiaries and for HEI’s working capital and general corporate purposes.
Hawaiian Electric. On April 2, 2014, Hawaiian Electric and a syndicate of nine financial institutions entered into an amended and restated revolving non-collateralized credit agreement (Hawaiian Electric Facility). The Hawaiian Electric

55


Facility increased Hawaiian Electric’s line of credit to $200 million from $175$175 million,, provided for a term of the facility to April 1, 2015 (but which term is to be extended to up to April 2, 2019 upon approval by the PUC during the initial term)term, which approval is currently being requested), and provided improved pricing compared to Hawaiian Electric’s originalprior facility. Under the Hawaiian Electric Facility, draws would generally bear interest, based on Hawaiian Electric’s current long-term credit ratings, at the “Adjusted LIBO Rate,” as defined in the agreement, plus 125 basis points and annual fees on undrawn commitments of 17.5 basis points. The Hawaiian Electric Facility contains updated provisions for pricing adjustments in the event of a long-term ratings change based on the Hawaiian Electric Facility’s ratings-based pricing grid. Certain modifications were made to incorporate some updated terms and conditions customary for facilities of this type. The Hawaiian Electric Facility does not contain clauses that would affect access to the facility by reason of a ratings downgrade, nor does it have broad “material adverse change” clauses, but it continues to contain customary conditions which must be met in order to draw on it, including compliance with several covenants (such as covenants preventing its subsidiaries from entering into agreements that restrict the ability of the subsidiaries to pay dividends to, or to repay borrowings from, Hawaiian Electric, and restricting its ability as well as the ability of any of its subsidiaries to guarantee additional indebtedness of the subsidiaries if such additional debt would cause the subsidiary’s “Consolidated Subsidiary Funded Debt to Capitalization Ratio” to exceed 65% (ratio of 42% for Hawaii Electric Light and 45% for Maui Electric as of March 31,June 30, 2014, as calculated under the agreement)). In addition to customary defaults, Hawaiian Electric’s failure to maintain its financial ratios, as defined in its credit agreement, or meet other requirements may result in an event of default. For example, under the credit agreement, it is an event of default if Hawaiian Electric fails to maintain a “Consolidated Capitalization Ratio” (equity) of at least 35% (ratio of 56%54% as of March 31,June 30, 2014, as calculated under the credit agreement), or if Hawaiian Electric is no longer owned by HEI.
The credit facility will be maintained to support the issuance of commercial paper, but also may be drawn to repay Hawaiian Electric’s short-term indebtedness, to make loans to subsidiaries and for Hawaiian Electric’s capital expenditures, working capital and general corporate purposes.

49


Changes in long-term debt.
May 2014 loan.  On May 2, 2014, HEI entered into a loan agreement with The Bank of Tokyo-Mitsubishi UFJ, Ltd., Royal Bank of Canada and U.S. Bank, National Association, which agreement includes the same financial covenant and customary conditions as the HEI credit agreement described above. On May 2, 2014, HEI drew a $125 million Eurodollar term loan for a term of two years and at an initial interest rate of 1.12% for an initial three month interest period. The proceeds from the term loan were used to pay-off $100 million of 6.51% medium term notes at maturity on May 5, 2014, pay down maturing commercial paper and for general corporate purposes.
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 2013 Form 10-K and should be read in conjunction with such discussion and the 2013 annual consolidated financial statements of HEI and Hawaiian Electric and notes thereto included in HEI’s and Hawaiian Electric’s 2013 Form 10-K, as well as the quarterly (as of and for the three and six months ended March 31,June 30, 2014) financial statements and notes thereto included in this Form 10-Q.
HEI consolidated
RESULTS OF OPERATIONS
(in thousands, except per Three months  
 ended March 31		 %  Three months ended June 30 % 
share amounts) 2014 2013 change Primary reason(s)* 2014 2013 change Primary reason(s)*
Revenues $783,749
 $782,232
 — Increase for the electric utility segment, partly offset by decrease for the bank segment $798,657
 $794,567
 1 Increase for the electric utility segment, partly offset by decrease for the bank segment
Operating income 88,306
 68,825
 28 Increase for the electric utility segment 82,275
 80,207
 3 Increase for the electric utility segment, partly offset by decrease for the bank segment and higher losses at corporate
Net income for common stock 45,927
 33,679
 36 Higher operating income and allowance for equity funds used during construction, partly offset by higher “interest expense, net—other than on deposit liabilities and other bank borrowings” 41,421
 40,588
 2 Higher operating income for the electric utility segment, partly offset by higher “interest expense, net—other than on deposit liabilities and other bank borrowings”
Basic earnings per common share $0.45
 $0.34
 32 Higher net income, partly offset by the impact of higher weighted average shares outstanding $0.41
 $0.41
 — Higher net income, offset by the impact of higher weighted average shares outstanding
Weighted-average number of common shares outstanding 101,382
 98,135
 3 Issuances of shares under the HEI Dividend Reinvestment and Stock Purchase Plan and other plans 101,495
 98,660
 3 Issuances of shares under the HEI Dividend Reinvestment and Stock Purchase Plan and other plans
 


56


(in thousands, except per Six months ended June 30 %  
share amounts) 2014 2013 change Primary reason(s)*
Revenues $1,582,406
 $1,576,799
 — Increase for the electric utility segment, partly offset by decrease for the bank segment
Operating income 170,581
 149,032
 14 Increase for the electric utility segment, partly offset by decrease for the bank segment and higher losses at corporate
Net income for common stock 87,348
 74,267
 18 Higher operating income for the electric utility segment, partly offset by higher “interest expense, net—other than on deposit liabilities and other bank borrowings”
Basic earnings per common share $0.86
 $0.75
 15 Higher net income, partly offset by the impact of higher weighted average shares outstanding
Weighted-average number of common shares outstanding 101,439
 98,399
 3 Issuances of shares under the HEI Dividend Reinvestment and Stock Purchase Plan and other plans
*                Also, see segment discussions which follow.
 
Notes:  The Company’s effective tax rates (combined federal and state) for the second quarters of 2014 and 2013 were 35% and 36%, respectively, and for each of the first threesix months of 2014 and 2013 were 35% and 34%, respectively..
HEI’s consolidated ROACE was 10.4%10.3% for the twelve months ended March 31,June 30, 2014 and 8.5% for the twelve months ended March 31,June 30, 2013.
Dividends.  The payout ratios for the first threesix months of 2014 and full year 2013 were 68%72% and 76%, respectively. HEI currently expects to maintain the 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; Blue Chip Economic Indicators; U.S. Energy Information Administration; Hawaii Tourism Authority (HTA); Honolulu Board of REALTORS®; Bureau of Economic Analysis and national and local newspapers).
Following a record-setting year in 2013, Hawaii’s tourism industry, a significant driver of Hawaii’s economy, experienced a decline inended the first quarterhalf of 2014 with higher visitor expenditures and relatively flat arrivals as compared to the same period last year.a year ago. Visitor expenditures increased 2.5% while arrivals and expenditures decreased 3.2% and 3.1%, respectively,0.1% in the first quartersix months of 2014 compared to the first quartersix months of 2013. Despite the slow start to the year, the

50


outlook for the visitor industry remains positive. The Hawaii Tourism Authority expects scheduled nonstop seats to Hawaii for the secondthird quarter of 2014 to increase by 3.1%4.4% over the secondthird quarter of 2013, driven by continued increases in international flights.air seats from North America, specifically Los Angeles and Seattle.
Hawaii’s unemployment rate was relatively stable at 4.5%4.4% in MarchJune 2014, lower than the state’s 4.8%4.7% rate in MarchJune 2013 and the MarchJune 2014 national unemployment rate of 6.7%6.1%.
Hawaii real estate activity, as indicated by the home resale market, wasexperienced strong growth in median sales prices in the first quarterhalf of 2014 as the median2014. Median sales priceprices for single family residential homes and condominiums on Oahu increased 9.2% and7.1% over the numberfirst half of 2013. However, closed sales increased 1.9%were relatively flat in the first half of 2014. Closed sales for single family residential homes were down 0.2% and condominiums were down 0.1% over the same period in 2013. Oahu condominiums also maintained strong momentum as the median sales price rose 1.5% and closed sales increased 1.7% in the first quarter of 2014 over the first quarter of 2013.
Hawaii’s petroleum product prices reflect supply and demand in the Asia-Pacific region and the price of crude oil in international markets. The dramatic reduction in Japan’s nuclear production following the tragic earthquake and tsunami in March 2011 increased regional demand for energy supplies, including petroleum, and the prices of the Utilities’ fuels have accordingly remained at the elevated 2011 level through the firstsecond quarter of 2014.
At its March 19,June 17-18, 2014 meeting, the Federal Open Market Committee (FOMC) noted that there is sufficient underlying strength in the broader economy to support ongoing improvement in labor market conditions. In light of this progress, the FOMC decided to make a further measured reduction in the pace of purchases of Treasury and agency mortgage-backed securities beyond the steps taken after its meeting in JanuaryApril 2014. The FOMC indicated that if economic data continues to support the outlook of ongoing improvement, the pace of asset purchases would likely be further reduced, however, asset

57


purchases are not on a preset course and are still contingent on FOMC evaluation. The FOMC maintained a highly accommodative stance regarding monetary policy. The federal funds rate target was held at 0% to 0.25% and is expected to remain at record low rates for a considerable time after the asset purchase program ends.
Overall, Hawaii’s economy is expected to see moderate growth continuing growth in 2014 and 2015. Local economic growth is expected to be supported2015 driven largely by the turn around in the public sector and the ongoing expansion in the construction industry. Softening economic prospects in the U.S., continued uncertainty in global economies, slowing growth in China and the looming consumptionThe visitor industry continues to fare well, but is not expected to contribute significantly to overall growth. Consumption tax increases slated forin Japan, uncertainty surrounding the effects of the Fed’s monetary policy and political instability in Eastern Europe pose possible risks to local economic growth.
Recent tax developments. The American Taxpayer Relief Act of 2012 provided a one year extension of 50% bonus depreciation through 2013, which increased federal tax depreciation for 2013 by an estimated $131 million, primarily attributable to the Utilities. Congress has not extended bonus depreciation for 2014 plant additions. Thus,additions, but both Houses have proposed bills which would extend bonus depreciation into the future. No action on these bills is expected until after the November election. Without an extension of bonus depreciation, income tax cash payments are expected to increase in 2014 compared to 2013.
Also, see Note 3 of the Consolidated Financial Statements.
Health care reform.  On June 28, 2012, the US Supreme Court upheld the Patient Protection and Affordable Care Act, the 2010 health care reform law. Currently, Hawaii’s Prepaid Health Care Act generally provides greater benefits to employees and dependents because of cost sharing limitations. The Company will continue to comply with its obligations under these laws and to monitor the interaction of the state and federal laws.
Retirement benefits.  For the first threesix months of 2014, the Company’s defined benefit pension and other postretirement benefit plans’ assets generated a gain, afternet of investment management fees, of 1.5%5.7%. The market value of these assets as of MarchJune 30, 2014 and December 31, 20142013 was $1.4 billion (including $1.3 billion for the Utilities) compared toand $1.4 billion at December 31, 2013 (including $1.2 billion for the Utilities)., respectively.
The Company estimates that the cash funding for its defined benefit pension and other postretirement benefit plans in 2014 will be $59$60 million ($5859 million by the Utilities, $1 million by HEI and nil by ASB), which is expected to fully satisfy the minimum contribution requirements, including requirements of the Utilities’ pension and other postretirement benefits tracking mechanisms and the plans’ funding policies.
During the first quarter of 2014, the Society of Actuaries issued an exposure draft with a proposed revised mortality table for use by actuaries, insurance companies, governments, benefit plan sponsors and others in setting assumptions regarding life expectancy in the United States for purposes of estimating pension and OPEB obligations, costs and required contribution amounts. The newly proposed mortality tables indicate substantial life expectancy improvements since the last study published in 2000 (RP 2000). Adoption of the new mortality table would result in significantly increased future pension and OPEB plan obligations, costs and required contribution amounts across all plan sponsors. The Company is currently evaluating the exposure draft and potential impacts to the December 31, 2014 valuation and future expected pension and OPEB plan obligations, cost and contributions. The IRS has indicated the RP 2000 table with mortality improvements projected seven years beyond the valuation date for annuitants and fifteen years beyond the valuation date for non-annuitants should be used for

51


Employee Retirement Income Security Act of 1974, as amended (ERISA) funding calculations impacting qualified pension plans in 2014 and 2015 by sponsors electing the static mortality option, meaning the earliest a new table is expected to be required for determining minimum ERISA funding requirements is January 1, 2016.
Commitments and contingencies.  See Note 3, "Electric utility segment" and Note 4, “Bank segment,” of the Consolidated Financial Statements.
Recent accounting pronouncements.  See Note 10, “Recent accounting pronouncements,” of the Consolidated Financial Statements.

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“Other” segment.
 Three months  
 ended March 31		  Three months  
 ended June 30		 Six months  
 ended June 30		 
(in thousands) 2014 2013 Primary reason(s) 2014 2013 2014 2013 Primary reason(s)
Revenues $68
 $35
  $(388) $15
 $(320) $50
 Writedown of venture capital investments
Operating loss (3,983) (4,047) Lower administrative and general expenses due in part to lower retirement benefits expense (4,841) (3,473) (8,824) (7,520) Writedown of venture capital investments and higher administrative and general expenses due to higher salaries, executive compensation and legal expenses, partly offset by lower retirement benefits expense
Net loss (4,032) (4,905) Lower operating loss and interest expense and higher income tax benefits (4,485) (4,024) (8,517) (8,929) Higher operating loss, partly offset by lower interest expense
The “other” business segment includes results of the stand-alone corporate operations of HEI and American Savings Holdings, Inc. (ASHI), both holding companies; HEI Properties, Inc., a company holding passive, venture capital investments; and The Old Oahu Tug Service, Inc., a maritime freight transportation company that ceased operations in 1999; as well as eliminations of intercompany transactions.

FINANCIAL CONDITION
Liquidity 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 requirements for the foreseeable future.
The consolidated capital structure of HEI (excluding deposit liabilities and other bank borrowings) was as follows:
(dollars in millions) March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
Short-term borrowings—other than bank $136
 4% $105
 3% $185
 5% $105
 3%
Long-term debt, net—other than bank 1,493
 44
 1,493
 45
 1,518
 44
 1,493
 45
Preferred stock of subsidiaries 34
 1
 34
 1
 34
 1
 34
 1
Common stock equity 1,746
 51
 1,727
 51
 1,761
 50
 1,727
 51
 $3,409
 100% $3,359
 100% $3,498
 100% $3,359
 100%
HEI’s short-term borrowings and HEI’s line of credit facility were as follows:
 Three months ended March 31, 2014 Balance Six months ended June 30, 2014 Balance
(in millions)  Average balance March 31, 2014 December 31, 2013 Average balance June 30, 2014 December 31, 2013
Short-term borrowings 1
  
  
  
  
  
  
Commercial paper $91
 $101
 $105
 $83
 $82
 $105
Line of credit draws —
 —
 —
 —
 —
 —
Undrawn capacity under HEI’s line of credit facility (expiring December 5, 2016) 2
   125
 125
   150
 125
 
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 during the first threesix months of 2014 was $106$102 million. At April 30,July 31, 2014, HEI had $96$60 million in outstanding commercial paper and its line of credit facility was undrawn.
2  
On April 2, 2014, HEI entered into an amended and restated revolving unsecured credit agreement, which increased HEI’s line of credit to $150 million from $125 million and extended the term. See Note 11 of the Consolidated Financial Statements.

52


HEI has a line of credit facility, as amended and restated on April 2, 2014, of $150 million. See Note 11 of the Consolidated Financial Statements.
The Company raised $3 million through the issuance of approximately 0.1 million shares of common stock under the DRIP, the HEIRSP and ASB 401(k) Plan from January 1 through March 5, 2014. As of March 6, 2014, HEI began satisfying the share purchase requirements of the DRIP, HEIRSP and ASB 401(k) Plan through open market purchases of its common stock rather than through new issuances.
In March 2013, HEI entered into equity forward transactions in which a forward counterparty borrowed 7 million shares of

59


HEI’s common stock from third parties and such borrowed shares were sold pursuant to an HEI registered public offering. See Note 7 of the Consolidated Financial Statements. In July 2014, HEI issued 1 million shares under the equity forward for proceeds of $23.9 million.
On May 2, 2014, HEI closed a two-year term loan from three banks for $125 million. See Note 11 of the Consolidated Financial Statements for a brief description of the loan agreement and the application of the proceeds of the loan.
In March 2013, HEI entered into equity forward transactions in which a forward counterparty borrowed 7 million shares of HEI’s common stock from third parties and such borrowed shares were sold pursuant to an HEI registered public offering. See Note 11 of the Consolidated Financial Statements. In the fourth quarter of 2014, HEI intends to issue a portion of the 5.7 million shares remaining under the equity forward transactions to raise net proceeds of approximately $30 million to $40 million to help fund its investments in Hawaiian Electric.
On March 6, 2013, HEI issued $50 million of 3.99% Senior Notes due March 6, 2023 via a private placement. HEI used the net proceeds from the issuance of the Senior Notes to refinance $50 million of its 5.25% medium-term notes that matured on March 7, 2013. The Senior Notes contain customary representation and warranties, affirmative and negative covenants, and events of default (the occurrence of which may result in some or all of the notes then outstanding becoming immediately due and payable) and provisions requiring the maintenance by HEI of certain financial ratios generally consistent with those in HEI’s line of credit facility.
For the first threesix months of 2014, net cash provided by operating activities of HEI consolidated was $1946 million. Net cash used by investing activities for the same period was $74$272 million, due to Hawaiian Electric’s consolidated capital expenditures, a net increase in ASB’s loans held for investment and purchases of investment and mortgage-related securities, partly offset by ASB's proceeds from sales of investment securities, and repayments of investment and mortgage-related securities and redemption of stock from the Federal Home Loan Bank of Seattle, and Hawaiian Electric’s contributions in aid of construction. Net cash provided by financing activities during this period was $104194 million as a result of several factors, including net increases in deposit liabilities and short-term borrowings and proceeds from the issuance of common stock under HEI plans,long-term debt (net of repayments), partly offset by the payment of common stock dividends. Other than capital contributions from their parent company, intercompany services (and related intercompany payables and receivables), Hawaiian Electric’s periodic short-term borrowings from HEI (and related interest) and the payment of dividends to HEI, the electric utility 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 threesix months of 2014, Hawaiian Electric and ASB (through ASHI) paid cash dividends to HEI of $23$44 million and $9$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 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 45, 59 to 61, and 71 to 73 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2013 Form 10-K.
Additional factors that may affect future results and financial condition are described on pages iv and v under “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 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 46, 61 to 62, and 73 to 74 of HEI’s MD&A included in Part II, Item 7 of HEI’s 2013 Form 10-K.

5360


Following are discussions of the results of operations, liquidity and capital resources of the electric utility and bank segments.
Electric utility
RESULTS OF OPERATIONS
Utility strategic progress. The Utilities continue to make significant progress in implementing their renewable energy strategies to support Hawaii’s efforts to reduce its dependence on oil. The PUC issued several important regulatory decisions during the the last few years, including a number of interim and final rate case decisions (see table in “Most recent rate proceedings” below).
Transition to renewable energy. The Utilities are committed to achieving or exceeding the State’s Renewable Portfolio Standard goal of 40% renewable energy by 2030 (see “Renewable energy strategy” below). In addition, while it will not take precedence over the Utilities’ work to increase their use of renewable energy, the Utilities are also working with the State of Hawaii and other entities to examine the possibility of using liquefied natural gas (LNG) as a cleaner and lower cost fuel to replace, at least in part, the petroleum oil that would otherwise be used for the remaining generation. In December 2013, the Utilities executed a non-binding memorandum of understanding with The Gas Company, LLC d/b/a HawaiiGAS, documenting the parties’ desire to work together to (a) develop and/or secure infrastructure for large scale importation of LNG into Hawaii and (b) establish a consortium to competitively procure the LNG and provide storage and regasification of it at an LNG terminal site. In March 2014, Hawaiian Electric issued a request for proposals (RFP) for the supply of LNG to Hawaii using International Standards Organization containers. Finalcontainerized LNG. Hawaiian Electric received 3 final bid submissions are expected in May 2014.2014 and is currently evaluating them in detail. Also, see "Subsequent event" in Note 3 of the Consolidated Financial Statements for a description of Hawaiian Electric's agreement with Fortis BC Energy Inc.
RegulatoryDuring the second quarter of 2014, Hawaiian Electric began replacement of approximately 5,200 residential and commercial meters with smart meters in selected areas across Oahu as part of the initial phase of its smart grid project. The initial phase is expected to run through the end of 2014 and.also includes the installation of fault circuit indicators and remote switching, as well as the integration of customer energy portals. In January 2013,June 2014, the residential customer energy portal was launched and available for customer use.  The smart grid should help customers manage their electric bills by providing them with more information about their energy use. Additionally, a fully developed smart grid will provide the Utilities the flexibility and Consumer Advocate signed a settlement agreement (2013 Agreement), whichability to respond to changes in power flow from intermittent sources, like solar and wind, thus allowing for the integration of more low-cost renewable energy. Hawaiian Electric is planning to seek approval from the PUC approved with clarifications in March 2013 (2013 D&O). See the discussion under “Most recent rate proceedings” below.first quarter of 2015 to commit funds for an expansion of the smart grid project, including at Hawaii Electric Light and Maui Electric.
Decoupling. In 2010, the PUC issued an order approving decoupling, which was implemented by the Utilities in 2011 orand 2012. The decoupling model implemented delinks revenues from sales and includes annual revenue adjustments for certain O&M expenses and rate base changes.
Under decoupling, the most significant drivers for improving earnings are:
•completing major capital projects within PUC approved amounts and on schedule;
•managing O&M expense relative to authorized O&M adjustments; and
•regulatory outcomes that cover O&M requirements and rate base items not included in the RAMs.
On May 31, 2013, as provided for in its original order issued in 2010 approving decoupling, the PUC opened an investigative docket to review whether the decoupling mechanisms are functioning as intended, are fair to the Utilities and their ratepayers, and are in the public interest. On February 7, 2014, in the first part of this bifurcated proceeding, the PUC issued a D&O on select issues, which made certain modifications to the decoupling mechanism. Among other things, the D&O requires:
An adjustment to the Rate Base RAM Adjustment to include 90% of the amount of the current RAM Period Rate Base RAM Adjustment that exceeds the Rate Base RAM Adjustment from the prior year, to be effective with the Utilities' 2014 decoupling filing.
Effective March 1, 2014, the interest rate to be applied on the outstanding RBA balances to be the short term debt rate used in each Utilities last rate case (ranging from 1.25% to 3.25%), instead of the 6% that has been previously approved.
The second part of this proceeding will continue this year with panel hearings scheduled for AugustOctober 2014. See "Decoupling" in Note 3 of the Consolidated Financial Statements.

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Actual and PUC-allowed (as of March 31,June 30, 2014) returns were as follows:
% Return on rate base (RORB)* ROACE** Rate-making ROACE*** Return on rate base (RORB)* ROACE** Rate-making ROACE***
Twelve months ended March 31, 2014 Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric
Twelve months ended June 30, 2014 Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric
Utility returns 7.86
 7.01
 6.75
 9.21
 7.64
 7.68
 9.95
 7.92
 8.20
 8.16
 7.08
 7.01
 9.56
 7.58
 8.16
 10.47
 8.07
 8.55
PUC-allowed returns 8.11
 8.31
 7.34
 10.00
 10.00
 9.00
 10.00
 10.00
 9.00
 8.11
 8.31
 7.34
 10.00
 10.00
 9.00
 10.00
 10.00
 9.00
Difference (0.25) (1.30) (0.59) (0.79) (2.36) (1.32) (0.05) (2.08) (0.80) 0.05
 (1.23) (0.33) (0.44) (2.42) (0.84) 0.47
 (1.93) (0.45)
*       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 executive bonuses and advertising.

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The approval of decoupling by the PUC has helped the Utilities to gradually improve their ROACEs, which in turn will facilitate the Utilities’ ability to effectively raise capital for needed infrastructure investments. However, the Utilities continue to expect an ongoing structural gap between their PUC-allowed ROACEs and the ROACEs actually achieved due to the following:
•the timing of general rate case decisions,
the effective date of June 1 (rather than January 1) for the RAMs for Hawaii Electric Light and Maui Electric currently, and for Hawaiian Electric beginning in 2017,
•the 5-year historical average for baseline plant additions,
the modifications to the rate base RAM and RBA interest rate per the PUC's February 2014 decision on decoupling (as discussed in Note 3 of the Consolidated Financial Statements), and
•the PUC’s consistent exclusion of certain expenses from rates.
The structural gap in 2014 to 2016 is expected to be 100 to 130 basis points. Factors which impact the range of the structural gap include the actual sales impacting the size of the RBA regulatory asset, the actual level of baseline additions in any given year relative to the 5-year historical average, and the timing, nature, and size of any general rate case. Between rate cases, items not covered by the annual RAMs could also have a negative impact on the actual ROACEs achieved by the Utilities (primarily investments in software projects, changes in fuel inventory and O&M in excess of indexed escalations). The specific magnitude of the impact will depend on various factors, including the size of software projects, changes in fuel prices and management’s ability to manage costs within the current mechanisms.
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. EarningsAt 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. For 2013, Maui Electric’s rate-making ROACE was 9.35%, which was above the PUC allowed 9% ROACE and triggered the earnings sharing mechanism. As a result, Maui Electric will credit its customers $0.4 million for their portion of the earnings sharing. Maui Electric’s 2013 ratemaking ROACE of 9.35% included adjustments to Maui Electric’s actual ROACE of 8.91% such as the exclusion of expenses not considered in establishing electric rates (e.g., executive bonuses). For 2013, Hawaiian Electric’s rate-making ROACE was 8.95% and Hawaii Electric Light’s rate-making ROACE was 7.46%, which did not trigger the earnings sharing mechanism.
Annual decoupling filings.filings. On March 31,May 30, 2014, Hawaiian Electric, Hawaii Electric Light and Maui Electric submitted theirthe PUC approved the revised annual decoupling filings for tariffed rates for each respective utilitythe Utilities that will be effective from June 1, 2014 through May 31, 2015 unless the filings are modified or suspended by the PUC.2015. The tariffed rates include: (1) RAM adjusted revenues (the components of the annual incremental changes are shown below) with the 2014 rate base RAM return on investment calculated as the PUC ordered in its recent investigative docket on the decoupling mechanism, (2) accrued earnings sharing credits to be refunded, and (3) the amount of the accrued RBA balance as of December 31, 2013 (and associated

62


revenue taxes) to be collected:
(in millions) Hawaiian Electric Hawaii Electric Light Maui Electric Hawaiian Electric Hawaii Electric Light Maui Electric
Annual incremental RAM adjusted revenues            
O&M $4.0
 $0.9
 $1.0
 $4.0
 $0.9
 $1.0
Invested capital 27.4
 3.9
 4.5
 26.8
 3.9
 4.4
Total annual incremental RAM adjusted revenues $31.4
 $4.8
 $5.5
 $30.8
 $4.8
 $5.4
Accrued earnings sharing credits to be refunded $—
 $—
 $(0.4) $—
 $—
 $(0.4)
Accrued RBA balance as of December 31, 2013 (and associated revenue taxes) to be collected $72.6
 $8.2
 $9.6
 $72.6
 $8.2
 $9.6
On May 31, 2013, the PUC approved the revised 2013 decoupling filings for tariffed rates for the Utilities that will be effective from June 1, 2013 through May 31, 2014. The amounts approved as noted below reflect the Utilities’ agreements withResults.
Three months ended June 30 Increase  
2014 2013 (decrease) (dollars in millions, except per barrel amounts)
$738
 $729
 $9
  
Revenues. Increase largely due to:
     $16
 higher decoupling revenues, including the rate base (RB) and O&M RAM acceleration for Hawaiian Electric
     7
 Maui Electric refund in 2013 due to final rate case decision
     (15) lower fuel costs
270
 289
 (19)  
Fuel oil expense. Decrease largely due to lower KWHs generated, resulting from higher purchased power and lower sales, partially offset by lower fuel efficiency performance of generators on Oahu and higher fuel handling costs
188
 178
 10
  
Purchased power expense. Increase due to higher KWHs purchased and higher purchased power energy costs
98
 94
 4
  
Operation and maintenance expenses. Increase due to:
     3
 costs related to installation of Smart Grid technologies
     2
 Maui Electric test year 2012 final D&O adjustments for deferral of pension/OPEB and IRP expenses in 2013
     (2) lower production costs due to deactivation of HPP
111
 107
 4
  
Other expenses. Increase primarily due to depreciation expense for plant investments
70
 59
 11
  
Operating income.  Increase due to higher revenues and decrease in overall expenses
34
 29
 5
  
Net income for common stock. Increase due to higher operating income
        
2,189
 2,247
 (58)  Kilowatthour sales (millions)
69.1
 69.3
 (0.2)  Wet-bulb temperature (Oahu average; degrees Fahrenheit)
1,244
 1,114
 130
  Cooling degree days (Oahu)
$132.07
 $129.94
 $2.13
  Average fuel oil cost per barrel


5563


the position of the Consumer Advocate. The approved tariffed rates include:
(in millions) Hawaiian Electric Hawaii Electric Light Maui Electric
Annual incremental RAM adjusted revenues      
O&M $3.9
 $0.9
 $1.0
Invested capital 27.5
 1.2
 2.4
Total annual incremental RAM adjusted revenues $31.4
 $2.1
 $3.4
Accrued earnings sharing credits to be refunded $(2.6) $—
 $—
Accrued RBA balance as of December 31, 2012 (and associated revenue taxes) to be collected $55.4
 $4.9
 $5.8
Six months  
 ended June 30		 Increase  
2014 2013 (decrease) (dollars in millions, except per barrel amounts)
$1,458
 $1,446
 $12
  
Revenues. Increase largely due to:
     $33
 higher decoupling revenues, including the RB and O&M RAM acceleration for Hawaiian Electric
     10
 higher purchased power costs
     5
 Maui Electric refund in 2013 due to final 2012 rate case decision
     (37) lower fuel costs
557
 594
 (37)  
Fuel oil expense. Decrease largely due to lower KWHs generated, resulting from higher purchased power
353
 332
 21
  
Purchased power expense. Increase due to higher KWHs purchased and capacity/non-fuel charges as a result of decreased availability of AES in 2013 and expanded capacity of HPower in 2014, partly offset by lower purchase power energy costs
187
 196
 (9)  
Operation and maintenance expenses. Decrease due to:
     (7) lower overhaul costs due to fewer overhauls performed
     (3) lower production costs due to deactivation of HPP
     (2) lower customer service costs that were elevated in 2013 during the stabilization period for the new CIS
     4
 costs related to installation of Smart Grid technologies
221
 213
 8
  
Other expenses. Increase primarily due to depreciation expense for plant investments
141
 110
 31
  
Operating income. Increase due to higher revenues and decrease in overall expenses
70
 53
 17
  
Net income for common stock. Increase due to higher operating income
        
4,315
 4,370
 (55)  Kilowatthour sales (millions)
68.1
 67.6
 0.5
  Wet-bulb temperature (Oahu average; degrees Fahrenheit)
2,072
 1,903
 169
  Cooling degree days (Oahu)
$131.60
 $131.49
 $0.11
  Average fuel oil cost per barrel
453,559
 450,455
 3,104
  Customer accounts (end of period)
Results.
Three months  
 ended March 31		 Increase  
2014 2013 (decrease) (dollars in millions, except per barrel amounts)
$720
 $717
 $3
  
Revenues. Increase largely due to:
     $16
 higher decoupling revenues, including the RB and O&M RAM acceleration for Hawaiian Electric
     10
 higher purchased power costs
     (22) lower fuel costs
     (2) Maui Electric test year 2012 final D&O received on May 31, 2013
286
 305
 (19)  
Fuel oil expense. Decrease largely due to lower KWHs generated, resulting from higher purchased power, partially offset by lower fuel efficiency performance of generators on Oahu
165
 153
 12
  
Purchased power expense. Increase due to higher KWHs purchased and capacity/non-fuel charges as a result of decreased availability of AES in 2013 and expanded capacity of HPower in 2014, offset by lower purchase power energy costs
89
 102
 (13)  
Operation and maintenance expenses. Decrease due to:
     (6) lower costs due to timing of overhauls
     (3) lower production costs due to deactivation of HPP during the quarter and modification of operation due to lower load generation
     (2) lower customer service costs that were elevated in 2013 during the stabilization period for the new CIS
110
 106
 4
  
Other expenses. Increase in depreciation primarily due to plant investments
71
 51
 20
  
Operating income. Increase due to lower expenses
35
 24
 11
  
Net income for common stock. Increase due to higher operating income
        
2,126
 2,123
 3
  Kilowatthour sales (millions)
67.1
 66.0
 1.1
  Wet-bulb temperature (Oahu average; degrees Fahrenheit)
828
 789
 39
  Cooling degree days (Oahu)
$131.15
 $130.83
 $0.32
  Average fuel oil cost per barrel
452,626
 449,512
 3,114
  Customer accounts (end of period)
Note:  The electric utilities had effective tax rates for the firstsecond quarters of 2014 and 2013 of 37% and 35%37%, respectively. The higher rate in 2014 was primarily due to a research and development credit of $0.3 million inelectric utilities had effective tax rates for the first quarter of 2013 (the last year of the credit), no taxes on nontaxable executive life insurance proceeds of $0.3 million in the first quarter of 2013 and higher income in the first quartersix months of 2014 resulting in the state tax credit amortization having a lesser impact in lowering the effective tax rate in the first quarterand 2013 of 2014 compared to 2013.37% and 36%, respectively.

Hawaiian Electric’s consolidated ROACE was 8.79.0% for the twelve months ended March 31,June 30, 2014 and 6.7%6.6% for the twelve months ended March 31,June 30, 2013.

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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' 2014 and 2015 KWH sales are expected to further decline below 2013 levels.
Other operation and maintenance expenses (excluding expenses covered by surcharges or by third parties) for 2014 are projected to be relatively flat as compared to 2013 as the Utilities expect to manage expenses to near 2013 levels.
The net book value (cost less accumulated depreciation) of utility property, plant and equipment (PPE) as of March 31,June 30, 2014 amounted to $3.6$3.7 billion, of which approximately 28% related to production PPE, 62%63% related to transmission and distribution PPE, and 10%9% related to other PPE. Approximately 3% 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.

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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.
The following table summarizes certain details of each utility’s most recent rate cases, including the details of the increases requested, whether the utility and the Consumer Advocate reached a settlement that they proposed to the PUC and the details of any granted interim and final PUC D&O increases.
Test year
(dollars in millions)
 
Date
(applied/
implemented)
 Amount 
% over 
rates in 
effect
 
ROACE
(%)
 
RORB
(%)
 
Rate
 base
 
Common
equity
%
 
Stipulated 
agreement 
reached with
Consumer
Advocate
 
Date
(applied/
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 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
   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
   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
   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
   9/1/12 58.1
 3.4
 10.00
 8.11
 1,386
 56.29
  
2014 (2)
 6/27/14             
Hawaii Electric Light    
  
  
  
  
  
      
  
  
  
  
  
  
2010 (2)
    
  
  
  
  
  
  
2010 (3)
    
  
  
  
  
  
  
Request 12/9/09 $20.9
 6.0
 10.75
 8.73
 $487
 55.91
 Yes 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
   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
   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
   4/9/12 4.5
 1.3
 10.00
 8.31
 465
 55.91
  
2013 (3)
    
  
  
  
  
  
  
2013 (4)
    
  
  
  
  
  
  
Request 8/16/12 $19.8
 4.2
 10.25
 8.30
 $455
 57.05
   8/16/12 $19.8
 4.2
 10.25
 8.30
 $455
 57.05
  
Closed 3/27/13  
  
  
  
  
  
   3/27/13  
  
  
  
  
  
  
Maui Electric    
  
  
  
  
  
      
  
  
  
  
  
  
2012 (4)
    
  
  
  
  
  
  
2012 (5)
    
  
  
  
  
  
  
Request 7/22/11 $27.5
 6.7
 11.00
 8.72
 $393
 56.85
 Yes 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
   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
   8/1/13 5.3
 1.3
 9.00
 7.34
 393
 56.86
  
__________________________________________ 
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.

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(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)   HawaiiSee “Hawaiian 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 heat2014 test year rate deadbands and the PPAC, which provides a surcharge mechanism that case” below.
(3)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

65


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.
(3)(4)   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 the 2013 Agreement and 2013 D&OOrder (described below), the rate case was withdrawn and the docket has been closed.
(4)(5)   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. See discussion on final D&O, including the refund to customers in September and October 2013 required as a result of the final D&O, in Note 3 of the Consolidated Financial Statements.
Hawaiian Electric 2011 test year rate case.  In the Hawaiian Electric 2011 test year rate case, the PUC had granted Hawaiian Electric’s request to defer CIS project O&M expenses (limited to $2,258,000 per year in 2011 and 2012) that were to be subject to a regulatory audit of project costs, and allowed Hawaiian Electric to accrue allowance for funds used during construction (AFUDC)AFUDC on these deferred costs until the completion of the regulatory audit.
On January 28, 2013, the Utilities and the Consumer Advocate entered into the 2013 Agreement to, among other things, write-off $40 million of CIS Project costs in lieu of conducting the regulatory audits of the CIP CT-1 and the CIS projects, with the remaining recoverable costs for the projects of $52 million to be included in rate base as of December 31, 2012. The parties agreed that Hawaii Electric Light would withdraw its 2013 test year rate case and not file a rate case until its next turn in the rate case cycle, for a 2016 test year, and Hawaiian Electric would delay the filing of its scheduled 2014 test year rate case to no earlier than January 2, 2014. The parties also agreed that, starting in 2014, Hawaiian Electric will be allowed to record RAM revenues starting on January 1 of 2014, 2015 and 2016 (which resulted in additional revenues of $7 million of additional revenuesand $5 million for the first quarterand second quarters of 2014)2014, respectively). On March 19, 2013, the PUC issued its 2013 D&OOrder approving the 2013 Agreement, with clarifications.
Hawaiian Electric 2014 test year rate case.  On October 30, 2013 Hawaiian Electric filed with the PUC a Notice of Intent to file an application for a general rate case (on or after January 2, 2014, but before June 30, 2014, using a 2014 test year) and a motion, which was subsequently recommended by the Consumer Advocate, for approval of test period waiver. Hawaiian Electric’s filing of a 2014 rate case would be in accordance with a PUC order which calls for a mandatory triennial rate case cycle. On March 7, 2014, the PUC issued an order granting Hawaiian Electric’s motion to waive the requirement to utilize a split test year, and authorized a 2014 test year.
On June 27, 2014, Hawaiian Electric submitted an abbreviated rate case filing (abbreviated filing), stating that it intends to forego 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. The abbreviated filing explained that Hawaiian Electric is aggressively attacking the root causes of high rates, by, among other things, vigorously pursuing the opportunity to switch from oil to liquefied natural gas, acquiring lower-cost renewable energy resources, pursuing opportunities to achieve operational efficiencies, and deactivating older, high-cost generation. Instead of seeking a rate increase, Hawaiian Electric is focused on developing and executing the new business model, plans and strategies required by the PUC’s April 2014 regulatory orders discussed in Note 3 of the Consolidated Financial Statements, as well as other actions that will reduce rates.
Hawaiian Electric further explained 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. If the PUC determines that additional materials are required, Hawaiian Electric stated it will work with the Consumer Advocate on a schedule to submit additional information as needed. Hawaiian Electric asked for an expedited decision on this filing and stated that if the PUC decides that such a ruling is not in order, Hawaiian Electric reserves the right to supplement the abbreviated filing with additional material to support the increase in revenue requirements forgone by this filing—calculated to be $56 million over revenues at current effective rates. Hawaiian Electric’s revenue at current effective rates includes: (1) the revenue from Hawaiian Electric’s base rates, including the revenue from the energy cost adjustment clause and the purchased power adjustment clause, (2) the revenue that would be included in the decoupling revenue balancing account (RBA) in 2014 based on 2014 test year forecasted sales, and (3) the revenue from the 2014 rate adjustment mechanism (RAM) implemented in connection with the decoupling mechanism.
Under Hawaiian Electric’s proposal, the decoupling RBA and RAM would continue, subject to any change to these mechanisms ordered by the PUC in Schedule B of the decoupling proceedings, the DSM surcharge would continue since demand response (DR) program costs would not be rolled into base rates (as required in the April 28, 2014 DR Order) until the next rate case, and the pension and OPEB tracking mechanisms would continue. Hawaiian Electric plans to file its next rate case according to the normal rate case cycle using a 2017 test year. If circumstances change, Hawaiian Electric may file its next rate case earlier.

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Management cannot predict whether the PUC will accept this abbreviated filing to satisfy Hawaiian Electric’s obligation to file a rate case in 2014, whether additional material will be required or whether Hawaiian Electric will be required to proceed with a traditional rate proceeding.
Renewable energy strategy.  The Utilities’ policy is to support efforts to increase renewable energy in Hawaii. The Utilities believe their actions will help stabilize customer bills as they become less dependent on costly and price-volatile fossil fuel. The Utilities’ renewable energy strategy will also allow them to meet Hawaii’s RPS law, which requires electric utilities to meet an RPS of 10%, 15%, 25% and 40% by December 31, 2010, 2015, 2020 and 2030, respectively. The Utilities met the 10% RPS for 2010 with a consolidated RPS of 20.7%, including savings from energy efficiency programs and solar water heating (or 9.5% without DSM energy savings). Energy savings resulting from DSM energy efficiency programs and solar water heating will not count toward the RPS after 2014. For 2013, the Utilities achieved an RPS without DSM energy savings of 18%, primarily through a comprehensive portfolio of renewable energy PPAs, net energy metering programs and biofuels. The Utilities have been successful in adding significant amounts of renewable energy resources to their electric systems. The Utilities are on track to exceed their 2015 RPS goal, and lead the nation in terms of the amount of photovoltaic systems installed by its customers. Additionally, the State continues to pursue reduction in energy use, as embodied in its energy efficiency portfolio standard (EEPS) goals.
As more generating resources, whether utility scale or distributed generation, are added to the Utilities' electric systems and as customers reduce their energy usage, the ability to accommodate additional generating resources and to accept energy from existing resources is becoming more challenging. As a result, there is a growing risk that energy production from generating resources may need to be curtailed and the interconnection of additional resources will need to be constrained.closely evaluated. Also, under the state’s renewable energy strategy, there has been exponential growth in recent years in variable generation (e.g. solar and wind) on Hawaii’s island grids. Much of this variable generation is in the form of distributed generators interconnected at distribution circuits that cannot be directly controlled by system operators. As a consequence, grid resiliency in response to events that cause significant frequency and/or voltage excursions has weakened, and the prospects for larger and more frequent service outages have increased. The Utilities have been progressively making changes in their operating practices, and are pursuingmaking investments in grid modernization technologies, and are working with the solar industry to mitigate these risks and allowcontinue the productionintegration of  additionalmore renewable energy.

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Developments in the Utilities’ renewable energy strategy include the following:
In July 2011, the PUC directed Hawaiian Electric to submit a draft RFP for the PUC’s consideration for a competitive bidding process for 200 MW or more of renewable energy to be delivered to, or to be sited on, the island of Oahu. In October 2011, Hawaiian Electric filed a draft RFP with the PUC. In July 2013, the PUC issued orders related to the 200 MW RFP (see Note 3RFP. First, it issued an order that Hawaiian Electric shall amend its current draft of the Consolidated Financial StatementsOahu 200 MW RFP to remove references to the Lanai Wind Project, eliminate solicitations for additional information).an undersea transmission cable, and amend the draft RFP to reflect other guidance provided in the order. Second, it initiated an investigative proceeding to review the progress of the Lanai Wind Project stating that there was an uncertainty whether the project developer retained an equivalent ability to develop the project as when it submitted its bid in 2008 and its term sheet in 2011. Third, the PUC initiated a proceeding to solicit information and evaluate whether an interisland grid interconnection transmission system between the islands of Oahu and Maui is in the public interest, given the potential for large-scale wind and solar projects on Maui.
In May 2012, the PUC approved Hawaiian Electric’s 3-year biodiesel supply contract with Renewable Energy Group for continued biodiesel supply to CT-1 of 3 million to 7 million gallons per year.
In May 2012, Maui Electric began purchasing wind energy from the 21 MW Kaheawa Wind Power II, LLC facility, which went into commercial operation in July 2012.
In May 2012, Hawaiian Electric signed a contract, which was approved by the PUC, with the City and County of Honolulu to purchase an additional 27 MW of capacity and energy from an expanded waste-to-energy HPower facility, which was placed in service in April 2013.
In May 2012, Hawaii Electric Light signed a PPA, which the PUC approved in December 2013, with Hu Honua Bioenergy for 21.5 MW of renewable, dispatchable firm capacity fueled by locally grown biomass from a facility on the island of Hawaii.
In May 2012, the PUC instituted a proceeding for a competitive bidding process for up to 50 MW of firm renewable geothermal dispatchable energy (Geothermal RFP) on the island of Hawaii. In February 2013,July 2014, the PUC ordered Hawaii Electric Light issuedto file by September 25, 2014 its request to modify the Final Geothermal RFP and subsequently received six bids. In March 2014, Hawaii Electric Light proposed to defer the Geothermal RFP until the completion of the Hawaii Electric Light Power Supply Improvement Plan (PSIP) requested by the PUC, after which Hawaii Electric Light intends to issue an addendum to the Geothermal RFP to gather additional information from eligible bidders.RFP.
In August 2012, the battery facility at a 30 MW Kahuku wind farm experienced a fire. After the interconnection infrastructure was rebuilt and voltage regulation equipment was installed, the facility came up to full output in January 2014 to perform control system acceptance testing, and energy is being purchased at a base rate until PUC approval of an amendment to the PPA.

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In August 2012, the PUC approved a waiver from the competitive bidding process to allow Hawaiian Electric to negotiate with the U.S. Army for construction of a 50 MW utility-owned and operated firm, renewable and dispatchable generation facility at Schofield Barracks on the island of Oahu and expected to be placed in service in 2017.
In September 2012, Hawaiian Electric began purchasing test wind energy from the 69 MW Kawailoa Wind, LLC facility. The wind farm was placed into full commercial operation in November 2012.
In December 2012, the PUC approved a 3-year biodiesel supply contract with Pacific Biodiesel to supply 250,000 to 1 million gallons of biodiesel at the Honolulu International Airport Emergency Power Facility beginning in 2013.
In December 2012, the 21 MW Auwahi Wind Energy LLC facility was placed into commercial operation, selling power to Maui Electric under a 20-year contract.
In December 2012, the 5 MW Kalaeloa Solar Two, LLC photovoltaic facility was placed into commercial operation, selling power to Hawaiian Electric under a 20-year contract.
In February 2013, Hawaiian Electric issued an “Invitation for Low Cost Renewable Energy Projects on Oahu through Request for Waiver from Competitive Bidding,” which seeks to lower the cost of electricity for customers in the near term with qualified renewable energy projects on Oahu that can be quickly placed into service at a low cost per KWH. Proposals were received and Hawaiian Electric is seekingobtained waivers from the PUC Competitive Bidding Framework for 9 projects. On February 13,nine projects, subject to certain conditions. In approving the waivers, executed PPAs for three of the projects needed to be filed by June 3, 2014, and Hawaiian Electric requested that the PUC issued a D&O approving 3 waivers,revise the filing date to October 10, 2014.  Executed PPAs for which executed PPAssix of the projects need to be filed for PUC approval by June 13,December 5, 2014.
In May 2013, Maui Electric requested a waiver from the PUC Competitive Bidding Framework to conduct negotiations for a PPA for approximately 4.5 to 6.0 MW of firm power from a proposed Mahinahina Energy Park, LLC project, fueled with biofuel. In March 2014, the PUC issued a D&O approving the waiver request, provided that an executed PPA must be filed for PUC approval by September 2014.
In October 2013, Hawaiian Electric requested approval from the PUC for a waiver from the competitive bidding process and to commit $42.4 million for the purchase and installation of a 15 MW utility-scale PV generation system at its Kahe Power generation station property. If approved, the project is expected to be completed in early 2016.
In October 2013, the Utilities signed a 3-year biodiesel supply contract, subject to PUC approval, with Pacific Biodiesel Technologies, LLC to spot purchase as available biodiesel at cost parity to petroleum diesel.
In October 2013, the PUC approved Hawaiian Electric’s 20-year contract with Hawaii BioEnergy to supply 10 million gallons per year of biocrude at Kahe Power Plant to begin within five years of November 25, 2013.
In November 2013, the 5 MW Kalaeloa Renewable Energy Park, LLC photovoltaic facility was placed into commercial operation selling power to Hawaiian Electric under a 20-year contract.
In December 2013, the PUC denied approval of Hawaii Electric Light’s contract with Aina Koa Pono-Ka’u LLC (AKP) to supply 16 million gallons of biodiesel per year, citing the higher cost of the biofuel over the cost of petroleum diesel.

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In December 2013, Hawaiian Electric requested PUC approval for a waiver of the Na Pua Makani Power Partners, LLC’s proposed 24 MW wind farm located in the Kahuku area on Oahu from the competitive bidding process and of the PPA for Renewable As-Available Energy dated October 3, 2013 between Hawaiian Electric and Na Pua Makani Power Partners, LLC for the proposed 24 MW wind farm.
In April 2014, Hawaiian Electric requested PUC approval of a PPA for Renewable As-Available Energy with Lanikuhana Solar, LLC for a proposed 20 MW photovoltaic facility on Oahu.
In June 2014, the PUC approved the Utilities 3-year biodiesel supply contract with Pacific Biodiesel Technologies, LLC to spot purchase up to 200,000 gallons per month of as available biodiesel at cost parity to petroleum diesel.
The Utilities began accepting energy from feed-in tariff projects in 2011. As of March 31,June 30, 2014, there were 10 MW, 1 MW and 2 MW of installed feed-in tariff capacity from renewable energy technologies at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively.
As of March 31,June 30, 2014,, there were approximately 167196 MW, 3338 MW and 3541 MW of installed net energy metering capacity from renewable energy technologies (mainly photovoltaic) at Hawaiian Electric, Hawaii Electric Light and Maui Electric, respectively. The amount of net energy metering capacity installed in 2013the first 6 months of 2014 was about 46% higher27% lower than the amount installed in 2012.
the first 6 months of 2013, principally due to higher circuit saturation on Hawaiian Electric’s and Hawaii Electric Light’s systems (resulting in processing delays and increased costs for required further technical reviews and modification hardware).
Adequacy of supply.
Hawaiian Electric. In April 2014, Hawaiian Electric filed its 2014 Adequacy of Supply (AOS) letter, which indicated that based on its February 2014 updated sales and peak forecast, Hawaiian Electric’s generation capacity is sufficient to meet reasonably expected demands for service and provide reasonable reserves for emergencies for the next three years (2014-2016). 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 2016 timeframe. Hawaiian Electric is proceeding with future firm capacity additions in coordination with the State of Hawaii Department of Transportation, and also

68


the U.S. Department of the Army for a utility owned and operated renewable, dispatchable, generation security project on federal lands. Hawaiian Electric is continuing negotiations with two firm capacity IPPs on Oahu under PPAs scheduled to expire in 2016 and 2022.

Hawaii Electric Light. In January 2014, Hawaii Electric Light filed its 2014 AOS letter which indicated that Hawaii Electric Light`s generation capacity through 2016 is sufficiently large to meet all reasonably expected demands for service and provide reasonable reserves for emergencies.
In April 2014, Hawaii Electric Light submitted a Power Supply Plan (PSP), which develops the base plan for the next 10 years of operations based on current assumptions, system impact studies and economic analysis. Generation requirements for the future are based on a PV growth rate assumption derived from the current rapid growth rate.
The PSP outlined the process used to determine the future plans for existing and future generating units. Additional generation can be added based on the ability of new generation to lower the cost to customers and to meet the system operating stability requirements. The current plans are to add the Hu Honua Bioenergy, LLC plant in 2015, and potentially additional generation in 2020 following evaluation of the proposals received from bidders on an RFP for up to 50 MW of geothermal generation. The current plans also include decommissioning Shipman units 3 and 4 in 2015, seasonal cycling of the Puna plant in 2014, andwith deactivation in 2018 and decommissioning in 2020, and occasional cycling operation of the Hill unit 5 in 2014, with deactivation in 2020 and decommissioning in 2022.
Hawaii Electric Light will review, revise and update the PSP based on new resource opportunities, identification of needs for additional resources or changes in assumptions. In its Reliability Standards Working Group order issuedAlso see “April 2014 regulatory orders—Integrated Resource Planning” in April 2014,Note 3 of the PUC stated that it will consolidate for review in a new docket the Hawaii Electric Light PSP with the Power Supply Improvement Plans that are to be filed within 120 days by Hawaiian Electric and Maui Electric.Consolidated Financial Statements.
Maui Electric. In April 2014, Maui Electric filed its 2014 AOS letter, which indicated that Maui Electric’s generation capacity through 2015 is sufficient to meet the forecasted demands on the islands of Maui, Lanai, and Molokai. Maui Electric anticipates needing additional firm capacity on Maui in the 2016 timeframe, with greater capacity needs in 2019. In February 2014, Maui Electric deactivated two fossil fuel generating units at its Kahului Power Plant. Maui Electric anticipates the retirement of all generating units at the Kahului Power Plant in the 2019 timeframe because of their age. Maui Electric plans to issue one or more RFPs for energy storage, demand response and firm generating capacity, and to make transmission system improvements needed to ensure reliability and voltage support in this timeframe.
April 2014 regulatory orders. In April 2014, the PUC issued four orders that collectively provide certain key policy, resource planning, and operational directives to the Utilities. See “April 2014 regulatory orders” in Note 3 of the Consolidated Financial Statements.
Commitments and contingencies.  See Note 3 of the Consolidated Financial Statements.

60


Recent accounting pronouncements.  See Note 10, “Recent accounting pronouncements,” of the Consolidated Financial Statements.
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, commercial paper and 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) March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
Short-term borrowings $35
 1% $—
 —% $103
 4% $—
 —%
Long-term debt, net 1,218
 42
 1,218
 43
 1,218
 41
 1,218
 43
Preferred stock 34
 1
 34
 1
 34
 1
 34
 1
Common stock equity 1,606
 56
 1,594
 56
 1,619
 54
 1,594
 56
 $2,893
 100% $2,846
 100% $2,974
 100% $2,846
 100%
 
                       Information about Hawaiian Electric’s short-term borrowings (other than from Hawaii Electric Light and Maui Electric) and line of credit facility were as follows:

69


 
 Average balance Balance Average balance Balance
(in millions) Three months ended March 31, 2014 March 31, 2014 December 31, 2013 Six months ended June 30, 2014 June 30, 2014��December 31, 2013
Short-term borrowings 1
  
  
  
  
  
  
Commercial paper $22
 $35
 $—
 $45
 $103
 $—
Line of credit draws —
 —
 —
 —
 —
 —
Borrowings from HEI —
 —
 —
 —
 —
 —
Undrawn capacity under line of credit facility (expiring December 5, 2016) 2
  
 175
 175
  
 200
 175
 

1        
The maximum amount of Hawaiian Electric’s external short-term borrowings during the first threesix months of 2014 was $67$103 million. At MarchJune 30, 2014, Hawaii Electric Light and Maui Electric had short-term borrowings from Hawaiian Electric of $3 million and $20 million, respectively. At July 31, 2014, Hawaiian Electric had $0.1 million of short-term borrowings from Hawaii Electric Light, and Maui Electric had $20 million of short-term borrowings from Hawaiian Electric. At April 30, 2014, Hawaiian Electric had $51$83 million of outstanding commercial paper, no draws under its line of credit facility, no borrowings from HEI and $7$3 million of short-term borrowings from Hawaii Electric Light. Also, at April 30,July 31, 2014, Maui Electric had $13$12 million of short-term borrowings from Hawaiian Electric. Intercompany borrowings are eliminated in consolidation.
2        
On April 2, 2014, Hawaiian Electric entered into an amended and restated revolving non-collateralized credit agreement, which increased Hawaiian Electric’s line of credit to $200 million from $175 million and revised the term. See Note 11 of the Consolidated Financial Statements.

                       Hawaiian Electric has a line of credit facility, as amended and restated on April 2, 2014, of $200 million. See Note 11 of the Consolidated Financial Statements. The Hawaiian Electric facility provides for a term through April 1, 2015 (but which term is to be extended to up to April 2, 2019 upon approval by the PUC during the initial term, which approval is currently being requested) and provides improved pricing compared to Hawaiian Electric’s prior facility.
                       Special purpose revenue bonds (SPRBs) have been issued by the Department of Budget and Finance of the State of Hawaii (DBF) to finance (and refinance) capital improvement projects of Hawaiian Electric and its subsidiaries, but the sources of their repayment are the non-collateralized obligations of Hawaiian Electric and its subsidiaries under loan agreements and notes issued to the DBF, including Hawaiian Electric’s guarantees of its subsidiaries’ obligations. The payment of principal and interest due on SPRBs currently outstanding and issued prior to 2009 are insured by Ambac Assurance Corporation or Financial Guaranty Insurance Company (FGIC), which was placed in a rehabilitation proceeding in the State of New York in June 2012. On August 19, 2013 FGIC's plan of rehabilitation became effective and the rehabilitation proceeding terminated. The S&P and Moody’s ratings of these insurers, which at the time the insured obligations were issued were higher than the ratings of the Utilities, have been withdrawn. Management believes that if Hawaiian Electric’s long-term credit ratings were to be downgraded, or if credit markets further tighten, it could be more difficult and/or expensive to sell bonds in the future.
                       The PUC has approved the use of an expedited approval procedure for the approval of long-term debt financings or refinancings (including the issuance of taxable debt) by the Utilities, up to specified amounts, during the period 2013 through

61


2015, subject to certain conditions. On October 3, 2013, after obtaining such expedited approvals, the Utilities issued through a private placement taxable non-collateralized senior notes with an aggregate principal amount of $236 million. PUC approval to issue an additional $80 million of long-term debt (Hawaiian Electric $50 million, Hawaii Electric Light $25 million and Maui Electric $5 million) and $47 million to refinance outstanding revenue bonds (Hawaiian Electric $40 million, Hawaii Electric Light $5 million and Maui Electric $2 million) can be requested under the expedited approval procedure through 2015.
                   In April 2014, Hawaiian Electric, Hawaii Electric Light and Maui Electric filed an application with the PUC for approval of the sale of each utility’s common stock over a period from the date of approval in 2014 to December 31, 2016 (Hawaiian Electric’s sale to HEI of up to $250 million and Hawaii Electric Light’s and Maui Electric’s sales to Hawaiian Electric of up to $26 million and $47 million, respectively), and the purchase of the Hawaii Electric Light and Maui Electric common stock by Hawaiian Electric over the same period. In July 2014, the Utilities modified their request to the PUC to approve the issuance and sale of common stock in 2014 only in the amounts stated in the application (Hawaiian Electric’s issuance and sale of its common stock to HEI of up to $60 million and Hawaii Electric Light’s and Maui Electric’s issuance and sale of their common stock to Hawaiian Electric of up to $5 million and $20 million, respectively). In addition, under a previous authorization received from the PUC in November 2010, Hawaiian Electric and Hawaii Electric Light have remaining authorization to issue their common stock through 2014 of up to an additional $43.4 million and $19.9 million, respectively.
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. For the first threesix months of 2014 and 2013, net cash provided by operating activities decreased by $53$87 million and increased by $64$133 million, respectively, compared to the same period in the prior year. In 2014, noncash depreciation and

70


amortization amounted to $43$87 million an increase over the prior year due to an increase in plant and equipment. Further net cash providedequipment offset by operating activities included an increasea decrease of $34 million of fuel oil stock and $9$63 million in regulatory assets.accounts payable. In 2013, noncash depreciation and amortization amounted to $39$80 million an increase over the prior year due to an increase in plant and equipment. Further, net cash provided by operating activities included a $29$44 million increasedecrease in fuel oil stock, offset by a net decrease of $37$27 million in accounts receivable and accrued unbilled revenues due to timing of payments.payments, and $41 million decrease in accounts payable.
For the first threesix months of 2014 and 2013, net cash used in investing activities increased by $1 million$85,000 and $16$18 million, respectively, compared to the prior year. Cash used in investing activities consisted primarily of capital expenditures, partly offset by contributions in aid of construction.
Financing activities provide supplemental cash for both day-to-day operations and capital requirements as needed. For the first threesix months of 2014 and 2013, cash flows from financing activities increased by $45 million and decreased by $11 million and increased by $14$81 million, respectively, compared to the same periods in the prior year. In 2014, cash provided by financing activities consisted primarily of net proceeds received from short-term borrowings of $35$103 million, partly offset by the payment of $23$45 million of common and preferred stock dividends. In 2013, cash provided by financing activities consisted of net proceeds received from short-term borrowings of $43$54 million, partly offset by the payment of $21$42 million of common and preferred stock dividends.

62


Bank
 
RESULTS OF OPERATIONS
 Three months  
 ended March 31		 Increase   Three months  
 ended June 30		 Increase  
(in millions) 2014 2013 (decrease) Primary reason(s) 2014 2013 (decrease) Primary reason(s)
Interest income $47
 $46
 $1
 The impact of higher average earning asset balances was offset by lower yields on earning assets. ASB’s average loan portfolio balance for the three months ended March 31, 2014 was $375 million higher than for the same period in 2013 as average residential, home equity lines of credit, commercial real estate and commercial loan balances increased by $121 million, $116 million, $84 million and $75 million, respectively. The growth in these loan portfolios was reflective of ASB’s portfolio mix target and loan growth strategy. Loan portfolio yields were impacted by the low interest rate environment as new loan production yields were lower than the average loan portfolio yields. The average investment and mortgage-related securities portfolio balance decreased by $123 million as ASB sold $70 million of agency obligations in 2013 and its $77 million municipal bond portfolio in the first quarter of 2014. $47
 $47
 $—
 The impact of higher average earning asset balances was offset by lower yields on earning assets. ASB’s average loan portfolio balance for the three months ended June 30, 2014 was $325 million higher than for the same period in 2013 as average home equity lines of credit, commercial real estate, commercial and residential loan balances increased by $115 million, $103 million, $86 million and $43 million, respectively. The growth in these loan portfolios was reflective of ASB’s portfolio mix target and loan growth strategy. Loan portfolio yields were impacted by the low interest rate environment as new loan production yields were lower than the average loan portfolio yields. The average investment and mortgage-related securities portfolio balance decreased by $71 million as ASB sold its $77 million municipal bond portfolio in the first quarter of 2014.
Noninterest income 17
 19
 (2) Lower noninterest income due to $3 million lower mortgage banking income as a result of lower mortgage loan volume being sold and $2 million lower debit card interchange fee as a result of being non-exempt from the Durbin Amendment as of July 1, 2013 were partly offset by the gain of $3 million on sale of the municipal bond portfolio. 14
 19
 (5) Lower noninterest income due to $2 million lower mortgage banking income as a result of lower mortgage loan volume being sold, $2 million lower debit card interchange fees as a result of being non-exempt from the Durbin Amendment as of July 1, 2013 and $1 million gain on sale of the agency obligations in the second quarter of 2013.
Revenues 64
 65
 (1)   61
 66
 (5)  
Interest expense 3
 2
 1
 Average deposit balances for the three months ended March 31, 2014 increased by $175 million compared to the same period in 2013 due to an increase in core deposits of $211 million, partly offset by a decrease in term certificates of $36 million. The other borrowings average balance increased by $51 million due to an increase in FHLB advance borrowings. 3
 2
 1
 Average deposit balances for the three months ended June 30, 2014 increased by $202 million compared to the same period in 2013 due to an increase in core deposits of $235 million, partly offset by a decrease in term certificates of $33 million. The other borrowings average balance increased by $50 million due to an increase in FHLB advance borrowings.
Provision for loan losses 1
 2
 (1) The provision for loan losses declined due to lower net charge-offs and improved credit quality of the loan portfolio. The net charge-off ratio at March 31, 2014 was 0.02% compared to 0.12% at March 31, 2013.
Provision (credit) for loan losses 1
 (1) 2
 The provision for loan losses increased as a credit for loan losses was recorded in the second quarter of 2013 due to a $1 million release of reserves related to ASB’s credit card portfolio sale and released reserves associated with specific commercial loan paydowns. ASB had a net recovery ratio of 0.04% in the second quarter of 2014 compared to a net charge-off ratio of 0.08% in the second quarter of 2013.
Noninterest expense 38
 39
 (1) Noninterest expense for the three months ended March 31, 2014 decreased slightly compared to the same period in 2013 due to lower debit card expenses, partly offset by higher printing expenses. 40
 40
 —
 Noninterest expense for the three months ended June 30, 2014 was flat compared to the same period in 2013.
Expenses 42
 43
 (1)  44
 41
 3
 
Operating income 22
 22
 —
 Lower provision for loan losses and lower noninterest expenses, offset by lower noninterest income. 17
 25
 (8) Lower noninterest income, higher provision for loan losses and higher interest expense.
Net income 15
 14
 1
  12
 16
 (4) 



71


  Six months  
 ended June 30		 Increase  
(in millions) 2014 2013 (decrease) Primary reason(s)
Interest income $93
 $93
 $—
 The impact of higher average earning asset balances was partly offset by lower yields on earning assets. ASB’s average loan portfolio balance for the six months ended June 30, 2014 was $350 million higher than for the same period in 2013 as average home equity lines of credit, commercial real estate, residential and commercial loan balances increased by $116 million, $93 million, $82 million and $81 million, respectively. The growth in these loan portfolios was reflective of ASB’s portfolio mix target and loan growth strategy. Loan portfolio yields were impacted by the low interest rate environment as new loan production yields were lower than the average loan portfolio yields. The average investment and mortgage-related securities portfolio balance decreased by $97 million as ASB sold $70 million of agency obligations in 2013 and its $77 million municipal bond portfolio in the first quarter of 2014.
Noninterest income 31
 38
 (7) Lower noninterest income due to $4 million lower mortgage banking income as a result of lower mortgage loan volume being sold and $4 million lower debit card interchange fees as a result of being non-exempt from the Durbin Amendment as of July 1, 2013 were partly offset by higher gain on sale of securities.
Revenues 124
 131
 (7)  
Interest expense 5
 5
 —
 Average deposit balances for the six months ended June 30, 2014 increased by $189 million compared to the same period in 2013 due to an increase in core deposits of $223 million, partly offset by a decrease in term certificates of $34 million. The other borrowings average balance increased by $50 million due to an increase in FHLB advance borrowings.
Provision for loan losses 2
 1
 1
 The provision for loan losses increased as a credit for loan losses was recorded in the second quarter of 2013 due to a $1 million release of reserves related to ASB’s credit card portfolio sale. At June 30, 2014, ASB had a net recovery ratio of 0.01% compared to a net charge-off ratio of 0.10% at June 30, 2013.
Noninterest expense 78
 79
 (1) Lower noninterest expense due to lower debit card expenses, partly offset by higher product development costs.
Expenses 85
 85
 —
  
Operating income 39
 46
 (7) Lower noninterest income and higher provision for loan losses, partly offset by lower noninterest expenses.
Net income 26
 30
 (4)  

           Details of ASB’s other noninterest income and other noninterest expense were as follows:
 Three months ended March 31 Three months ended June 30 Six months ended June 30
(in thousands) 2014 2013 2014 2013 2014 2013
Bank-owned life insurance $963
 $967
 $982
 $985
 $1,945
 $1,952
Other 625
 625
 661
 746
 1,286
 1,371
Total other income, net $1,588
 $1,592
 $1,643
 $1,731
 $3,231
 $3,323
FDIC insurance premium $796
 $840
 $805
 $848
 $1,601
 $1,688
Marketing 711
 538
 1,031
 824
 1,742
 1,362
Office supplies, printing and postage 1,616
 873
 1,456
 1,026
 3,072
 1,899
Communication 503
 471
 448
 424
 951
 895
Other 3,527
 4,873
 4,354
 5,378
 7,881
 10,251
Total other expense $7,153
 $7,595
 $8,094
 $8,500
 $15,247
 $16,095
                       See Note 4 of the Consolidated Financial Statements and “Economic conditions” in the “HEI Consolidated” section above.
                       Despite the revenue pressures across the banking industry, management expects ASB’s low-cost funding base and lower-risk profile to continue to deliver strong performance compared to industry peers.

6372


                       ASB’s return on average assets and net interest margin were as follows:
 Three months ended March 31 Three months ended June 30 Six months ended June 30
(percent) 2014 2013 2014 2013 2014 2013
Return on average assets 1.10
 1.12
 0.87
 1.25
 0.98
 1.19
Net interest margin 3.64
 3.78
 3.55
 3.79
 3.59
 3.79
Average balance sheet and net interest margin.  The following tables set forth average balances, together with interest earned and accrued, and resulting yields and costs:
Three months ended March 31 2014 2013
Three months ended June 30 2014 2013
(dollars in thousands) 
Average
balance
 Interest 
Yield/
rate (%)
 
Average
balance
 Interest 
Yield/
rate (%)
 
Average
balance
 Interest 
Yield/
rate (%)
 
Average
balance
 Interest 
Yield/
rate (%)
Assets:  
  
  
  
  
  
  
  
  
  
  
  
Other investments 1
 $176,766
 $76
 0.17
 $198,202
 $64
 0.13
 $187,179
 $86
 0.18
 $164,374
 $44
 0.11
Securities purchased under resale agreements 8,000
 8
 0.38
 —
 —
 —
 12,527
 12
 0.38
 26,154
 25
 0.38
Available-for-sale investment and mortgage-related securities 525,582
 3,101
 2.36
 648,693
 3,619
 2.23
 546,694
 2,852
 2.09
 617,942
 3,386
 2.19
Loans                        
Residential 1-4 family 2,003,541
 22,669
 4.53
 1,882,185
 23,356
 4.96
 2,007,362
 22,475
 4.48
 1,964,140
 23,503
 4.79
Commercial real estate 505,205
 5,373
 4.28
 421,492
 4,633
 4.42
 532,334
 5,504
 4.14
 429,409
 4,973
 4.64
Home equity line of credit 756,428
 6,098
 3.27
 640,151
 4,462
 2.83
 780,821
 6,414
 3.29
 665,879
 4,840
 2.92
Residential land 15,873
 243
 6.12
 25,009
 256
 4.09
 16,285
 251
 6.16
 22,607
 335
 5.93
Commercial loans 786,290
 7,233
 3.72
 711,707
 7,469
 4.24
 785,438
 7,166
 3.65
 699,023
 7,347
 4.21
Consumer loans 111,666
 2,066
 7.48
 123,648
 2,427
 7.94
 107,121
 2,041
 7.64
 123,601
 2,626
 8.52
Total loans 2,3
 4,179,003
 43,682
 4.20
 3,804,192
 42,603
 4.50
 4,229,361
 43,851
 4.15
 3,904,659
 43,624
 4.47
Total interest-earning assets 4
 4,889,351
 46,867
 3.85
 4,651,087
 46,286
 4.00
 4,975,761
 46,801
 3.76
 4,713,129
 47,079
 4.00
Allowance for loan losses (40,514)  
  
 (42,608)  
  
 (41,752)  
  
 (43,372)  
  
Non-interest-earning assets 444,377
  
  
 434,117
  
  
 454,129
  
  
 429,924
  
  
Total assets $5,293,214
  
  
 $5,042,596
  
  
 $5,388,138
  
  
 $5,099,681
  
  
Liabilities and shareholder’s equity:  
  
  
  
  
  
  
  
  
  
  
  
Savings $1,840,042
 $268
 0.06
 $1,775,477
 $254
 0.06
 $1,869,934
 $278
 0.06
 $1,811,157
 $263
 0.06
Interest-bearing checking 717,759
 29
 0.02
 640,190
 24
 0.02
 736,767
 32
 0.02
 659,790
 25
 0.02
Money market 180,990
 57
 0.13
 195,563
 63
 0.13
 176,819
 55
 0.13
 176,812
 56
 0.13
Time certificates 433,756
 871
 0.81
 469,798
 971
 0.84
 430,277
 872
 0.81
 462,762
 952
 0.83
Total interest-bearing deposits 3,172,547
 1,225
 0.16
 3,081,028
 1,312
 0.17
 3,213,797
 1,237
 0.15
 3,110,521
 1,296
 0.17
Advances from Federal Home Loan Bank 100,000
 775
 3.10
 50,000
 535
 4.28
 100,000
 784
 3.10
 51,264
 542
 4.18
Securities sold under agreements to repurchase 148,408
 630
 1.70
 147,296
 629
 1.71
 145,643
 636
 1.73
 144,496
 636
 1.74
Total interest-bearing liabilities 3,420,955
 2,630
 0.31
 3,278,324
 2,476
 0.30
 3,459,440
 2,657
 0.31
 3,306,281
 2,474
 0.30
Non-interest bearing liabilities:  
  
  
  
  
  
  
  
    
  
  
Deposits 1,234,566
  
  
 1,151,572
  
  
 1,281,412
  
   1,182,244
  
  
Other 110,349
  
  
 110,850
  
  
 115,458
  
   104,372
  
  
Total liabilities 4,765,870
  
  
 4,540,746
  
  
 4,856,310
  
   4,592,897
  
  
Shareholder’s equity 527,344
  
  
 501,850
  
  
 531,828
  
   506,784
  
  
Total liabilities and shareholder’s equity $5,293,214
  
  
 $5,042,596
  
  
 $5,388,138
  
   $5,099,681
  
  
Net interest income  
 $44,237
  
  
 $43,810
  
  
 $44,144
    
 $44,605
  
Net interest margin (%) 5
  
  
 3.64
  
  
 3.78
  
  
 3.55
  
  
 3.79


73


Six months ended June 30 2014 2013
(dollars in thousands) Average
balance		 Interest Yield/
rate (%)		 Average
balance		 Interest Yield/
rate (%)
Assets:  
  
  
  
  
  
Other investments 1
 $182,002
 $162
 0.18
 $181,195
 $108
 0.12
Securities purchased under resale agreements 10,276
 20
 0.38
 13,149
 25
 0.38
Available-for-sale investment and mortgage-related securities 536,196
 5,953
 2.22
 633,232
 7,005
 2.21
Loans            
Residential 1-4 family 2,005,462
 45,144
 4.50
 1,923,389
 46,859
 4.87
Commercial real estate 518,844
 10,877
 4.21
 425,473
 9,606
 4.53
Home equity line of credit 768,692
 12,512
 3.28
 653,086
 9,302
 2.87
Residential land 16,081
 494
 6.14
 23,801
 591
 4.97
Commercial loans 785,861
 14,399
 3.68
 705,330
 14,816
 4.23
Consumer loans 109,381
 4,107
 7.56
 123,624
 5,053
 8.23
Total loans 2,3
 4,204,321
 87,533
 4.18
 3,854,703
 86,227
 4.49
Total interest-earning assets 4
 4,932,795
 93,668
 3.81
 4,682,279
 93,365
 4.00
Allowance for loan losses (41,136)  
  
 (42,992)  
  
Non-interest-earning assets 449,279
  
  
 432,009
  
  
Total assets $5,340,938
  
  
 $5,071,296
  
  
Liabilities and shareholder’s equity:  
  
  
  
  
  
Savings $1,855,070
 $546
 0.06
 $1,793,415
 $517
 0.06
Interest-bearing checking 727,316
 61
 0.02
 650,044
 49
 0.02
Money market 178,893
 112
 0.13
 186,136
 119
 0.13
Time certificates 432,007
 1,743
 0.81
 466,261
 1,923
 0.83
Total interest-bearing deposits 3,193,286
 2,462
 0.16
 3,095,856
 2,608
 0.17
Advances from Federal Home Loan Bank 100,000
 1,559
 3.10
 50,635
 1,077
 4.23
Securities sold under agreements to repurchase 147,018
 1,266
 1.71
 145,888
 1,265
 1.73
Total interest-bearing liabilities 3,440,304
 5,287
 0.31
 3,292,379
 4,950
 0.30
Non-interest bearing liabilities:  
  
  
  
  
  
Deposits 1,258,118
  
  
 1,166,993
  
  
Other 112,918
  
  
 107,594
  
  
Total liabilities 4,811,340
  
  
 4,566,966
  
  
Shareholder’s equity 529,598
  
  
 504,330
  
  
Total liabilities and shareholder’s equity $5,340,938
  
  
 $5,071,296
  
  
Net interest income  
 $88,381
  
  
 $88,415
  
Net interest margin (%) 5
  
  
 3.59
  
  
 3.79
1       Includes federal funds sold, interest bearing deposits and stock in the Federal Home Loan Bank of Seattle ($9289 million and $96$95 million as of March 31,June 30, 2014 and 2013, respectively)
2    
Includes loans held for sale.
3    
Includes loan fees of $1.1$0.7 million and $1.5$1.4 million for the three months ended March 31,June 30, 2014 and 2013, respectively, and $1.8 million and $2.9 million for the six months ended June 30, 2014 and 2013, respectively, together with interest accrued prior to suspension of interest accrual on nonaccrual loans.
4    
Interest income includes taxable equivalent basis adjustments, based upon a federal statutory tax rate of 35%, of nil and $0.2 million for the three months ended March 31,June 30, 2014 and 2013.2013, respectively, and $0.2 million and $0.4 million for the six months ended June 30, 2014 and 2013, respectively.
5   
Defined as net interest income as a percentage of average earning assets.


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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 and these conditions have continued to have a negative impact on ASB’s net interest margin.
                       Loan originations and mortgage-related securities are ASB’s primary sources of 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 loan portfolio was as follows:
 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
(dollars in thousands) Balance % of total Balance % of total Balance % of total Balance % of total
Real estate loans:  
  
  
  
  
  
  
  
Residential 1-4 family $1,985,812
 47.3
 $2,006,007
 48.2
 $2,019,092
 47.0
 $2,006,007
 48.2
Commercial real estate 452,303
 10.8
 440,443
 10.6
 476,116
 11.1
 440,443
 10.6
Home equity line of credit 764,483
 18.2
 739,331
 17.8
 790,837
 18.4
 739,331
 17.8
Residential land 15,906
 0.4
 16,176
 0.4
 17,189
 0.4
 16,176
 0.4
Commercial construction 66,578
 1.6
 52,112
 1.3
 80,312
 1.9
 52,112
 1.3
Residential construction 16,474
 0.4
 12,774
 0.3
 17,441
 0.4
 12,774
 0.3
Total real estate loans, net 3,301,556
 78.7
 3,266,843
 78.6
 3,400,987
 79.2
 3,266,843
 78.6
Commercial loans 786,611
 18.7
 783,388
 18.8
 782,804
 18.2
 783,388
 18.8
Consumer loans 108,202
 2.6
 108,722
 2.6
 111,254
 2.6
 108,722
 2.6
 4,196,369
 100.0
 4,158,953
 100.0
 4,295,045
 100.0
 4,158,953
 100.0
Less: Deferred fees and discounts (7,909)  
 (8,724)  
 (7,433)  
 (8,724)  
Allowance for loan losses (40,923)  
 (40,116)  
 (42,372)  
 (40,116)  
Total loans, net $4,147,537
  
 $4,110,113
  
 $4,245,240
  
 $4,110,113
  
                        The increase in the total loan portfolio during the first threesix months ofended June 30, 2014 was primarily due to an increase in originated home equity lines of credit, and commercial real estate loans and commercial construction loans.
                                                       Home equity — key credit statistics.
March 31, 2014 December 31, 2013June 30, 2014 December 31, 2013
Outstanding balance (in thousands)$764,483
 $739,331
$790,837
 $739,331
Percent of portfolio in first lien position39.4% 38.2%39.9 % 38.2%
Net charge-off ratio—% 0.06%
Net charge-off (recovery) ratio(0.05)% 0.06%
Delinquency ratio0.22% 0.28%0.24 % 0.28%
     End of draw period – interest only Current     End of draw period – interest only Current
March 31, 2014 Total Interest only 2014-2015 2016-2018 Thereafter amortizing
June 30, 2014 Total Interest only 2014-2015 2016-2018 Thereafter amortizing
Outstanding balance (in thousands) $764,483
 $557,004
 $1,151
 $105,721
 $450,132
 $207,479
 $790,837
 $581,460
 $1,032
 $104,762
 $475,666
 $209,377
% of total 100% 73% —% 14% 59% 27% 100% 74% —% 14% 60% 26%
 
                       The home equity line of credit (HELOC)HELOC portfolio makes up 18% 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 92%93% of the total HELOC portfolio and is the current product offering. Within this product type, 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 March 31,June 30, 2014, approximately 19% of the portfolio balances were amortizing loans under the Fixed Rate Loan Option. Nearly all originations prior to 2008 consisted of amortizing equity lines that have structured principal payments during the draw period. These older vintage equity lines represent 8%7% of the portfolio and are included in the amortizing balances identified in the table above.
Loan portfolio risk elements.  See Note 4 of the Consolidated Financial Statements.

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Investment and mortgage-related securities.  ASB’s investment portfolio was comprised as follows:
 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013
(dollars in thousands) Balance % of total Balance % of total Balance % of total Balance % of total
Federal agency obligations $81,615
 16% $80,973
 15% $97,049
 18% $80,973
 15%
Mortgage-related securities — FNMA, FHLMC and GNMA 431,014
 83
 369,444
 70
 447,292
 81
 369,444
 70
U.S treasury securities 4,905
 1
 —
 —
 4,980
 1
 —
 —
Municipal bonds —
 —
 78,590
 15
 —
 —
 78,590
 15
 $517,534
 100% $529,007
 100% $549,321
 100% $529,007
 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 Seattle and securities sold under agreements to repurchase continue to be additional sources of funds. As of March 31,June 30, 2014 and December 31, 2013, ASB’s costing liabilities consisted of 95% deposits and 5% other borrowings. The weighted average cost of deposits for the first threesix months of 2014 and 2013 was 0.11% and 0.12%., respectively.
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 those instruments, respectively. In addition, changes in credit spreads also impact the fair values of those instruments.
As of March 31,June 30, 2014, ASB had an unrealized loss, net of taxes, on available-for-sale investments and mortgage-related securities (including securities pledged for repurchase agreements) in AOCI of $3$0.3 million compared to an unrealized loss, net of taxes, on available-for-sale investments and mortgage-related securities (including securities pledged for repurchase agreements) in AOCI of $4 million as of December 31, 2013. See “Item 3. Quantitative and qualitative disclosures about market risk.”
During the first threesix months of 2014, ASB recorded a provision for loan losses of $1.0$2.0 million primarily due to growth in the loan portfolio and net charge-offs during the year for consumer loans and growth in the loan portfolio.loans. During the first threesix months of 2013, ASB recorded a provision for loan losses of $1.9$0.9 million primarily due to net charge-offs during the quarteryear for 1-4 family, residential land,consumer, commercial and consumer loans.HELOC loans, and growth in the loan portfolio, partly offset by the release of reserves for the credit card portfolio. Financial stress on ASB’s customers may result in higher levels of delinquencies and losses.
 Three months  
 ended March 31		 
Year ended
December 31
 Six months ended June 30 
Year ended
December 31
(in thousands) 2014 2013 2013 2014 2013 2013
Allowance for loan losses, January 1 $40,116
 $41,985
 $41,985
 $40,116
 $41,985
 $41,985
Provision for loan losses 995
 1,858
 1,507
 2,016
 899
 1,507
Less: net charge-offs 188
 1,113
 3,376
 (240) 1,880
 3,376
Allowance for loan losses, end of period $40,923
 $42,730
 $40,116
 $42,372
 $41,004
 $40,116
Ratio of allowance for loan losses, end of period, to end of period loans outstanding 0.98% 1.11% 0.97% 0.99 % 1.04% 0.97%
Ratio of net charge-offs during the period to average loans outstanding (annualized) 0.02% 0.12% 0.09% (0.01)% 0.10% 0.09%
Legislation and regulation.  ASB is subject to extensive regulation, principally by the Office of the Comptroller of the Currency (OCC) and the Federal Deposit Insurance Corporation (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, ASHI 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, ASHI and ASB, under the Dodd-Frank Act, on July 21, 2011, all of the functions of the Office of Thrift Supervision (OTS) transferred to the OCC, the FDIC, the Federal Reserve Board (FRB) and the Consumer Financial Protection Bureau (Bureau). Supervision and regulation of HEI and ASHI, as thrift holding

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companies, moved to the FRB, and supervision and regulation of ASB, as a federally chartered savings bank, moved to the OCC.

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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, 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 imposes 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, under the proposed Ability-to-Repay rule, among other things, (i) potential borrowers will have to supply financial information, and lenders must verify it, (ii) to qualify for a particular loan, a consumer will have to have sufficient assets or income to pay back the loan, and (iii) lenders will 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.
On May 22, 2012, the Bureau issued the Final Remittance Rule (an amendment to Regulation E). It became effective on October 28, 2013. For consumer international wires, the rule now provides flexibility regarding the disclosure of foreign taxes, as well as fees imposed by a designated recipient’s institution for receiving a remittance transfer in an account. Second, the rule limits a remittance transfer provider’s obligation to disclose foreign taxes to those imposed by a country’s central government. And third, the rule revises the error resolution provisions that apply when a remittance transfer is not delivered to a designated recipient because the sender provided incorrect or insufficient information, and, in particular, when a sender provides an incorrect account number and that incorrect account number results in the funds being deposited in the wrong account. On April 14, 2014, the Bureau proposed to amend the Final Remittance Rule. The proposal extends a temporary provision that permits insured institutions to estimate certain pricing disclosures. Based on a preliminary determination that the termination of the exception would negatively affect the ability of insured institutions to send remittance transfers, the Bureau proposed to extend the temporary exception by five years from July 21, 2015, to July 21, 2020. This rule has not had a significant impact on ASB's results of operations.
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 will 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.
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. For the firstsecond quarter of 2014, ASB had earned an average of 2322 cents per electronic debit transaction, compared to an average of 49 cents per electronic debit transaction in the firstsecond quarter of 2013. ASB estimates debit card interchange fees to be lower, as a result of the application of this Amendment, by approximately $6 million after tax in 2014.
Many of the provisions of the Dodd-Frank Act, as amended, will not become effective until implementing regulations are issued and effective.
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,

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either 50% or more of its total consolidated assets or 50% or more of its total revenues on an enterprise-wide basis (calculated

67


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 ASHI). The FRB anticipates that it will release a proposal on intermediate holding companies in the near term 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.
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 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 risk-based 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 risk-based 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 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 is effective January 1, 2015 for ASB. 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 be effective for HEI or ASHI on January 1, 2015 as well. If the fully phased-in capital requirements were currently applicable to HEI and ASB, management believes HEI and ASB 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 ASHI, if any.

Commitments and contingencies.  See Note 4 of the Consolidated Financial Statements.
FINANCIAL CONDITION
Liquidity and capital resources.
(dollars in millions) March 31, 2014 December 31, 2013 % change June 30, 2014 December 31, 2013 % change
Total assets $5,371
 $5,244
 2
 $5,418
 $5,244
 3
Available-for-sale investment and mortgage-related securities 518
 529
 (2) 549
 529
 4
Loans receivable held for investment, net 4,148
 4,110
 1
 4,245
 4,110
 3
Deposit liabilities 4,478
 4,372
 2
 4,525
 4,372
 3
Other bank borrowings 245
 245
 —
 242
 245
 (1)
As of March 31,June 30, 2014, ASB was one of Hawaii’s largest financial institutions based on assets of $5.4 billion and deposits of $4.5 billion.
As of March 31,June 30, 2014, ASB’s unused FHLB borrowing capacity was approximately $1.2 billion. As of March 31,June 30, 2014, ASB had commitments to borrowers for loan commitments and unused lines and letters of credit of $1.7 billion, including. There were no commitments to lend $0.3 million to borrowers whose loan terms have been impaired or modified in troubled debt restructurings. Management believes ASB’s current sources of funds will enable it to meet these obligations while maintaining liquidity at satisfactory levels.

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For the first threesix months ofended June 30, 2014, net cash provided by ASB’s operating activities was $18$26 million. Net cash used during the same period by ASB’s investing activities was $17$140 million, primarily due to purchases of investment and mortgage-related securities of $80$126 million and a net increase in loans receivable of $38$137 million, partly offset by proceeds from the sale of investment securities of $80 million, repayments of investment and mortgage-related securities of $15$33 million and redemption of stock from the FHLB of Seattle of $6$12 million. Net cash provided by financing activities during this period was $93$132 million, primarily due to net increases in deposit liabilities of $106$152 million, partly offset by a net decrease in mortgage escrow depositsretail repurchase agreements of $4$2 million and the payment of $9$19 million in common stock dividends to HEI (through ASHI).
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 March 31,June 30, 2014, ASB was well-capitalized (minimum ratio requirements noted in parentheses) with a leverage ratio of 9.0% (5.0%), a Tier-1 risk-based capital ratio of 11.7%11.5% (6.0%) and a total risk-based capital ratio of 12.7%12.6% (10.0%). FRB approval is required before ASB can pay a dividend or otherwise make a capital distribution to HEI (through ASHI).
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 pages 74 to 76, HEI’s and Hawaiian Electric’s Quantitative and Qualitative Disclosures About Market Risk, in Part II, Item 7A of HEI’s 2013 Form 10-K.
ASB’s interest-rate risk sensitivity measures as of March 31,June 30, 2014 and December 31, 2013 constitute “forward-looking statements” and were as follows:
 
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)
Change in interest rates
(basis points)
 March 31, 2014 December 31, 2013 March 31, 2014 December 31, 2013 June 30, 2014 December 31, 2013 June 30, 2014 December 31, 2013
+300 2.1% 1.3% (9.3)% (10.7)% 1.6% 1.3% (10.2)% (10.7)%
+200 0.9
 0.3
 (5.7) (6.9) 0.6
 0.3
 (6.1) (6.9)
+100 0.2
 —
 (2.5) (3.3) 0.1
 —
 (2.5) (3.3)
-100 (0.5) (0.5) (0.4) 0.6
 (0.5) (0.5) (0.8) 0.6
 Management believes that ASB’s interest rate risk position as of March 31,June 30, 2014 represents a reasonable level of risk. The net interest income (NII) profile under the rising interest rate scenarios was more asset sensitive for all rate increases as of March 31,June 30, 2014 compared to December 31, 2013 due to changes in the mix of assets.
ASB’s base economic value of equity (EVE) was relatively flat at $903increased to $925 million as of March 31,June 30, 2014 compared to $906 million as of December 31, 2013.2013 due to the increase in capital.
The change in EVE was less sensitive in the risingincreasing rate scenarios as of March 31,June 30, 2014 compared to December 31, 2013 due to the short term increasedecrease in interest bearing deposits, the contraction of the longerlong rates resulting in a shorter duration residential mortgage portfolio,for mortgage-related assets and growth in the shortershort duration consumer and commercial loan 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.

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Item 4. Controls and Procedures
HEI:
Changes in Internal Control over Financial Reporting
During the firstsecond quarter of 2014, there were no changes in internal control over financial reporting identified in connection with management’s evaluation of the effectiveness of the Company’s internal control over financial reporting as of March 31,June 30, 2014 that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
Constance H. Lau, HEI Chief Executive Officer, and James A. Ajello, HEI Chief Financial Officer, have evaluated the disclosure controls and procedures of HEI as of March 31,June 30, 2014. Based on their evaluations, as of March 31,June 30, 2014, they have concluded that the disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective in ensuring that information required to be disclosed by HEI in reports HEI files or submits under the Securities Exchange Act of 1934:
(1)   is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission rules and forms, and
(2)   is accumulated and communicated to HEI management, including HEI’s principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.
Hawaiian Electric:
Changes in Internal Control over Financial Reporting
During the firstsecond quarter of 2014, there were no changes in internal control over financial reporting identified in connection with management’s evaluation of the effectiveness of Hawaiian Electric and its subsidiaries’ internal control over financial reporting as of March 31,June 30, 2014 that has materially affected, or is reasonably likely to materially affect, Hawaiian Electric and its subsidiaries’ internal control over financial reporting.
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
Richard M. Rosenblum, Hawaiian Electric Chief Executive Officer, and Tayne S. Y. Sekimura, Hawaiian Electric Chief Financial Officer, have evaluated the disclosure controls and procedures of Hawaiian Electric as of March 31,June 30, 2014. Based on their evaluations, as of March 31,June 30, 2014, they have concluded that the disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) were effective in ensuring that information required to be disclosed by Hawaiian Electric in reports Hawaiian Electric files or submits under the Securities Exchange Act of 1934:
(1)        is recorded, processed, summarized, and reported within the time periods specified in the Securities and Exchange Commission rules and forms, and
(2)        is accumulated and communicated to Hawaiian Electric management, including Hawaiian Electric’s principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure.


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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 2013 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 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 and ASB) 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 24 to 32 of HEI’s and Hawaiian Electric's 2013 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 Consolidated Financial Statements herein. Also, see “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 during the first quarter to satisfy the requirements of certain plans as follows:
ISSUER PURCHASES OF EQUITY SECURITIES
Period*
(a)
Total Number of Shares Purchased **
 (b)
Average
Price Paid
per Share **
 (c)
 Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
 (d)
Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
(a)
Total Number of Shares Purchased **
 (b)
Average
Price Paid
per Share **
 (c)
 Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
 (d)
Maximum Number (or Approximate Dollar Value) of Shares that May Yet Be Purchased Under the Plans or Programs
March 6 to 31, 2014333,020
$24.66
—
NA
April 1 to 30, 201488,795
$24.47—
NA
May 1 to 31, 201469,705
$24.10—
NA
June 1 to 30, 2014325,283
$24.41—
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 shares listed in column (a), 296,86082,895 of the 333,02088,795 shares, all of the 69,705 shares and 297,783 of the 325,283 shares were purchased for the DRIP, 30,7005,900 of the 333,02088,795 shares, none of the 69,705 shares and 22,500 of the 325,283 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.
Three months  
 ended March 31		 Years ended December 31Six months  
 ended June 30		 Years ended December 31
2014 2013 2013 2012 2011 2010 20092014 2013 2013 2012 2011 2010 2009
HEI and Subsidiaries 
  
  
  
  
  
  
 
  
  
  
  
  
  
Excluding interest on ASB deposits3.84
 3.15
 3.53
 3.28
 3.22
 2.89
 2.29
3.76
 3.41
 3.53
 3.28
 3.22
 2.89
 2.29
Including interest on ASB deposits3.71
 3.03
 3.40
 3.14
 3.03
 2.64
 1.95
3.63
 3.28
 3.40
 3.14
 3.03
 2.64
 1.95
Hawaiian Electric and Subsidiaries4.07
 3.21
 3.72
 3.37
 3.52
 2.88
 2.99
4.06
 3.45
 3.72
 3.37
 3.52
 2.88
 2.99
 See HEI Exhibit 12.1 and Hawaiian Electric Exhibit 12.2.
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Item 6. Exhibits
 
HEI Exhibit 4Loan Agreement dated as of May 2, 2014 among HEI, as Borrower, the Lenders Party Thereto and Royal Bank of Canada, as Syndication Agent, and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Administrative Agent, and The Bank of Tokyo-Mitsubishi UFJ, Ltd. and RBC Capital Markets, as Joint Lead Arrangers and Joint Book Runners
HEI Exhibit 12.1 
Hawaiian Electric Industries, Inc. and Subsidiaries
Computation of ratio of earnings to fixed charges, threesix months ended March 31,June 30, 2014 and 2013 and years ended December 31, 2013, 2012, 2011, 2010 and 2009
   
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 James A. Ajello (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 12.2 
Hawaiian Electric Company, Inc. and Subsidiaries
Computation of ratio of earnings to fixed charges, threesix months ended March 31,June 30, 2014 and 2013 and years ended December 31, 2013, 2012, 2011, 2010 and 2009
   
Hawaiian Electric Exhibit 31.3 Certification Pursuant to Rule 13a-14 promulgated under the Securities Exchange Act of 1934 of Richard M. Rosenblum (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


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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/ Richard M. Rosenblum
 Constance H. Lau  Richard M. Rosenblum
 President and Chief Executive Officer  President and Chief Executive Officer
 (Principal Executive Officer of HEI)  (Principal Executive Officer of Hawaiian Electric)
   
   
By/s/ James A. Ajello By/s/ Tayne S. Y. Sekimura
 James A. Ajello  Tayne S. Y. Sekimura
 Executive Vice President and  Senior Vice President
 Chief Financial Officer  and Chief Financial Officer
 (Principal Financial and Accounting  (Principal Financial Officer of Hawaiian Electric)
 Officer of HEI)  
   
   
Date: May 7,August 11, 2014 Date: May 7,August 11, 2014


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