##### Table of Contents

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549



FORM 10-K



|x | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
|- | ------------------------------------------------------------------------------------



For the fiscal year ended December 31, 2003



OR



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



|                      |  |                                                                                                                                     |  |                                   
|--------------------- |  | ----------------------------------------------------------------------------------------------------------------------------------- |  | ----------------------------------
|CommissionFile Number |  | Registrant; State of Incorporation;Address; and Telephone Number                                                                    |  | I.R.S. Employer Identification No.
|1-8503                |  | HAWAIIAN ELECTRIC INDUSTRIES, INC., a Hawaii corporation (HEI) 900 Richards Street, Honolulu, Hawaii 96813 Telephone (808) 543-5662 |  | 99-0208097                        
|1-4955                |  | HAWAIIAN ELECTRIC COMPANY, INC., a Hawaii corporation (HECO) 900 Richards Street, Honolulu, Hawaii 96813 Telephone (808) 543-7771   |  | 99-0040500                        



Securities
registered pursuant to Section 12(b) of the Act:



|                                   |  |                                                                                                       |  |                                         
|---------------------------------- |  | ----------------------------------------------------------------------------------------------------- |  | ----------------------------------------
|Registrant                         |  | Title of each class                                                                                   |  | Name of each exchangeon which registered
|Hawaiian Electric Industries, Inc. |  | Common Stock, Without Par Value                                                                       |  | New York Stock Exchange                 
|Hawaiian Electric Industries, Inc. |  | Guarantee with respect to 8.36% Trust Originated Preferred SecuritiesSM(TOPrSSM)                      |  | New York Stock Exchange                 
|Hawaiian Electric Industries, Inc. |  | Preferred Stock Purchase Rights                                                                       |  | New York Stock Exchange                 
|Hawaiian Electric Company, Inc.    |  | Guarantee with respect to 8.05% Cumulative Quarterly Income Preferred SecuritiesSeries 1997 (QUIPSSM) |  | New York Stock Exchange                 
|Hawaiian Electric Company, Inc.    |  | Guarantee with respect to 7.30% Cumulative Quarterly Income Preferred SecuritiesSeries 1998 (QUIPSSM) |  | New York Stock Exchange                 



Securities
registered pursuant to Section 12(g) of the Act:



|                                   |  |                           
|---------------------------------- |  | --------------------------
|Registrant                         |  | Title of each class       
|Hawaiian Electric Industries, Inc. |  | None                      
|Hawaiian Electric Company, Inc.    |  | Cumulative Preferred Stock



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. Yes x No ̈



Indicate by check mark if disclosure of delinquent filers pursuant to Item
405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrants knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form
10-K. x



Indicate by check
mark whether Registrant Hawaiian Electric Industries, Inc. is an accelerated filer (as defined in Rule 12b-2 of the Act). Yes x No ̈



Indicate by check
mark whether Registrant Hawaiian Electric Company, Inc. is an accelerated filer (as defined in Rule 12b-2 of the Act). Yes ̈No x



|                                         |  |                                                                                                           |  |                                                                              
|---------------------------------------- |  | --------------------------------------------------------------------------------------------------------- |  | -----------------------------------------------------------------------------
|                                         |  | Aggregate market value ofthe voting common equityheld by non-affiliates of theregistrants onJune 30, 2003 |  | Number of shares of
common stockoutstanding of theregistrants onMarch 1, 2004
|Hawaiian Electric Industries, Inc. (HEI) |  | $1,715,658,628.25                                                                                         |  | 38,032,319 (Without par value)                                               
|                                         |  |                                                                                                          
|Hawaiian Electric Company, Inc. (HECO)   |  | Not applicable                                                                                            |  | 12,805,843 ($6 2/3 par value)                                                



DOCUMENTS
INCORPORATED BY REFERENCE



HEI Annual Report to Shareholders for the fiscal
year ended December 31, 2003Parts I, II, III and IV



HECO Consolidated
2003 Financial StatementsParts I, II, III and IV



Portions of Proxy
Statement of Hawaiian Electric Industries, Inc., dated March 9, 2004 for the 2004 Annual Meeting of ShareholdersPart III



This combined Form 10-K represents separate filings by Hawaiian Electric Industries, Inc. and Hawaiian Electric Company, Inc. Information contained herein relating to
any individual registrant is filed by each registrant on its own behalf. Neither registrant makes any representations as to the information relating to the other registrant.



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##### Table of Contents



TABLE OF CONTENTS



|                                                                          |  |                                                                                       |  |     
|------------------------------------------------------------------------- |  | ------------------------------------------------------------------------------------- |  | ----
|                                                                          |  |                                                                                       |  | Page
|Glossary of Terms                                                         |  | ii                                                                                   
|Forward-Looking Statements and Risk Factors                               |  | vi                                                                                   
|                                                                          | 
|PART I                                                                    |  |                                                                                      
|                                                                          |  |                                                                                      
|Item 1.                                                                   |  | Business                                                                              |  | 1   
|Item 2.                                                                   |  | Properties                                                                            |  | 44  
|Item 3.                                                                   |  | Legal Proceedings                                                                     |  | 45  
|Item 4.                                                                   |  | Submission of Matters to a Vote of Security Holders                                   |  | 46  
|Executive Officers of the Registrant (Hawaiian Electric Industries, Inc.) |  | 46                                                                                   
|                                                                          | 
|PART II                                                                   |  |                                                                                      
|                                                                          |  |                                                                                      
|Item 5.                                                                   |  | Market for Registrants Common Equity and Related Stockholder Matters                 |  | 47  
|Item 6.                                                                   |  | Selected Financial Data                                                               |  | 48  
|Item 7.                                                                   |  | Managements Discussion and Analysis of Financial Condition and Results of Operations |  | 50  
|Item 7A.                                                                  |  | Quantitative and Qualitative Disclosures about Market Risk                            |  | 68  
|Item 8.                                                                   |  | Financial Statements and Supplementary Data                                           |  | 68  
|Item 9.                                                                   |  | Changes in and Disagreements with Accountants on Accounting and Financial Disclosure  |  | 68  
|Item 9A.                                                                  |  | Controls and Procedures                                                               |  | 68  
|                                                                          | 
|PART III                                                                  |  |                                                                                      
|                                                                          |  |                                                                                      
|Item 10.                                                                  |  | Directors and Executive Officers of the Registrants                                   |  | 69  
|Item 11.                                                                  |  | Executive Compensation                                                                |  | 73  
|Item 12.                                                                  |  | Security Ownership of Certain Beneficial Owners and Management                        |  | 77  
|Item 13.                                                                  |  | Certain Relationships and Related Transactions                                        |  | 78  
|Item 14.                                                                  |  | Principal Accounting Fees and Services                                                |  | 78  
|                                                                          | 
|PART IV                                                                   |  |                                                                                      
|                                                                          |  |                                                                                      
|Item 15.                                                                  |  | Exhibits, Financial Statement Schedules, and Reports on Form 8-K                      |  | 79  
|Independent Auditors Report - Hawaiian Electric Industries, Inc.         |  | 81                                                                                   
|Independent Auditors Report - Hawaiian Electric Company, Inc.            |  | 82                                                                                   
|Index to Exhibits                                                         |  | 87                                                                                   
|Signatures                                                                |  | 115                                                                                  



i



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##### Table of Contents

GLOSSARY OF TERMS



Defined below are certain terms
used in this report:



|                  |  |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                          
|----------------- |  | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Terms             |  | Definitions                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              
|                  | 
|1935 Act          |  | Public Utility Holding Company Act of 1935                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                               
|                  | 
|AES Hawaii        |  | AES Hawaii, Inc., formerly known as AES Barbers Point, Inc.                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              
|                  | 
|ASB               |  | American Savings Bank, F.S.B., a wholly-owned subsidiary of HEI Diversified, Inc. and parent company of American Savings Investment Services
Corp. (and its subsidiary since March 15, 2001, Bishop Insurance Agency of Hawaii, Inc.), ASB Service Corporation (dissolved in January 2004), AdCommunications, Inc., American Savings Mortgage Co., Inc. (dissolved in July 2003), and ASB Realty
Corporation                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                             
|                  | 
|BIF               |  | Bank Insurance Fund                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                      
|                  | 
|BLNR              |  | Board of Land and Natural Resources of the State of Hawaii                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                               
|                  | 
|Btu               |  | British thermal unit                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                     
|                  | 
|CDUP              |  | Conservation District Use Permit                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                         
|                  | 
|CERCLA            |  | Comprehensive Environmental Response, Compensation and Liability Act                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                     
|                  | 
|Chevron           |  | Chevron Products Company, a fuel oil supplier                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                            
|                  | 
|Company           |  | When used in Hawaiian Electric Industries, Inc. sections, the Company refers to Hawaiian
Electric Industries, Inc. and its direct and indirect subsidiaries, including, without limitation, Hawaiian Electric Company, Inc., Maui Electric Company, Limited, Hawaii Electric Light Company, Inc., HECO Capital Trust I, HECO Capital Trust II,
HECO Capital Trust III, Renewable Hawaii, Inc., HEI Diversified, Inc., American Savings Bank, F.S.B. and its subsidiaries, Pacific Energy Conservation Services, Inc., HEI District Cooling, Inc. (dissolved in October 2003), ProVision Technologies,
Inc. (sold in July 2003), HEI Properties, Inc., HEI Leasing, Inc. (dissolved in October 2003), Hycap Management, Inc., Hawaiian Electric Industries Capital Trust I, Hawaiian Electric Industries Capital Trust II, Hawaiian Electric Industries Capital
Trust III, HEI Preferred Funding, LP, The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.), HEI Power Corp. and its subsidiaries and Malama Pacific Corp. When used in Hawaiian Electric Company, Inc. sections, the Company refers to Hawaiian Electric Company, Inc. and its
direct subsidiaries, including, without limitation, Maui Electric Company, Limited, Hawaii Electric Light Company, Inc., HECO Capital Trust I, HECO Capital Trust II, HECO Capital Trust III and Renewable Hawaii, Inc.
|                  | 
|Consumer Advocate |  | Division of Consumer Advocacy, Department of Commerce and Consumer Affairs of the State of Hawaii                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                        
|                  | 
|CT                |  | Combustion turbine                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                       
|                  | 
|DLNR              |  | Department of Land and Natural Resources of the State of Hawaii                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                          
|                  | 
|D&O               |  | Decision and order                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                       
|                  | 
|DOD               |  | Department of Defense  federal                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                          
|                  | 
|DOH               |  | Department of Health of the State of Hawaii                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              
|                  | 
|DSM               |  | Demand-side management                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                   
|                  | 
|DTCC              |  | Dual-train combined-cycle                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                
|                  | 
|EAPRC             |  | East Asia Power Resources Corporation                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                    
|                  | 
|ECA               |  | Energy cost adjustment                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                   
|                  | 
|Enserch           |  | Enserch Development Corporation                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                          
|                  | 
|EPA               |  | Environmental Protection Agency  federal                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                



ii



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##### Table of Contents

GLOSSARY OF TERMS(continued)



|                                      |  |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                    
|------------------------------------- |  | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Terms                                 |  | Definitions                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                        
|                                      | 
|ERL                                   |  | Environmental Response Law of the State of Hawaii                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                  
|                                      | 
|FDIC                                  |  | Federal Deposit Insurance Corporation                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              
|                                      | 
|FDICIA                                |  | Federal Deposit Insurance Corporation Improvement Act of 1991                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                      
|                                      | 
|federal                               |  | U.S. Government                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                    
|                                      | 
|FHLB                                  |  | Federal Home Loan Bank                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                             
|                                      | 
|FICO                                  |  | Financing Corporation                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              
|                                      | 
|FIRREA                                |  | Financial Institutions Reform, Recovery, and Enforcement Act of 1989                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                               
|                                      | 
|Hamakua Partners                      |  | Hamakua Energy Partners, L.P., formerly known as Encogen Hawaii, L.P.                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                              
|                                      | 
|HRD                                   |  | Hawi Renewable Development, Inc.                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                   
|                                      | 
|HCPC                                  |  | Hilo Coast Power Company, formerly Hilo Coast Processing Company                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                   
|                                      | 
|HC&S                                  |  | Hawaiian Commercial & Sugar Company, a division of A&B-Hawaii, Inc.                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                
|                                      | 
|HECO                                  |  | Hawaiian Electric Company, Inc., an electric utility subsidiary of Hawaiian Electric Industries, Inc. and parent company of Maui Electric
Company, Limited, Hawaii Electric Light Company, Inc., HECO Capital Trust I, HECO Capital Trust II, HECO Capital Trust III and Renewable Hawaii, Inc.                                                                                                                                                                                                                                                                                                                                    
|                                      | 
|HECOsConsolidatedFinancialStatements |  | Hawaiian Electric Company, Inc.s Consolidated Financial Statements incorporated into Parts I, II and IV of this Form 10-K, which is
filed as HECO Exhibit 99.4 and incorporated into this Form 10-K by reference                                                                                                                                                                                                                                                                                                                                                                                                                  
|                                      | 
|HECOs MD&A                           |  | Hawaiian Electric Company, Inc.s Managements Discussion and Analysis of Financial Condition and Results of Operations on pages 50
to 67 of this Form 10-K                                                                                                                                                                                                                                                                                                                                                                                                                                                                        
|                                      | 
|HEI                                   |  | Hawaiian Electric Industries, Inc., direct parent company of Hawaiian Electric Company, Inc., HEI Diversified, Inc., Pacific Energy
Conservation Services, Inc., HEI District Cooling, Inc. (dissolved in October 2003), ProVision Technologies, Inc. (sold in July 2003), HEI Properties, Inc., HEI Leasing, Inc. (dissolved in October 2003), Hycap Management, Inc., Hawaiian Electric
Industries Capital Trust I, Hawaiian Electric Industries Capital Trust II, Hawaiian Electric Industries Capital Trust III, The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.), HEI Power Corp. and Malama Pacific
Corp.
|                                      | 
|HEIsAnnual Report                    |  | Hawaiian Electric Industries, Inc.s 2003 Annual Report to Shareholders, which is filed as HEI Exhibit 13 and incorporated into this Form
10-K by reference                                                                                                                                                                                                                                                                                                                                                                                                                                                                        
|                                      | 
|HEIsConsolidatedFinancialStatements  |  | Hawaiian Electric Industries, Inc.s Consolidated Financial Statements incorporated into Parts I, II and IV of this Form 10-K by
reference to pages 39 to 88 of HEIs Annual Report                                                                                                                                                                                                                                                                                                                                                                                                                                                
|                                      | 
|HEIs MD&A                            |  | Hawaiian Electric Industries, Inc.s Managements Discussion and Analysis of Financial Condition and Results of Operations
incorporated into Parts I, II and IV of this Form 10-K by reference to pages 4 to 35 of HEIs Annual Report                                                                                                                                                                                                                                                                                                                                                                                             
|                                      | 
|HEIs 2004 ProxyStatement             |  | Portions of Hawaiian Electric Industries, Inc.s 2004 Proxy Statement dated March 9, 2004, which portions are incorporated into this Form
10-K by reference                                                                                                                                                                                                                                                                                                                                                                                                                                                                        
|                                      | 
|HEIDI                                 |  | HEI Diversified, Inc., a wholly-owned subsidiary of Hawaiian Electric Industries, Inc. and the parent company of American Savings Bank,
F.S.B.                                                                                                                                                                                                                                                                                                                                                                                                                                                                                     



iii



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##### Table of Contents

GLOSSARY OF TERMS(continued)



|            |  |                                                                                                                                                                                                                                                                                                                                                                      
|----------- |  | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Terms       |  | Definitions                                                                                                                                                                                                                                                                                                                                                          
|            | 
|HEIII       |  | HEI Investments, Inc. (formerly HEI Investment Corp.), a wholly-owned subsidiary of HEI Power Corp.                                                                                                                                                                                                                                                                  
|            | 
|HEIPC       |  | HEI Power Corp., a wholly owned subsidiary of Hawaiian Electric Industries, Inc., and the parent company of numerous subsidiaries, several of
which were dissolved or otherwise wound up in 2002 and 2003. On October 23, 2001, the HEI Board of Directors adopted a formal plan to exit the international power business (engaged in by HEIPC and its subsidiaries).
|            | 
|HEIPC Group |  | HEI Power Corp. and its subsidiaries                                                                                                                                                                                                                                                                                                                                 
|            | 
|HEIPI       |  | HEI Properties, Inc., a wholly-owned subsidiary of Hawaiian Electric Industries, Inc.                                                                                                                                                                                                                                                                                
|            | 
|HELCO       |  | Hawaii Electric Light Company, Inc., an electric utility subsidiary of Hawaiian Electric Company, Inc.                                                                                                                                                                                                                                                               
|            | 
|HITI        |  | Hawaiian Interisland Towing, Inc.                                                                                                                                                                                                                                                                                                                                    
|            | 
|HTB         |  | Hawaiian Tug & Barge Corp. On November 10, 1999, HTB sold substantially all of its operating assets and the stock of Young Brothers,
Limited, and changed its name to The Old Oahu Tug Services, Inc.                                                                                                                                                                
|            | 
|IPP         |  | Independent power producer                                                                                                                                                                                                                                                                                                                                           
|            | 
|IRP         |  | Integrated resource plan                                                                                                                                                                                                                                                                                                                                             
|            | 
|Kalaeloa    |  | Kalaeloa Partners, L.P.                                                                                                                                                                                                                                                                                                                                              
|            | 
|KCP         |  | Kawaihae Cogeneration Partners                                                                                                                                                                                                                                                                                                                                       
|            | 
|KDC         |  | Keahole Defense Coalition                                                                                                                                                                                                                                                                                                                                            
|            | 
|kV          |  | kilovolt                                                                                                                                                                                                                                                                                                                                                             
|            | 
|KIP         |  | Kalaeloa Investment Partners                                                                                                                                                                                                                                                                                                                                         
|            | 
|KPP         |  | Kahua Power Partners LLC                                                                                                                                                                                                                                                                                                                                             
|            | 
|KWH         |  | Kilowatthour                                                                                                                                                                                                                                                                                                                                                         
|            | 
|LSFO        |  | Low sulfur fuel oil                                                                                                                                                                                                                                                                                                                                                  
|            | 
|MBtu        |  | Million British thermal unit                                                                                                                                                                                                                                                                                                                                         
|            | 
|MECO        |  | Maui Electric Company, Limited, an electric utility subsidiary of Hawaiian Electric Company, Inc.                                                                                                                                                                                                                                                                    
|            | 
|MPC         |  | Malama Pacific Corp., a wholly-owned subsidiary of Hawaiian Electric Industries, Inc. On September 14, 1998, the HEI Board of Directors
adopted a plan to exit the residential real estate development business engaged in by Malama Pacific Corp. and its then-existing subsidiaries. As of December 31, 2003, all of its subsidiaries had been dissolved.          
|            | 
|MSFO        |  | Medium sulfur fuel oil                                                                                                                                                                                                                                                                                                                                               
|            | 
|MW          |  | Megawatts                                                                                                                                                                                                                                                                                                                                                            
|            | 
|NA          |  | Not applicable                                                                                                                                                                                                                                                                                                                                                       
|            | 
|NM          |  | Not meaningful                                                                                                                                                                                                                                                                                                                                                       
|            | 
|NOV         |  | Notice of Violation                                                                                                                                                                                                                                                                                                                                                  
|            | 
|OPA         |  | Federal Oil Pollution Act of 1990                                                                                                                                                                                                                                                                                                                                    
|            | 
|OTS         |  | Office of Thrift Supervision, Department of Treasury                                                                                                                                                                                                                                                                                                                 
|            | 
|PCB         |  | Polychlorinated biphenyls                                                                                                                                                                                                                                                                                                                                            



iv



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##### Table of Contents

GLOSSARY OF TERMS(continued)



|           |  |                                                                                                                                                                                                                                                           
|---------- |  | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Terms      |  | Definitions                                                                                                                                                                                                                                               
|           | 
|PECS       |  | Pacific Energy Conservation Services, Inc., a wholly-owned subsidiary of Hawaiian Electric Industries, Inc.                                                                                                                                               
|           | 
|PGV        |  | Puna Geothermal Venture                                                                                                                                                                                                                                   
|           | 
|PPA        |  | Power purchase agreement                                                                                                                                                                                                                                  
|           | 
|PSD permit |  | Prevention of Significant Deterioration/Covered Source permit                                                                                                                                                                                             
|           | 
|PUC        |  | Public Utilities Commission of the State of Hawaii                                                                                                                                                                                                        
|           | 
|PURPA      |  | Public Utility Regulatory Policies Act of 1978                                                                                                                                                                                                            
|           | 
|QF         |  | Qualifying Facility under the Public Utility Regulatory Policies Act of 1978                                                                                                                                                                              
|           | 
|QTL        |  | Qualified Thrift Lender                                                                                                                                                                                                                                   
|           | 
|RCRA       |  | Resource Conservation and Recovery Act of 1976                                                                                                                                                                                                            
|           | 
|Registrant |  | Hawaiian Electric Industries, Inc. or Hawaiian Electric Company, Inc.                                                                                                                                                                                     
|           | 
|ROACE      |  | Return on average common equity                                                                                                                                                                                                                           
|           | 
|SAIF       |  | Savings Association Insurance Fund                                                                                                                                                                                                                        
|           | 
|SEC        |  | Securities and Exchange Commission                                                                                                                                                                                                                        
|           | 
|ST         |  | Steam turbine                                                                                                                                                                                                                                             
|           | 
|state      |  | State of Hawaii                                                                                                                                                                                                                                           
|           | 
|Tesoro     |  | Tesoro Hawaii Corp. dba BHP Petroleum Americas Refining Inc., a fuel oil supplier                                                                                                                                                                         
|           | 
|TOOTS      |  | The Old Oahu Tug Service, Inc. (formerly Hawaiian Tug & Barge Corp.), a wholly-owned subsidiary of Hawaiian Electric Industries, Inc. On
November 10, 1999, HTB sold the stock of YB and substantially all of HTBs operating assets and changed its name.
|           | 
|UIC        |  | Underground Injection Control                                                                                                                                                                                                                             
|           | 
|UST        |  | Underground storage tank                                                                                                                                                                                                                                  
|           | 
|VIE        |  | Variable interest entities                                                                                                                                                                                                                                
|           | 
|YB         |  | Young Brothers, Limited, which was sold on November 10, 1999, was formerly a wholly-owned subsidiary of Hawaiian Tug & Barge
Corp.                                                                                                                        



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##### Table of Contents

Forward-Looking Statements and Risk Factors



This report and other presentations made by Hawaiian Electric Industries, Inc. (HEI) and Hawaiian Electric Company, Inc. (HECO) 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 (including future revenues, expenses, earnings or losses or growth rates), ongoing business strategies or prospects and possible future
actions, which may be provided by management, 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 (including HECO and its subsidiaries), the performance of the industries in which they do business and economic and market factors, among other things. These forward-lookingstatements are
not guarantees of future performance.



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



| |  | the effects of international, national and local economic conditions, including the state of the Hawaii tourist and construction industries, the strength or weakness of the Hawaii
and continental U.S. housing markets, the military presence in Hawaii and the effects of the February 2004 strike in the Hawaii concrete industry;
| | - | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| |  | the effects of weather and natural disasters;
| | - | ---------------------------------------------



| |  | global developments, including the effects of terrorist acts, the war on terrorism, continuing U.S. presence in Iraq and Afghanistan and potential conflict or crisis with North
Korea;
| | - | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| |  | the timing and extent of changes in interest rates;
| | - | ---------------------------------------------------



| |  | the risks inherent in changes in the value of and market for securities available for sale and pension and other retirement plan assets;
| | - | ----------------------------------------------------------------------------------------------------------------------------------------



| |  | changes in assumptions used to calculate retirement benefits costs and changes in funding requirements;
| | - | -------------------------------------------------------------------------------------------------------



| |  | demand for services and market acceptance risks;
| | - | ------------------------------------------------



| |  | increasing competition in the electric utility and banking industries;
| | - | ----------------------------------------------------------------------



| |  | capacity and supply constraints or difficulties;
| | - | ------------------------------------------------



| |  | fuel oil price changes, performance by suppliers of their fuel oil delivery obligations and the continued availability to the electric utilities of their energy cost adjustment
clauses;
| | - | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| |  | the ability of independent power producers to deliver the firm capacity anticipated in their power purchase agreements;
| | - | -----------------------------------------------------------------------------------------------------------------------



| |  | the ability of the electric utilities to negotiate, periodically, favorable collective bargaining agreements;
| | - | -------------------------------------------------------------------------------------------------------------



| |  | new technological developments that could affect the operations and prospects of HEIs subsidiaries (including HECO and its subsidiaries) or their competitors;
| | - | ---------------------------------------------------------------------------------------------------------------------------------------------------------------



| |  | federal, state and international governmental and regulatory actions, such as changes in laws, rules and regulations applicable to HEI, HECO and their subsidiaries (including
changes in taxation and governmental fees and assessments); decisions by the Hawaii Public Utilities Commission (PUC) in rate cases and other proceedings and by other agencies and courts on land use, environmental and other permitting issues;
required corrective actions (such as with respect to environmental conditions, capital adequacy and business practices);
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| |  | the risks associated with the geographic concentration of HEIs businesses;
| | - | ---------------------------------------------------------------------------



| |  | the effects of changes in accounting principles applicable to HEI, HECO and their subsidiaries, including the possible effects of applying new accounting principles applicable to
variable interest entities (VIEs) to power purchase arrangements with independent power producers;
| | - | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| |  | the effects of changes by securities rating agencies in the ratings of the securities of HEI and HECO;
| | - | ------------------------------------------------------------------------------------------------------



| |  | 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 rights of
American Savings Bank, F.S.B. (ASB);
| | - | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| |  | the ultimate net proceeds from the disposition of assets and settlement of liabilities of discontinued or sold operations;
| | - | --------------------------------------------------------------------------------------------------------------------------



| |  | the final outcome of tax positions taken by HEI and its subsidiaries, including with respect to ASBs real estate investment trust subsidiary;
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------



| |  | the risks of suffering losses that are uninsured; and
| | - | -----------------------------------------------------



| |  | other risks or uncertainties described elsewhere in this report and in other periodic reports previously and subsequently filed by HEI and/or HECO 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 and its subsidiaries undertake no obligation to publicly update or revise any forward-looking
statements, whether as a result of new information, future events or otherwise.



vi



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##### Table of Contents

PART I



|ITEM 1. | BUSINESS
|------- | --------



HEI



HEI was
incorporated in 1981 under the laws of the State of Hawaii and is a holding company with its principal subsidiaries engaged in the electric utility, banking and other businesses operating primarily in the State of Hawaii. HEIs predecessor,
HECO, was incorporated under the laws of the Kingdom of Hawaii (now the State of Hawaii) on October 13, 1891. As a result of a 1983 corporate reorganization, HECO became an HEI subsidiary and common shareholders of HECO became common shareholders of
HEI.



HECO and its operating subsidiaries, Maui Electric
Company, Limited (MECO) and Hawaii Electric Light Company, Inc. (HELCO), are regulated electric public utilities providing the only electric public utility service on the islands of Oahu, Maui, Lanai, Molokai and Hawaii, which islands collectively
include approximately 93% of Hawaiis electric public utility market. HECO also owns all the common securities of HECO Capital Trust I, HECO Capital Trust II and HECO Capital Trust III (Delaware statutory trusts), which were formed to effect
the issuances of $50 million of 8.05% cumulative quarterly income preferred securities in March 1997 (expected to be redeemed in the first half of 2004), $50 million of 7.30% cumulative quarterly income preferred securities in December 1998 and an
anticipated $50 million of cumulative quarterly income preferred securities in the first half of 2004 (the proceeds of which will be used to redeem the preferred securities issued by HECO Capital Trust I), respectively, for the benefit of HECO, MECO
and HELCO. In December 2002, HECO formed a subsidiary, Renewable Hawaii, Inc., to invest in renewable energy projects.



Besides HECO and its subsidiaries, HEI also owns directly or indirectly the following subsidiaries: HEI Diversified, Inc. (HEIDI) (a holding company) and
its subsidiary, ASB, and the subsidiaries of ASB; Pacific Energy Conservation Services, Inc. (PECS); ProVision Technologies, Inc. (sold in July 2003); HEI Properties, Inc. (HEIPI); HEI Leasing, Inc. (dissolved in October 2003); Hycap Management,
Inc. and its subsidiary; Hawaiian Electric Industries Capital Trust I; Hawaiian Electric Industries Capital Trust II and III (formed in 1997 to be available for trust securities financings); HEI District Cooling, Inc. (dissolved in October 2003);
The Old Oahu Tug Service, Inc. (TOOTS); HEI Power Corp. (HEIPC) and its subsidiaries (discontinued operations); and Malama Pacific Corp. (MPC) (discontinued operations).



ASB, acquired in 1988, was the third largest financial institution in the State of Hawaii based on total assets and had 68
retail branches as of December 31, 2003. ASB has subsidiaries involved in the sale and distribution of insurance products and advertising activities for ASB and its subsidiaries and a subsidiary, ASB Realty Corporation, which elects to be taxed as a
real estate investment trust and holds assets (primarily loans and mortgage-related securities) of $1.8 billion (see Note 9 to HEIs Consolidated Financial Statements).



HEIDI was also the parent company of HEIDI Real Estate Corp., which was formed in February 1998. In September 1999, HEIDI
Real Estate Corp.s name was changed to HEIPI, and HEIDI transferred ownership of HEIPI to HEI. HEIPI currently holds venture capital investments.



PECS was formed in 1994 and currently is a contract services company providing limited support services in Hawaii. ProVision Technologies, Inc., formed in
October 1998 to sell, install, operate and maintain on-site power generation equipment and auxiliary appliances in Hawaii and the Pacific Rim, was sold in July 2003. HEI Leasing, Inc. was formed in February 2000 to own passive investments and real
estate subject to leases, but was never active and was dissolved in October 2003. Hycap Management, Inc., including its subsidiary HEI Preferred Funding, LP (a limited partnership in which Hycap Management, Inc. is the sole general partner), and
Hawaiian Electric Industries Capital Trust I (a Delaware statutory trust in which HEI owns all the common securities) were formed to effect the issuance of $100 million of 8.36% HEI-obligated trust preferred securities in 1997. HEI District Cooling,
Inc. was formed in August 1998 to develop, build, own, lease, operate and/or maintain, either directly or indirectly, central chilled water cooling system facilities, and other energy related products and services for commercial and residential
buildings, but was dissolved in October 2003.



In November
1999, Hawaiian Tug & Barge Corp. (HTB) sold substantially all of its operating assets and the stock of YB for a nominal gain, changed its name to TOOTS and ceased maritime freight transportation operations. TOOTS currently administers certain
employee and retiree-related benefits programs and monitors matters related its former operations and the operations of its former subsidiary.



1



---

##### Table of Contents

For information concerning a strike in the Hawaii concrete industry that has been ongoing since early
February 2004 and is adversely affecting the construction industry and Hawaii economy generally, see the discussion under the caption Overview and strategy in HECOs MD&A. If a prolonged strike significantly impacted the Hawaii
economy, the operations of the electric utilities and bank could be adversely affected.



For information about the Companys discontinued operations, see Note 13 to HEIs Consolidated Financial Statements.



For financial information about the Companys industry segments, see Note 2 to HEIs Consolidated Financial Statements.



For additional information about the Company, see HEIs MD&A,
HEIs Quantitative and Qualitative Disclosures about Market Risk and HEIs Consolidated Financial Statements.



The Companys website address is www.hei.com. HEI and HECO currently make available free of charge through this website their annual reports on Form
10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and all amendments to those reports (since 1994) as soon as reasonably practicable after such material is electronically filed with the SEC.



Electric utility



HECO and subsidiaries and service areas



HECO, MECO and HELCO are regulated operating electric public utilities engaged in the production, purchase, transmission, distribution and sale of
electricity on the islands of Oahu; Maui, Lanai and Molokai; and Hawaii, respectively. HECO was incorporated under the laws of the Kingdom of Hawaii (now State of Hawaii) in 1891. HECO acquired MECO in 1968 and HELCO in 1970. In 2003, the electric
utilities revenues and net income from continuing operations amounted to approximately 78% and 67%, respectively, of HEIs consolidated amounts, compared to approximately 76% and 76% in 2002 and approximately 75% and 82% in 2001,
respectively.



The islands of Oahu, Maui, Lanai, Molokai and
Hawaii have a combined population currently estimated at 1,197,000, or approximately 95% of the population of the State of Hawaii, and comprise a service area of 5,766 square miles. The principal communities served include Honolulu (on Oahu),
Wailuku and Kahului (on Maui) and Hilo and Kona (on Hawaii). The service areas also include numerous suburban communities, resorts, U.S. Armed Forces installations and agricultural operations.



The state has granted HECO, MECO and HELCO nonexclusive franchises, which
authorize the utilities to construct, operate and maintain facilities over and under public streets and sidewalks. HECOs franchise covers the City & County of Honolulu, MECOs franchises cover the County of Maui and the County of
Kalawao, and HELCOs franchise covers the County of Hawaii. Each of these franchises will continue in effect for an indefinite period of time until forfeited, altered, amended or repealed.



For additional information about HECO, see HEIs MD&A, HEIs
Quantitative and Qualitative Disclosures about Market Risk and HEIs Consolidated Financial Statements and HECOs MD&A, HECOs Quantitative and Qualitative Disclosures about Market Risk and HECOs
Consolidated Financial Statements.



Sales of electricity



HECO, MECO and HELCO provide the only electric public utility service on the
islands they serve. The following table sets forth the number of electric customer accounts as of December 31, 2003, 2002 and 2001 and electric sales revenues by company for each of the years then ended:



|                       |  |                  |  |                        |           |                  |         |                        |   |                  |  |                        |  |   |          
|---------------------- |  | ---------------- |  | ---------------------- | --------- | ---------------- | ------- | ---------------------- | - | ---------------- |  | ---------------------- |  | - | ---------
|                       |  | 2003             |  | 2002                   |           | 2001            
|(dollars in thousands) |  | Customeraccounts |  | Electric salesrevenues |           | Customeraccounts |         | Electric salesrevenues |   | Customeraccounts |  | Electric salesrevenues
|HECO                   |  | 286,677          |  | $                      | 960,717   |                  | 283,161 |                        | $ | 865,608          |  | 280,911                |  | $ | 882,308  
|MECO                   |  | 61,423           |  |                        | 213,806   |                  | 59,983  |                        |   | 191,029          |  | 58,840                 |  |   | 203,847  
|HELCO                  |  | 68,893           |  |                        | 213,268   |                  | 66,411  |                        |   | 191,589          |  | 65,241                 |  |   | 193,209  
|                       |  |                  |  |                        |           |                  |         |                        |   |                  |  |                        |  |   |          
|                       |  | 416,993          |  | $                      | 1,387,791 |                  | 409,555 |                        | $ | 1,248,226        |  | 404,992                |  | $ | 1,279,364
|                       |  |                  |  |                        |           |                  |         |                        |   |                  |  |                        |  |   |          



2



---

##### Table of Contents

Revenues from the sale of electricity in 2003 were from the following types of customers in the
proportions shown:



|                      |  |      |   |  |      |   |  |       |   |  |       |  
|--------------------- |  | ---- | - |  | ---- | - |  | ----- | - |  | ----- | -
|                      |  | HECO |   |  | MECO |   |  | HELCO |   |  | Total |  
|Residential           |  | 32   | % |  | 36   | % |  | 41    | % |  | 34    | %
|Commercial            |  | 32   |   |  | 35   |   |  | 41    |   |  | 34    |  
|Large light and power |  | 35   |   |  | 29   |   |  | 18    |   |  | 31    |  
|Other                 |  | 1    |   |  |     |   |  |      |   |  | 1     |  
|                      |  |      |   |  |      |   |  |       |   |  |       |  
|                      |  | 100  | % |  | 100  | % |  | 100   | % |  | 100   | %
|                      |  |      |   |  |      |   |  |       |   |  |       |  



HECO and its
subsidiaries sales are not as strongly seasonal as compared to some utilities on the mainland. The weather in Hawaii is temperate, and has neither the cold winters nor the hot humid summers experienced in some parts of the mainland. Any seasonal
variation in HECO and its subsidiaries sales is due largely to weather, with warm summers causing an increase in cooling demand. Hawaiis economic activity throughout the year is relatively steady, although, generally, the summer months (June
through August) and the winter months (December, January and February) see the most visitors to the islands, and result in an increase in demand for electricity.



HECO and its subsidiaries derived approximately 10%, 9% and 10% of their operating revenues from the sale of electricity to
various federal government agencies in 2003, 2002 and 2001, respectively.



Formerly one of HECOs larger customers, the Naval Base at Barbers Point, Oahu, closed in 1999 with redevelopment of the base to occur through 2020. Considering (1) that the base closure necessitated relocation
of essential flight operations and support personnel to another base on Oahu and (2) the Naval Air Station Barbers Point Community Redevelopment Plan will increase development of the area, HECO continues to expect that the closure is likely to
result in an overall increase in demand for electricity over time.



In 1995, HECO and the U.S. General Services Administration (GSA) entered into a Basic Ordering Agreement (GSA-BOA) under which HECO would arrange for the financing and installation of energy conservation projects at federal facilities in
Hawaii. In 1996, HECO signed an umbrella Basic Ordering Agreement with the Department of Defense (DOD-BOA) and in 2001, a new DOD-BOA was signed. In 1997, HECO and the U.S. Postal Service signed a Shared Energy Savings Contract. Under these and
other agreements, HECO has completed energy conservation and other projects for federal agencies over the years.



Executive Order 13123, adopted in 1994, mandates that each federal agency develop and implement a program to reduce energy consumption by 35% by the year
2010 to the extent that these measures are cost effective. The 35% reduction will be measured relative to the agencys 1985 energy use. HECO continues to work with various federal agencies to implement demand-side management (DSM) programs that
will help them achieve their energy reduction objectives. Neither HEI nor HECO management can predict with certainty the impact of Executive Order 13123 on HEIs or HECOs future financial condition, results of operations or liquidity.



3



---

##### Table of Contents

Selected consolidated electric utility operating statistics



|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|--------------------------------------------- |  | ---- | --------- | ---- | - | --------- |  | ---- | --------- | ---- | - | --------- |  | - | ---------
|                                              |  | 2003 |           | 2002 |   | 2001      |  | 2000 |           | 1999
|KWH sales (millions)                          |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Residential                                   |  |      | 2,875.9   |      |   | 2,778.5   |  |      | 2,665.2   |      |   | 2,627.2   |  |   | 2,550.5  
|Commercial                                    |  |      | 3,168.3   |      |   | 3,073.6   |  |      | 3,016.1   |      |   | 2,923.5   |  |   | 2,781.5  
|Large light and power                         |  |      | 3,676.5   |      |   | 3,639.2   |  |      | 3,636.5   |      |   | 3,666.9   |  |   | 3,598.3  
|Other                                         |  |      | 54.4      |      |   | 53.0      |  |      | 52.6      |      |   | 54.1      |  |   | 54.7     
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  |      | 9,775.1   |      |   | 9,544.3   |  |      | 9,370.4   |      |   | 9,271.7   |  |   | 8,985.0  
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  |      |           |      |  
|KWH net generated and purchased (millions)    |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Net generated                                 |  |      | 6,280.2   |      |   | 6,249.7   |  |      | 6,042.4   |      |   | 6,247.0   |  |   | 6,115.1  
|Purchased                                     |  |      | 4,054.3   |      |   | 3,829.6   |  |      | 3,861.6   |      |   | 3,572.0   |  |   | 3,391.7  
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  |      | 10,334.5  |      |   | 10,079.3  |  |      | 9,904.0   |      |   | 9,819.0   |  |   | 9,506.8  
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Losses and system uses (%)                    |  |      | 5.2       |      |   | 5.1       |  |      | 5.2       |      |   | 5.4       |  |   | 5.3      
|                                              |  |      |           |      |  
|Energy supply (year-end)                      |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Net generating capabilityMW                  |  |      | 1,606     |      |   | 1,606     |  |      | 1,608     |      |   | 1,608     |  |   | 1,587    
|Firm purchased capabilityMW                  |  |      | 531       |      |   | 510       |  |      | 531       |      |   | 532       |  |   | 472      
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  |      | 2,137     |      |   | 2,116     |  |      | 2,139     |      |   | 2,140     |  |   | 2,059    
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Net peak demandMW1                           |  |      | 1,638     |      |   | 1,583     |  |      | 1,564     |      |   | 1,527     |  |   | 1,478    
|Btu per net KWH generated                     |  |      | 10,663    |      |   | 10,673    |  |      | 10,675    |      |   | 10,818    |  |   | 10,789   
|Average fuel oil cost per Mbtu (cents)        |  |      | 580.5     |      |   | 466.4     |  |      | 539.3     |      |   | 538.5     |  |   | 329.7    
|                                              |  |      |           |      |  
|Customer accounts (year-end)                  |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Residential                                   |  |      | 362,400   |      |   | 356,244   |  |      | 352,132   |      |   | 347,316   |  |   | 342,957  
|Commercial                                    |  |      | 52,659    |      |   | 51,386    |  |      | 50,974    |      |   | 50,434    |  |   | 49,549   
|Large light and power                         |  |      | 549       |      |   | 551       |  |      | 542       |      |   | 547       |  |   | 550      
|Other                                         |  |      | 1,385     |      |   | 1,374     |  |      | 1,344     |      |   | 1,342     |  |   | 1,299    
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  |      | 416,993   |      |   | 409,555   |  |      | 404,992   |      |   | 399,639   |  |   | 394,355  
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  |      |           |      |  
|Electric revenues (thousands)                 |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Residential                                   |  | $    | 471,697   |      | $ | 426,291   |  | $    | 425,287   |      | $ | 421,129   |  | $ | 356,631  
|Commercial                                    |  |      | 474,017   |      |   | 425,595   |  |      | 436,751   |      |   | 422,977   |  |   | 345,808  
|Large light and power                         |  |      | 434,319   |      |   | 389,312   |  |      | 409,977   |      |   | 414,067   |  |   | 336,434  
|Other                                         |  |      | 7,758     |      |   | 7,028     |  |      | 7,349     |      |   | 7,487     |  |   | 6,454    
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  | $    | 1,387,791 |      | $ | 1,248,226 |  | $    | 1,279,364 |      | $ | 1,265,660 |  | $ | 1,045,327
|                                              |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|                                              |  |      |           |      |  
|Average revenue per KWH sold (cents)          |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Residential                                   |  |      | 16.40     |      |   | 15.34     |  |      | 15.96     |      |   | 16.03     |  |   | 13.98    
|Commercial                                    |  |      | 14.96     |      |   | 13.85     |  |      | 14.48     |      |   | 14.47     |  |   | 12.43    
|Large light and power                         |  |      | 11.81     |      |   | 10.70     |  |      | 11.27     |      |   | 11.29     |  |   | 9.35     
|Other                                         |  |      | 14.26     |      |   | 13.26     |  |      | 13.98     |      |   | 13.84     |  |   | 11.80    
|Average revenue per KWH sold                  |  |      | 14.20     |      |   | 13.08     |  |      | 13.65     |      |   | 13.65     |  |   | 11.63    
|                                              |  |      |           |      |  
|Residential statistics                        |  |      |           |      |   |           |  |      |           |      |   |           |  |   |          
|Average annual use per customer account (KWH) |  |      | 8,004     |      |   | 7,840     |  |      | 7,620     |      |   | 7,618     |  |   | 7,490    
|Average annual revenue per customer account   |  | $    | 1,313     |      | $ | 1,203     |  | $    | 1,216     |      | $ | 1,221     |  | $ | 1,047    
|Average number of customer accounts           |  |      | 359,288   |      |   | 354,419   |  |      | 349,782   |      |   | 344,882   |  |   | 340,528  



|1 | Sum of the net peak demands on all islands served, noncoincident and nonintegrated.
|- | -----------------------------------------------------------------------------------



4



---

##### Table of Contents

Generation statistics



The following table contains certain generation statistics as of December 31, 2003 and for the year ended December 31, 2003. The capability available for
operation at any given time may be more or less than the generating capability shown because of capability restrictions or temporary outages for inspection, maintenance, repairs or unforeseen circumstances.



|                                                                        |  |                      |   |  |                      |   |  |                      |   |  |                        |   |  |                         |   |  |          |   
|----------------------------------------------------------------------- |  | -------------------- | - |  | -------------------- | - |  | -------------------- | - |  | ---------------------- | - |  | ----------------------- | - |  | -------- | --
|                                                                        |  | Island of Oahu- HECO |   |  | Island of Maui- MECO |   |  | Island ofLanai- MECO |   |  | Island ofMolokai- MECO |   |  | Island of Hawaii- HELCO |   |  | Total    |   
|Net generating and firm purchased capability (MW) at December 31, 20031 |  |                      |   |  |                      |   |  |                      |   |  |                        |   |  |                         |  
|Conventional oil-fired steam units                                      |  | 1,106.8              |   |  | 35.9                 |   |  |                     |   |  |                       |   |  | 62.2                    |   |  | 1,204.9  |   
|Diesel                                                                  |  |                     |   |  | 94.9                 |   |  | 10.3                 |   |  | 9.6                    |   |  | 39.0                    |   |  | 153.8    |   
|Combustion turbines (peaking units)                                     |  | 101.8                |   |  |                     |   |  |                     |   |  |                       |   |  |                        |   |  | 101.8    |   
|Combustion turbines                                                     |  |                     |   |  | 41.6                 |   |  |                     |   |  | 2.2                    |   |  | 44.9                    |   |  | 88.7     |   
|Combined-cycle unit                                                     |  |                     |   |  | 56.8                 |   |  |                     |   |  |                       |   |  |                        |   |  | 56.8     |   
|Firm contract power2                                                    |  | 406.0                |   |  | 16.0                 |   |  |                     |   |  |                       |   |  | 109.0                   |   |  | 531.0    |   
|                                                                        |  |                      |   |  |                      |   |  |                      |   |  |                        |   |  |                         |   |  |          |   
|                                                                        |  | 1,614.6              |   |  | 245.2                |   |  | 10.3                 |   |  | 11.8                   |   |  | 255.1                   |   |  | 2,137.0  |   
|                                                                        |  |                      |   |  |                      |   |  |                      |   |  |                        |   |  |                         |   |  |          |   
|Net peak demand (MW)                                                    |  | 1,242.0              |   |  | 197.7                |   |  | 5.0                  |   |  | 6.5                    |   |  | 186.7                   |   |  | 1,637.93 |   
|Reserve margin                                                          |  | 30.5                 | % |  | 24.0                 | % |  | 105.8                | % |  | 82.2                   | % |  | 36.6                    | % |  | 30.9     | % 
|Annual load factor                                                      |  | 72.7                 | % |  | 70.2                 | % |  | 67.6                 | % |  | 69.6                   | % |  | 69.8                    | % |  | 72.0     | %3
|KWH net generated and purchased (millions)                              |  | 7,909.0              |   |  | 1,215.4              |   |  | 29.6                 |   |  | 39.6                   |   |  | 1,140.9                 |   |  | 10,334.5 |   



|1 | HECO units at normal ratings; MECO and HELCO units at reserve ratings.
|- | ----------------------------------------------------------------------



|2 | Nonutility generatorsHECO: 180 MW (Kalaeloa Partners, L.P., oil-fired), 180 MW (AES Hawaii, Inc., coal-fired) and 46 MW (H-Power, refuse-fired); MECO: 16 MW
(Hawaiian Commercial & Sugar Company, primarily bagasse-fired); HELCO: 27 MW (Puna Geothermal Venture, geothermal), 22 MW (Hilo Coast Power Company, coal-fired) and 60 MW (Hamakua Energy Partners, L.P., oil-fired).
|- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|3 | Noncoincident and nonintegrated.
|- | --------------------------------



Generating reliability



HECO, HELCO and MECO have isolated electrical systems that are not interconnected to each other or to any other electrical grid. HECO serves the island of
Oahu and HELCO serves the island of Hawaii. MECO has three separate electrical systemsone each on the islands of Maui, Molokai and Lanai.



Because each island system cannot rely upon backup generation from neighboring utilities, HECO, HELCO and MECO each maintain a higher level of reserve
generation than is typically carried by interconnected mainland utilities, which are able to share reserve capacity. These higher levels of reserve margins are required to meet peak electric demands, to provide for scheduled maintenance of
generating units (including the units operated by independent power producers (IPPs) relied upon for firm capacity) and to allow for the forced outage of the largest generating unit in the system. Although the planning for, and installation of,
adequate levels of reserve generation have contributed to the achievement of generally high levels of system reliability, service interruptions do occur from time to time as a result of unforeseen circumstances. For example, HECO implemented load
shedding and temporarily shut off power to a significant number of customers on one occasion in 2002, due to unplanned generating unit outages. Load shedding is a predetermined plan that prevents overloading and possible major damage to generating
units and potentially a much larger power outage.



HELCOs
management is concerned about the possibility of power interruptions as a result of the current operating status of various IPPs supplying power to it and the condition and performance of aging generators on the



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HELCO system that were intended to be operated less frequently once CT-4 and CT-5 were installed at HELCOs Keahole power plant. (See discussion in Note
11 to HECOs Consolidated Financial Statements). A significant number of HELCOs customers experienced rolling blackouts on two occasions in 2002 due to unplanned generating unit outages.



Integrated resource planning and requirements for additional generating capacity



As a result of a proceeding initiated in 1990, the Public
Utilities Commission of the State of Hawaii (PUC) issued an order in 1992 requiring the energy utilities in Hawaii to develop integrated resource plans (IRPs). The goal of integrated resource planning is the identification of demand- and supply-side
resources and the integration of these resources for meeting near- and long-term consumer energy needs in an efficient and reliable manner at the lowest reasonable cost. In its 1992 order, the PUC adopted a framework, which established
both the process and the guidelines for developing IRPs. The PUCs framework directs that each plan cover a 20-year planning horizon with a five-year program implementation schedule and states that the planning cycle will be repeated every
three years. Under the framework, the PUC may approve, reject or require modifications of the utilities IRPs.



The framework also states that utilities are entitled to recover all appropriate and reasonable integrated resource planning and implementation costs,
including the costs of planning and implementing DSM programs. Under appropriate circumstances, the utilities have been allowed in the past to recover lost margins resulting from DSM programs and earn shareholder incentives. The PUC has approved IRP
cost recovery provisions for HECO, MECO and HELCO. Pursuant to the cost recovery provisions, the electric utilities have been allowed to recover through a surcharge the costs for approved DSM programs (including DSM program lost margins and
shareholder incentives), and other incremental IRP costs incurred by the utilities and approved by the PUC, to the extent the costs are not included in their base rates.



In October 2001, HECO and the Consumer Advocate finalized agreements, which were approved by the PUC in November 2001, under
which HECOs three commercial and industrial DSM programs and two residential DSM programs would be continued until HECOs next rate case, which, under the agreements, HECO committed to file using a 2003 or 2004 test year and following the
PUCs rules for determining the test year. In August 2003, HECO and the Consumer Advocate agreed, and the PUC approved, a delay in the filing of HECOs next rate case, with the result that the rate case would be filed using a 2005 test
year. Under the agreements, HECO will cap the recovery of lost margins and shareholder incentives if such recovery would cause HECO to exceed its current authorized return on rate base. HECO also agreed it will not pursue the continuation of lost
margins recovery and shareholder incentives through a surcharge mechanism in future rate cases. Consistent with the HECO agreements, in October 2001, MECO and HELCO reached agreements with the Consumer Advocate and filed requests to continue their
four existing DSM programs. In November 2001, the PUC issued orders (one of which was later amended) that, subject to certain reporting requirements and other conditions, allowed MECO and HELCO to continue temporarily their respective four existing
energy efficiency DSM programs. See Other regulatory mattersDemand-side management programsagreements with the Consumer Advocate at page 55 in HECOs MD&A. All of the electric utilities existing DSM programs
are energy efficiency programs designed to reduce the consumption of electricity.



In August 2000, pursuant to a stipulation filed by the electric utilities and the parties in the IRP cost proceedings, the PUC issued an order allowing the electric utilities to begin recovering the 1995 through 1999
incremental IRP costs, subject to refund with interest, pending the PUCs final decision and order (D&O) approving recovery of each respective years incremental IRP costs. Procedural schedules for the IRP cost proceedings have been
established with respect to the 2000-2003 IRP costs, such that the electric utilities can begin recovering incremental IRP costs in the month after the filing of the actual costs incurred for the year, subject to refund with interest, pending the
PUCs final D&O approving recovery of the costs. The Consumer Advocate has objected to the recovery of $2.5 million (before interest) of the $10.3 million of incremental IRP costs incurred during the 1995-2002 period, and the PUCs
decision is pending on this matter.



The electric utilities
have completed the recovery of their respective 1995 through 2001 incremental IRP costs through a surcharge on customer bills, subject to refund with interest. In addition, HECO completed the recovery of its 2002 incremental IRP costs in May 2003,
subject to refund with interest. MECO is scheduled to complete the recovery of its 2002 incremental IRP costs by May 2004. As of December 31, 2003, the amount of revenues the electric utilities recorded for IRP cost recoveries, subject to refund
with interest, amounted to $17 million. HECO



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and MECO expect to begin recovering their incremental 2003 IRP costs, subject to refund with interest pending a final D&O, following the filing of actual
2003 costs (which is expected to occur in late March or early April 2004).



In early 2001, the PUC issued its final D&O in the HELCO 2000 test year rate case, in which the PUC concluded that it is appropriate for HELCO to recover its IRP costs through base rates (and included an estimated
amount for such costs in HELCOs test year revenue requirements) and to discontinue recovery of incremental IRP costs through the separate surcharge. HELCO recovered its incremental IRP costs incurred in 2000, which were incurred prior to the
final D&O in its rate case, through its surcharge. HELCOs IRP costs incurred for 2001 and future years are recovered through HELCOs base rates. HELCO will continue to recover its DSM program costs, lost margins and shareholder
incentives approved by the PUC in a separate surcharge.



The
utilities have characterized their proposed IRPs as planning strategies, rather than fixed courses of action, and the resources ultimately added to their systems may differ from those included in their 20-year plans. Under the IRP framework, the
utilities are required to submit annual evaluations of their plans (including a revised five-year program implementation schedule) and to submit new plans on a three-year cycle, subject to changes approved by the PUC. Prior to proceeding with the
DSM programs, separate PUC approval proceedings must be completed, in which the PUC further reviews the details of the proposed programs and the utilities proposals for the recovery of DSM program expenditures, lost margins and shareholder
incentives.



HECOs IRP. HECO filed its second
IRP with the PUC in January 1998 and updated the status of its DSM and Supply Side Action Plans in July 1999. In January 2001, the parties to the proceeding filed a stipulation for PUC approval to expedite the proceeding and the PUC approved the
stipulation, closed the docket and ordered HECO to submit its IRP annual evaluation report and program implementation schedule by October 2002 (subsequently extended to December 2002) and its third IRP by October 2005, as stipulated. The PUC also
ordered HECO to immediately notify it in writing if HECO requires additional generation prior to the 2009 time frame.



In December 2002, HECO filed with the PUC its IRP evaluation report, updating the second IRP to reflect the latest sales and fuel forecasts and updated
key planning assumptions.



On the supply side, HECOs
updated second IRP focused on the planning for the next generating unit addition in the 2009 time framea 107 MW simple-cycle combustion turbine. The updated second IRP also includes plans to add a second 107 MW simple-cycle combustion turbine
in 2015, and in 2016, a conversion unit 105 MW steam turbine to create a dual-train combined-cycle unit. However, the report notes there is flexibility to allow HECO to defer the need for the second and third generating units should alternative
generation technologies advance to where they are an economically and technically feasible substitutes for conventional generation. In addition, pursuant to HECOs generation asset management program, all existing generating units are currently
planned to be operated (future environmental considerations permitting) beyond the 20-year IRP planning period (1998-2017).



On the demand side, in November 2001, the PUC issued two D&Os allowing HECO to temporarily continue its five energy efficiency DSM programs until its
next rate case. The five energy efficiency DSM programs are designed to reduce the rate of increase in Oahus energy use, defer construction of new generating units, minimize the states use of oil, and achieve savings for utility
customers who participate in the programs. The energy efficiency DSM programs include incentives for customers to install efficient lighting, refrigeration, water-heating and air-conditioning equipment and industrial motors. HECOs updated
second IRP includes two load management programs scheduled for implementation in 2004 (i.e., a Residential Direct Load Control Program and a Commercial and Industrial Direct Load Control Program). HECO filed applications with the PUC requesting
approval of these two load management programs in June and December 2003, respectively.



In September 2003, the PUC opened a docket to commence HECOs third IRP, which HECO expects to file by March 2005 and expects will require multiple solutions to meet Oahus future energy needs, including
renewable energy resources, energy efficiency, conservation, technology (such as CHP) and central station generation. Given the lead times needed for permitting and regulatory approvals, in October 2003, HECO submitted a covered source permit
application with the DOH for a 107 MW simple cycle combustion turbine in Campbell Industrial Park. The application specifies that the unit would use diesel fuel oil or naphtha, with the ability to convert to a bio-fuel, like ethanol or bio-diesel,
when it becomes commercially practicable.



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MECOs IRP. MECO filed its second IRP with the PUC in May 2000. A stipulated prehearing order was
approved by the PUC in October 2000. The parties filed individual Statements of Position in May 2001. In February 2004, the parties to the proceeding filed a stipulation for PUC approval to expedite the proceeding, close the docket, and establish a
schedule for MECOs next IRP annual evaluation report and program implementation schedule and its next IRP. The stipulation provided that MECO would submit IRP evaluation reports and program implementation schedules by April 2004 and April 2005
and its next (third) IRP by October 2006. The PUCs decision on the stipulation is pending.



MECOs second IRP identified changes in key forecasts and assumptions since the development of MECOs initial IRP. On the supply side,
MECOs second IRP focused on the planning for the installation of approximately 150 MW of additional generation through the year 2020 on the island of Maui, including 38 MW of generation at its Maalaea power plant site in increments from
2000-2005, 100 MW at its new Waena site in increments from 2007-2018, beginning with a 20 MW combustion turbine in 2007, and 10 MW from the acquisition of a wind resource in 2003 (currently, MECO expects to receive 20 MW of wind energy in 2006).
Approximately 4 MW of additional generation through the year 2020 is planned for each of the islands of Lanai and Molokai. MECO completed the installation of a 20 MW increment (the second) at Maalaea in September 2000, and the final increment of 18
MW, which was originally expected to be installed in 2005, is currently expected to be installed in September 2006 (assuming receipt in early 2004 of the necessary air permit, for which an application was submitted in December 2001).



On the demand side, in November 2001 the PUC issued a D&O allowing MECO
to continue temporarily its four existing energy efficiency DSM programs, which are similar in design to HECOs programs. MECOs IRP included plans for a new energy efficiency DSM program and two new load management DSM programs. MECO does
not plan to proceed with a new energy efficiency DSM program at this time, and MECO is in the process of evaluating the load management DSM programs, and will determine at a later date the need for and timing of filing load management DSM program
applications.



HELCOs IRP. In September 1998, HELCO filed
with the PUC its second IRP, which was updated in March 1999 and revised in June 1999. A schedule for the proceeding was approved by the PUC, and the parties to the proceeding completed two rounds of discovery. In January 2004, the parties to the
proceeding filed a stipulation for PUC approval to expedite the proceeding and in February 2004 the PUC approved the stipulation, closed the docket and ordered HELCO to submit its IRP annual evaluation report by the end of March 2004 and its next
IRP by October 2005, as stipulated. The PUC also ordered HELCO to immediately notify it in writing should circumstances change pertaining to, among other things, HELCOs supply-side resources and load and sales forecast. The PUC subsequently
opened a docket to commence HELCOs third IRP.



The second
IRP identified changes in key forecasts and assumptions since the development of HELCOs initial IRP. On the supply side, HELCOs second IRP focused on the planning for generating unit additions after near-term additions. Due to delays in
adding new generation, the near-term additions proposed in HELCOs second IRP included installing two 20 MW combustion turbines (CTs) at its Keahole power plant site and proceeding in parallel with a power purchase agreement (PPA) with Hamakua
Energy Partners, L.P. (Hamakua Partners, formerly Encogen Hawaii, L.P.) for a 60 MW (net) dual-train combined-cycle (DTCC) facility.



The Hamakua Partners PPA was approved in 1999 and its DTCC facility was completed in December 2000. (See the discussion of HELCO power purchase agreements
in Nonutility generation.) The two Keahole CTs, CT-4 and CT-5, which were the first two phases of a planned 56 MW (net) DTCC unit, have been delayed, but are now expected to be fully operational by December 31, 2004. (See HELCO
power situation in Note 11 to HECOs Consolidated Financial Statements.) A PPA with Hilo Coast Power Company (HCPC) for 18 MW of firm capacity terminated at the end of 1999, but as a result of the delays in adding new generation, HELCO
has been purchasing 22 MW of firm capacity from HCPCs coal-fired facility under a restated and amended PPA, the term of which runs through 2004, but automatically extends for one-year periods thereafter, unless terminated prior to an extension
period by either party. HELCO also has deferred the retirements of some of its older generating units. After CT-4 and CT-5 are installed, HELCOs current plans are to install a 16 MW steam turbine, ST-7, in 2009 or earlier pending approval of
land use re-classification, zoning approval and obtaining all the necessary permits and approvals to complete the DTCC unit. After the installation of ST-7, the target date for the next firm capacity



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addition is the 2017 timeframe. The timing of the need for additional new generation may change, however, based on factors such as the condition of the units
whose retirements have been deferred, and the status of the nonutility generators providing firm capacity, including Puna Geothermal Venture (PGV) and HCPC. (See the discussion of HELCO power purchase agreements in Nonutility
generation.)



On the demand side, in December 2001 the
PUC issued a D&O allowing HELCO to continue temporarily its four existing energy efficiency DSM programs, which are similar in design to HECOs programs.



New capital projects



The capital projects of the electric utilities may be subject to various approval and permitting processes, including obtaining PUC approval of the
project, air permits from the Department of Health of the State of Hawaii (DOH) and/or the U.S. Environmental Protection Agency (EPA) and land use permits from the Hawaii Board of Land and Natural Resources (BLNR). Difficulties in obtaining, or the
inability to obtain, the necessary approvals or permits could result in project delays, increased project costs and/or project abandonments. Extensive project delays and significantly increased project costs could result in a portion of the project
costs being excluded from rates. If a project is abandoned, the project costs are generally written-off to expense, unless the PUC determines that all or part of the costs may be deferred for later recovery in rates.



In addition to HELCOs Keahole power plant expansion project and HECOs East Oahu
Transmission Project (see discussion in Note 11 to HECOs Consolidated Financial Statements), the Company has two other significant capital projects currently in progress. In 2003, construction commenced on a $37 million project for an
underground fuel pipeline that will transport fuel from an oil refinery at Campbell Industrial Park to HECOs Waiau power plant. This project is scheduled for completion in late 2004. Also in 2003, planning continued on HECOs $23 million
project to construct a New Dispatch Center which will house a modernized Energy Management System, and which will be integrated with new Outage Management and Customer Information systems. The New Dispatch Center project is expected to be completed
in 2007, with the Energy Management System operational in 2006.



Nonutility
generation



The Company has supported state
and federal energy policies which encourage the development of alternate energy sources that reduce the use of fuel oil. The Companys alternate energy sources range from wind, geothermal and hydroelectric power, to energy produced by the
burning of bagasse (sugarcane waste) and municipal waste and coal.



HECO
PPAs. HECO currently has three major PPAs. In March 1988, HECO entered into a PPA with AES Barbers Point, Inc. (now known as AES Hawaii, Inc. (AES Hawaii)), a Hawaii-based, indirect subsidiary of The AES Corporation. The agreement with AES
Hawaii, as amended in August 1989, provides that, for a period of 30 years beginning September 1992, HECO will purchase 180 MW of firm capacity. The AES Hawaii 180 MW coal-fired cogeneration plant, which became operational in September 1992,
utilizes a clean coal technology. The facility is designed to sell sufficient steam to be a Qualifying Facility (QF) under the Public Utility Regulatory Policies Act of 1978 (PURPA). See discussion of a lawsuit against The
AES Corporation, AES Hawaii, HECO and HEI in Note 11 to HECOs Consolidated Financial Statements. Under the amended PPA, AES Hawaii must obtain certain consents from HECO prior to entering into any arrangement to refinance the facility. In the
second quarter of 2003, HECO and AES Hawaii reached agreement on the terms upon which HECO would consent to a proposed refinancing. Under the agreement, which was contingent on obtaining certain PUC approvals and completion of the refinancing, HECO
received consideration for its consent, primarily in the form of a PPA amendment that reduces the cost of firm capacity supplied to HECO pursuant to the PPA, retroactive to June 1, 2003. The benefit of the firm capacity cost reduction, totaling
approximately $2.9 million annually for the remaining term of the PPA, is being passed on to ratepayers through a reduction in rates. AES Hawaii also has granted HECO an option, subject to certain conditions, to acquire an interest in portions of
the AES Hawaii facility site that are not needed for the existing plant operations, and which potentially could be used for the development of another coal-fired facility. On July 1, 2003, the PUC issued a D&O approving the PPA amendment and the
establishment of a rate adjustment (lowering rates) on short notice, and, on July 9, 2003, the PUC issued a D&O clarifying its July 1, 2003 D&O. On July 31, 2003, the proposed refinancing was completed and capacity payments were reduced,
retroactive to June 1, 2003.



In October 1988, HECO entered
into an agreement with Kalaeloa Partners, L.P. (Kalaeloa), a limited partnership whose sole general partner was an indirect, wholly-owned subsidiary of ASEA Brown Boveri, Inc. (ABB), which has



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guaranteed certain of Kalaeloas obligations and, through affiliates, contracted to design, build, operate and maintain the facility. The agreement with
Kalaeloa, as amended, provides that HECO will purchase 180 MW of firm capacity for a period of 25 years beginning in May 1991. The Kalaeloa facility, which was completed in the second quarter of 1991, is a combined-cycle operation, consisting of two
oil-fired combustion turbines burning low sulfur fuel oil (LSFO) and a steam turbine that utilizes waste heat from the combustion turbines. The facility is designed to sell sufficient steam to be a QF. As of February 28, 1997, the ownership of
Kalaeloa was restructured so that 1% was owned by the ABB subsidiary as the general partner and 99% was owned by Kalaeloa Investment Partners (KIP) as the limited partner. KIP is a limited partnership comprised of PSEG Hawaiian Management, Inc. and
PSEG Hawaiian Investment, Inc. (nonregulated affiliates of Public Service Enterprise Group Incorporated) and Harbert Power Corporation. Subsequently, HECO consented to, and the PUC approved of, the transfer of the general partner partnership
interest from the ABB subsidiary to an entity affiliated with the owners of KIP. During the second quarter of 2003, Kalaeloa approached HECO with plans to upgrade the combustion turbines (the M upgrade) by installing new parts designed to improve
their efficiency and output. The upgraded combustion turbines would allow Kalaeloa to increase the capacity of the facility by approximately 20 MW. Under the agreement, Kalaeloa may not make any modifications to the facility that would either
increase or decrease the generating capacity of the facility without the prior approval of HECO, except as required by law or regulation. The agreement also provides that HECO shall not be obligated to approve a change in facility capacity if such
change would adversely impact HECO system reliability or result in an increased cost of power to HECO from the facility. On December 31, 2003, HECO and Kalaeloa entered into a Consent and Agreement (Consent) in which HECO consented to the M upgrade.
The Consent provides that neither the M upgrade nor HECOs consent to the M upgrade shall obligate HECO to accept additional energy made available as a result of the M upgrade, or to enter into negotiations to accept any change in the firm
capacity of the facility, and shall not affect the rights of the parties under the section of the agreement related to an increase in firm capacity.



HECO also entered into a PPA in March 1986 and a firm capacity amendment in April 1991 with the City and County of Honolulu with respect to a refuse-fired
plant (H-POWER). The H-POWER facility began to provide firm energy in 1990 and currently supplies HECO with 46 MW of firm capacity. The firm capacity amendment provides that HECO will purchase firm capacity until mid-2015.



HECO purchases energy on an as-available basis from two nonutility
generators, which are diesel-fired qualifying cogeneration facilities at the two oil refineries (10 MW and 18 MW) on Oahu. HECO previously purchased energy on an as-available basis from an approximately 3 MW combustion turbine fired by methane gas
from a landfill. In March 2002, the combustion turbine suffered a major failure. In July 2002, the owner of the facility requested that HECO terminate the PPA and HECO agreed.



The PUC has approved and allowed rate recovery for the firm capacity and purchased energy costs related to HECOs three
major PPAs that provide a total of 406 MW of firm capacity, representing 25% of HECOs total net generating and firm purchased capacity on the island of Oahu as of December 31, 2003. The PUC also has approved and allowed rate recovery for the
purchased energy costs related to HECOs as-available energy PPAs.



MECO and HELCO PPAs. As of December 31, 2003, MECO and HELCO had PPAs for 16 MW (includes 4 MW of system protection) and 109 MW of currently available firm capacity, respectively.



MECO has a PPA with Hawaiian Commercial & Sugar Company (HC&S) for 16
MW of firm capacity. The HC&S generating units primarily burn bagasse (sugar cane waste) along with secondary fuels of oil or coal. In March 1998, an HC&S unit failed and HC&S lost 10 MW of generating capacity. HC&S replaced the unit
and put it into operation in the second quarter of 2000. HC&S, however, has had some difficulties in meeting its contractual obligations to MECO for the years 2000 through 2003 due to operational constraints that led to several claims of force
majeure by HC&S. The constraints have been primarily due to an extended drought condition on Maui that impacts HC&Ss irrigation pumping load for its sugar cane operations. There has also been a higher than normal reduction in energy
produced due to other equipment outages. On January 23, 2001, MECO rescinded a December 27, 1999 PPA termination notice that it had sent to HC&S and agreed with HC&S that neither party would issue to the other a notice of termination prior
to the end of 2002. On June 14, 2002, MECO and HC&S agreed that neither party will give written notice of termination under the terms of the PPA, such that the PPA terminates prior to December 31, 2007. As a result, the PPA remains in force and
effect through December 31, 2007, and from year to year thereafter, subject to termination on or after December 31, 2007 on not less than two years prior written notice by either party.



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HELCO has a 35-year PPA with Puna Geothermal Venture (PGV) for 30 MW of firm capacity from its geothermal
steam facility expiring on December 31, 2027. PGVs output was reduced to 6 MW from April 2002 to March 2003. The loss of generation was attributed to blockage of a source well due to a failed liner 5,000 feet below the earths surface and
decreasing steam quality emanating from one of PGVs source wells. PGV completed drilling an additional source well in February 2003, and converted the blocked source well into an injection well in early March 2003. The new injection well was
tested and PGVs capacity is currently between 25 to 28 MW. PGV obtained a permit from the DOH for the new injection well in March 2003. Without the new injection well, PGV was able to produce only about 10 to 11 MW due to the high moisture
content of the steam from the new source well. PGV is assessing whether to drill another source well or to install new generation equipment designed to utilize the lower quality steam. While PGV indicates it is evaluating its options to enable it to
restore its 30 MW commitment to HELCO as soon as possible, HELCO cannot predict when PGV will be able to meet its contractual commitment. HELCOs PPA with PGV provides for annual availability sanctions against PGV if PGV does not provide up to
the contracted 30 MW of capacity. In the first quarter ending March 31, 2003, HELCO recorded $0.7 million lower purchased power expense from PGV for availability sanctions for not meeting contracted capacity for 2002. In addition, since PGV had not
yet restored its 30 MW commitment to HELCO by December 31, 2003, availability sanctions for 2003, of approximately $0.2 million, will be assessed against PGV in 2004. Constellation Energy, parent company of PGV, has solicited preliminary indications
of interest from potential bidders in order to explore the possibility of putting PGV up for sale. HELCO is not aware if and when a sale will be completed.



On October 4, 1999, HELCO entered into a PPA with HCPC effective January 1, 2000 through December 31, 2004, subject to early termination by HELCO after
two years, whereby HELCO purchases 22 MW of firm capacity from HCPCs coal-fired facility. The PPA extends for one-year periods thereafter, unless terminated prior to an extension period. The PPA was amended on November 5, 1999, which extended
the November 30, 1999 deadline for obtaining PUC approval of the PPA. The PUC approved the PPA, as amended, on December 7, 1999.



In October 1997, HELCO entered into an agreement with Encogen, a limited partnership whose general partners at the time were wholly-owned special-purpose
subsidiaries of Enserch and Jones Capital Corporation. Enserch Corporation and J.A. Jones, Inc. (Jones), the parent companies of Enserch and Jones Capital Corporation, respectively, guaranteed certain of Encogens obligations. The agreement
provides that HELCO will purchase up to 60 MW (net) of firm capacity for a period of 30 years. The DTCC facility, which primarily burns naphtha, consists of two oil-fired combustion turbines and a steam turbine that utilizes waste heat from the
combustion turbines. The PUC approved the agreement on July 14, 1999. On November 8, 1999, HELCO entered into a PPA Novation with Encogen and Hamakua Partners, which recognizes the transfer of the obligations of Encogen under the PPA to Hamakua
Partners. Hamakua Partners was formed as a result of the sale of the general partner and limited partner partnership interests of Enserch to entities affiliated with TECO Energy Inc., which is a Florida-based energy company and parent company of
Tampa Electric Company, a regulated electric utility. TECO Energy Inc. has replaced the guarantee of Enserch Corporation of certain of Hamakua Partners obligations. On August 12, 2000, Hamakua Partners began providing HELCO with firm capacity
from the first phase of a two-phase construction completion schedule. On December 31, 2000, Hamakua Partners began providing firm capacity from the entire facility, following completion of the second phase of construction. In June 2001, Hamakua
Partners demonstrated 60 MW of output from the facility. Subsequently, the output deteriorated due to technical problems in the steam turbine. Hamakua Partners has since resolved its nozzle plugging problems, but due to high nitrogen oxide emissions
and high steam turbine vibration problems, the output had been limited to 55-57 MW in early 2003. Hamakua Partners requested maintenance outages to correct the problems and returned to providing HELCO with 60 MW later in 2003. In September 2003,
Jones filed for reorganization in bankruptcy in North Carolina. Jones is the parent company of the managing general partner and a limited partner of Hamakua Partners, and is one of the two co-guarantors of the Hamakua Partners project. Jones has
stated that the bankruptcy filing will have no impact on Hamakua Partners ability to meet its contractual commitments. Jones has been attempting to sell its interest in Hamakua Partners under the supervision of the bankruptcy court. An auction
among the qualified bidders was held on February 23, 2004 and the court held a hearing on February 24, 2004. By Order dated March 2, 2004, the court approved a motion to sell substantially all of the assets of Jones to United States Power Fund L. P.
(USPF) and directed the appropriate parties to implement the sale. HELCO will be working with Jones and USPF to evaluate the terms and conditions of the sale and any implications of the sale on the PPA with Hamakua Partners.



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HELCO purchases energy on an as-available basis from a number of nonutility generators. The largest
include an 11 MW run-of-the-river hydroelectric facility and a 7 MW wind facility. Wailuku River Hydroelectric L.P., the owner of the hydroelectric facility, has an existing contract to provide HELCO with as-available power through May 2023. Apollo
Energy Corporation (Apollo), the owner of the wind facility, has an existing contract to provide HELCO with as-available windpower through June 29, 2002 (and extending thereafter until terminated by HELCO or Apollo). Apollo filed a petition for
hearing with the PUC on April 28, 2000, alleging that it had unsuccessfully attempted to negotiate a new power purchase agreement with HELCO. Apollo had offered to repower its existing 7 MW facility by the end of 2000 and to install additional wind
turbines, up to a total allowed capacity of 15 MW, by the end of 2001. The parties agreed to limit to four issues the matters being presented to the PUC for guidance: whether Apollo is entitled to capacity payments; whether Apollo is entitled to a
minimum purchase rate; whether certain performance standards should apply; and whether HELCOs proposed dispute resolution provision should apply. A hearing on these issues was held on October 3 to 5, 2000. On May 30, 2001, the PUC issued a
D&O in which it ordered HELCO and Apollo to continue to negotiate a PPA, consistent with the terms of the D&O, and to submit by August 13, 2001 either a finalized PPA or status reports informing the PUC of matters preventing finalization of
a PPA. HELCO and Apollo were unable to agree to a PPA by August 13, 2001, and each submitted a status report. The parties continued to negotiate in 2002 and 2003, but final agreement has not been reached on certain technical and interconnection cost
issues.



On August 17, 1999, HELCO entered into a PPA with
Kahua Power Partners LLC (KPP) for the purchase of as-available energy from KPPs proposed 10 MW windfarm. The PPA was amended by Amendment No. 1 dated April 4, 2000. The PUC approved the PPA, as amended, on June 1, 2001. KPP did not, however,
construct its windfarm. GE Wind Energy completed the acquisition of certain assets of Enron Wind Corporation in May 2002, including the proposed KPP project. On October 7, 2003, GE Wind Energy assigned the KPP PPA to Hawi Renewable Development, Inc.
(HRD). On December 9, 2003, HELCO terminated the KPP PPA pursuant to HRDs notice that it does not plan to develop that wind farm, and its request that the PPA be terminated.



On January 8, 2001, HELCO entered into a PPA with HRD for the purchase of as-available energy from HRDs proposed 5 MW
windfarm. An amendment to the PPA was completed on April 30, 2002. The PPA, as amended, was approved by the PUC on January 14, 2003. Due to transmission line limitations, the output of HRD would have been limited to 3 MW if the KPP windfarm were
connected to the electric grid through the same 34.5 kilovolt (kV) line.



On December 30, 2003, HELCO and Hawi Renewable Development, LLC (HRD LLC) entered into a PPA under which HRD LLC would sell energy from an expanded wind farm (approximately 10.6 MW) at HRDs 5 MW wind farm site
(which can accommodate the expanded wind farm). Since the KPP wind farm would not be built, it is anticipated that the output of the 10.6 MW wind farm would not be limited by another wind farm on the 34.5 kV line (although the output of the 10.6 MW
wind farm may be limited on occasion due to other factors). PUC approval of the PPA is pending.



The PUC has approved and allowed rate recovery for the firm capacity and purchased energy costs for MECOs and HELCOs approved firm capacity
and as-available energy PPAs.



Fuel oil usage and supply



The rate schedules of the Companys electric utility subsidiaries
include energy cost adjustment (ECA) clauses under which electric rates (and consequently the revenues of the electric utility subsidiaries generally) are adjusted for changes in the weighted-average price paid for fuel oil and certain components of
purchased power, and the relative amounts of company-generated power and purchased power. See discussion below under Rates, and Regulation of electric utility rates and Electric utility revenues in HECOs
MD&A.



HECOs steam power plants burn LSFO.
HECOs combustion turbine peaking units burn No. 2 diesel fuel (diesel). MECOs and HELCOs steam power plants burn medium sulfur fuel oil (MSFO) and their combustion turbine and diesel engine generating units burn diesel. The LSFO
supplied to HECO is primarily derived from Indonesian and other Far East crude oils processed in Hawaii refineries. The MSFO supplied to MECO and HELCO is derived from U.S. domestic crude oil processed in Hawaii refineries.



In December 1997, HECO executed contracts for the purchase of LSFO and the
use of certain fuel distribution facilities with Chevron Products Company (Chevron) and BHP Petroleum Americas Refining Inc. (BHP). Subsequently, Tesoro Hawaii Corp. (Tesoro) acquired BHP and assumed all rights and obligations under the contract
between HECO and BHP. The Chevron and BHP (now Tesoro) fuel supply and facilities operations contracts have a term of seven years commencing January 1, 1998. The PUC approved the contracts and permits the inclusion of



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costs incurred under these contracts in HECOs ECA clauses. HECO pays market-related prices for fuel supplies purchased under these agreements. HECO is
currently negotiating with its fuel suppliers for new long-term LSFO supply agreements to replace those expiring at the end of 2004.



HECO, MECO and HELCO executed joint fuel supply contracts with Chevron and BHP (now Tesoro) for the purchase of diesel and MSFO supplies and for the use
of certain petroleum distribution facilities for a period of seven years commencing January 1, 1998. The PUC approved these contracts and permits the electric utilities to include fuel costs incurred under these contracts in their respective ECA
clauses. The electric utilities pay market-related prices for diesel and MSFO supplied under these agreements. HECO, HELCO and MECO are currently negotiating with its fuel suppliers for new long-term contracts for the supply of diesel and MSFO to
replace those expiring at the end of 2004.



The diesel supplies
acquired by the Lanai Division of MECO are purchased under a contract with a local petroleum wholesaler, Lanai Oil Co., Inc. On March 1, 2000, the PUC approved an amended contract with a term extending through December 31, 2001, and further
extending through December 31, 2003 unless terminated as of the end of 2001. This agreement has been extended through December 31, 2004 and the utility anticipates that it will again continue for another year, through December 31, 2005, as provided
by a provision in the existing contract.



See the fuel oil
commitments information set forth in the Fuel contracts section in Note 11 to HECOs Consolidated Financial Statements.



The following table sets forth the average cost of fuel oil used by HECO, MECO and HELCO to generate electricity in the years 2003, 2002 and 2001:



|     |  |          |  |        |  |          |  |              |  |          |  |        |  |          |  |       
|---- |  | -------- |  | ------ |  | -------- |  | ------------ |  | -------- |  | ------ |  | -------- |  | ------
|     |  | HECO     |  | MECO   |  | HELCO    |  | Consolidated
|     |  | $/Barrel |  | ¢/MBtu |  | $/Barrel |  | ¢/MBtu       |  | $/Barrel |  | ¢/MBtu |  | $/Barrel |  | ¢/MBtu
|2003 |  | 35.49    |  | 561.3  |  | 39.52    |  | 662.1        |  | 34.96    |  | 566.4  |  | 36.23    |  | 580.5 
|2002 |  | 27.95    |  | 442.3  |  | 32.78    |  | 548.5        |  | 30.58    |  | 496.7  |  | 29.10    |  | 466.4 
|2001 |  | 31.90    |  | 508.3  |  | 40.00    |  | 670.0        |  | 31.96    |  | 514.8  |  | 33.49    |  | 539.3 



The average per-unit
cost of fuel oil consumed to generate electricity for HECO, MECO and HELCO reflects a different volume mix of fuel types and grades. In 2003, over 99% of HECOs generation fuel consumption consisted of LSFO. The balance of HECOs fuel
consumption was diesel. Diesel made up approximately 75% of MECOs and 29% of HELCOs fuel consumption. MSFO made up the remainder of the fuel consumption of MECO and HELCO. In general, MSFO is the least costly fuel, diesel is the most
expensive fuel and the price of LSFO falls between the two on a per-barrel basis. During 2003, the prices of LSFO, MSFO and diesel remained at or above the high levels reached at the end of 2002 reflecting geopolitical uncertainty with the invasion
of Iraq and tight U.S. crude oil and petroleum inventories. Thus the annual prices paid by the utilities for LSFO, MSFO and diesel averaged approximately 25%, 13% and 21%, respectively, above the average price for that grade of fuel in 2002. Even
though the average price per barrel was lower in 2002 than 2001, the prices of LSFO, MSFO and diesel trended higher during 2002 from the level prevailing at the end of 2001. The utilities 2002 price for LSFO and diesel averaged approximately
7% and 16%, respectively, below the average price in 2001, while the price for MSFO averaged approximately 3% above the average price in 2001.



In December 2000, HELCO and MECO executed contracts of private carriage with Hawaiian Interisland Towing, Inc. (HITI) for the shipment of MSFO and diesel
supplies from their fuel suppliers facilities on Oahu to storage locations on the islands of Hawaii and Maui, respectively, commencing January 1, 2002. These contracts were the result of a competitive bidding process and provide for the
employment of a new double-hull bulk petroleum barge at freight rates approximately the same as prevailed under predecessor transportation contracts with HITI. The new barge entered utility service in March 2002. The contracts are for an initial
term of 5 years with options for three additional 5-year extensions. On December 10, 2001, the PUC approved these contracts and issued a final order that permits HELCO and MECO to include the fuel transportation and related costs incurred under the
provisions of these agreements in their respective ECA clauses.



HITI never takes title to the fuel oil or diesel fuel, but does have custody and control while the fuel is in transit from Oahu. If there were an oil spill in transit, HITI is contractually obligated to indemnify HELCO and/or MECO. HITI has
liability insurance coverage for oil spill related damage of $1 billion. State law provides a cap of $700 million on liability



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for releases of heavy fuel oil transported interisland by tank barge. HELCO and/or MECO may be responsible for any clean-up and/or fines that HITI or its
insurance carrier does not cover.



The prices that HECO, MECO
and HELCO pay for purchased energy from nonutility generators are generally linked to the price of oil. The AES Hawaii energy prices vary primarily with an inflation indicator. The energy prices for Kalaeloa, which purchases LSFO from Tesoro, vary
primarily with world LSFO prices. The H-POWER, HC&S, PGV and HCPC energy prices are based on the electric utilities respective PUC-filed short-run avoided energy cost rates (which vary with their respective composite fuel costs), subject
to minimum floor rates specified in their approved PPAs. The Hamakua Partners energy prices vary primarily with HELCOs diesel costs.



The Company estimates that 78% of the net energy generated and purchased by HECO and its subsidiaries in 2004 will be generated from the burning of oil.
Increases in fuel oil prices are passed on to customers through the electric utility subsidiaries ECA clauses. Failure by the Companys oil suppliers to provide fuel pursuant to the supply contracts and/or substantial increases in fuel
prices could adversely affect consolidated HECOs and the Companys financial condition, results of operations and/or liquidity. HECO, however, maintains an inventory of fuel oil in excess of one months supply. HELCO and MECO
maintain approximately a one months supply of both MSFO and diesel. The PPAs with AES Hawaii and Hamakua Partners require that they maintain certain minimum fuel inventory levels.



Transmission systems



HECO has 138 kV transmission and 46 kV subtransmission lines. HELCO has 69 kV transmission and 34.5 kV subtransmission lines. MECO has 69 kV transmission
and 23 kV subtransmission lines on Maui and 34.5 kV transmission lines on Molokai. Lanai has no transmission lines and uses 12 kV lines to distribute electricity. The electric utilities overhead and underground transmission and subtransmission
lines, as well as their distribution lines, are uninsured because the amount of insurance available is limited and the premiums are extremely high.



Lines are added when needed to serve increased loads and/or for reliability reasons. In some design districts on Oahu, lines must be placed underground.
By state law, the PUC generally must determine whether new 46 kV, 69 kV or 138 kV lines can be constructed overhead or must be placed underground. The process of acquiring permits and regulatory approvals for new lines can be contentious, time
consuming (leading to project delays) and costly.



HECO system. HECO
serves Oahus electricity requirements with firm capacity (net) generating units located in West Oahu (1,027 MW); Waiau, adjacent to Pearl Harbor (481 MW); and Honolulu (107 MW). HECOs nonfirm power sources (approximately 28 MW) are
located primarily in West Oahu. HECO transmits power to its service areas on Oahu through approximately 219 miles of overhead and underground 138 kV transmission lines (of which approximately 8 miles are underground) and approximately 570 miles of
overhead and underground 46 kV subtransmission lines.



HECOs power sources are located primarily in West Oahu, but the bulk of HECOs system load is in the Honolulu/East Oahu area. Accordingly, HECO transmits bulk power to the Honolulu/East Oahu area over two major transmission
corridors (Northern and Southern). HECO had planned to construct a part underground/part overhead 138 kilovolt (kV) transmission line from the Kamoku substation to the Pukele substation in order to close the gap between the Southern and Northern
corridors and provide a third 138 kV transmission line to the Pukele substation. Construction of the proposed transmission line in its originally proposed location required the BLNR to approve a CDUP for the overhead portion of the line that would
have been in conservation district lands. Several community and environmental groups opposed the project, particularly the overhead portion of the line and, in June 2002, the BLNR denied HECOs request for a CDUP.



HECO continues to believe that the proposed project (the East Oahu
Transmission Project) is needed to improve the reliability of the Pukele substation, which serves approximately 16% of Oahus electrical load, including Waikiki, and to address future potential line overloads under certain contingencies. In
2003, HECO completed its evaluation of alternative ways to accomplish the project (including using 46 kV transmission lines). As part of its evaluation, HECO conducted a community-based process to obtain public views of the alternatives. In December
2003, HECO filed an application with the PUC requesting approval to commit funds (currently estimated at $55 million) for its revised East Oahu Transmission Project. See discussion in Note 11 to HECOs Consolidated Financial Statements.



In March 2004, approximately 40,000 of HECOs customers
in the Honolulu//East Oahu area, including Waikiki, lost power for forty-five minutes to one and one-half hours. The areas affected are served by the Pukele substation. One of the two transmission lines serving the Pukele substation was out for
scheduled maintenance when the second



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transmission line went out of service and resulted in the power outage. Management believes that the effects of the outage could have been mitigated, and
that the outage might have been prevented if the East Oahu Transmission Project had been completed.



HELCO system.HELCO serves the island of Hawaiis electricity requirements with firm capacity (net) generating units located in West Hawaii (42 MW) and East Hawaii (213 MW). HELCOs nonfirm power
sources total 24 MW. HELCO transmits power to its service area on the island of Hawaii through approximately 468 miles of 69 kV overhead lines and approximately 173 miles of 34.5 kV overhead lines.



MECO system.MECO serves its electricity requirements with firm capacity (net)
generating units located on the island of Maui (245 MW), Molokai (12 MW) and Lanai (10 MW). MECO has no nonfirm power sources. MECO transmits power to its service area through approximately 143 miles of 69 kV overhead lines, approximately 15 miles
of 34.5 kV overhead lines, and approximately 85 miles of 23 kV overhead lines.



Rates



HECO, MECO and HELCO are subject to the
regulatory jurisdiction of the PUC with respect to rates, issuance of securities, accounting and certain other matters. See Regulation and other mattersElectric utility regulation.



All rate schedules of HECO and its subsidiaries contain ECA clauses as
described previously. Under current law and practices, specific and separate PUC approval is not required for each rate change pursuant to automatic rate adjustment clauses previously approved by the PUC. Rate increases, other than pursuant to such
automatic adjustment clauses, require the prior approval of the PUC after public and contested case hearings. PURPA requires the PUC to periodically review the ECA clauses of electric and gas utilities in the state, and such clauses, as well as the
rates charged by the utilities generally, are subject to change.



See Regulation of electric utility rates, Recent rate requests and Electric utility revenues in HECOs MD&A.



Public Utilities Commission of the State of Hawaii



Carlito Caliboso has been the Chairman of the PUC since April 30, 2003. Mr. Caliboso is an attorney and was in private
practice prior to his appointment. Continuing to serve on the PUC is Commissioner Wayne H. Kimura, who served as Chairman from July 2002 to April 2003 and Commissioner Janet E. Kawelo.



Most recent rate requests



See Recent rate requests in HECOs MD&A.



Maui Electric Company, Limited.In January 1998, MECO filed a request to increase rates, based on a 1999 test year, primarily to recover costs relating to the
addition of generating unit M17 in late 1998. In November 1998, MECO revised its requested increase to 11.9%, or $16.4 million, in annual revenues, based on a 12.75% return on average common equity (ROACE). In April 1999, MECO received an amended
final D&O from the PUC which authorized an 8.2%, or $11.3 million, increase in annual revenues, based on a 1999 test year and a 10.94% ROACE. The timing of a future MECO rate increase cannot be determined at this time.



Competition



In December 1996, the PUC instituted a proceeding to identify and examine the issues surrounding electric competition and to
determine the impact of competition on the electric utility infrastructure in Hawaii. See Competition in HECOs MD&A.



Electric and magnetic fields



Research on potential adverse health effects from exposure to electric and magnetic fields (EMF) continues. To date, no definite relationship between EMF
and health risks has been demonstrated. In 1996, the National Academy of Sciences examined more than 500 studies and stated that the current body of evidence does not show that exposure to EMFs presents a human-health hazard. An
extensive study released in 1997 by the National Cancer Institute and the Childrens Cancer Group found no evidence of increased risk for childhood leukemia from EMF. In 1999, the National Institute of Environmental Health Sciences
Directors Report concluded that while EMF could not be found to be entirely safe, the evidence of a health risk was weak and did not warrant aggressive regulatory actions.



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While EMF has not been established as a cause of any health condition, there were developments in 2002
and 2003. EMF was classified as a possible human carcinogen in reports from two public health organizations and in 2003, the U.K. National Radiological Protection Board (NRPB) published a consultation report that considered a precautionary approach
and proposed limiting exposure to EMF. The implications of the reports and the NRPB proposals have not yet been determined.



HECO and its subsidiaries are monitoring the research and continue to participate in utility industry funded studies on EMF and, where technically
feasible and economically reasonable, continue to reduce EMF in the design and installation of new transmission and distribution facilities. Management cannot predict the impact, if any, the EMF issue may have on HECO, HELCO and MECO in the future.



Legislation



See Legislation in HECOs MD&A.



Commitments and contingencies



See Certain factors that may affect future results and financial
conditionOther regulatory and permitting contingencies in HECOs MD&A and Note 11 to HECOs Consolidated Financial Statements for a discussion of important commitments and contingencies, including (but not limited to)
HELCOs Keahole power situation, HECOs East Oahu Transmission Project, the lawsuit against The AES Corporation and the Company, and the Honolulu Harbor environmental investigation.



BankAmerican Savings Bank, F.S.B.



General



ASB was granted a federal savings bank charter in January 1987. Prior to that time, ASB had operated since 1925 as the
Hawaii division of American Savings & Loan Association of Salt Lake City, Utah. As of December 31, 2003, ASB was the third largest financial institution in the State of Hawaii based on total assets of $6.5 billion and deposits of $4.0 billion.
In 2003, ASBs revenues and net income from continuing operations amounted to approximately 21% and 48%, respectively, of HEIs consolidated amounts, compared to approximately 24% and 48% in 2002 and approximately 26% and 45% in 2001,
respectively.



At the time of HEIs acquisition of ASB in
1988, HEI agreed with the Office of Thrift Supervisions (OTS) predecessor regulatory agency that ASBs regulatory capital would be maintained at a level of at least 6% of ASBs total liabilities, or at such greater amount as may be
required from time to time by regulation. Under the agreement, HEIs obligation to contribute additional capital was limited to a maximum aggregate amount of approximately $65.1 million. At December 31, 2003, HEIs maximum obligation to
contribute additional capital has been reduced to approximately $28.3 million because of additional capital contributions of $36.8 million by HEI to ASB since the acquisition, exclusive of capital contributions made in connection with ASBs
acquisition of most of the Hawaii operations of Bank of America, FSB. ASB is subject to OTS regulations on dividends and other distributions applicable to financial institutions regulated by the OTS and ASB must receive a letter of non-objection
before it can declare and pay a dividend to HEI.



The
accounting treatment for goodwill and other intangible assets has changed for 2002 and subsequent years such that goodwill is no longer amortized, but other intangible assets continue to be amortized, and goodwill and other intangible assets are
reviewed for impairment at least annually. See Goodwill and other intangibles in Note 1 to HEIs Consolidated Financial Statements.



ASBs earnings depend primarily on its net interest incomethe difference between the interest income earned on interest-earning assets (loans
receivable and investment and mortgage-related securities) and the interest expense incurred on interest-bearing liabilities (deposit liabilities and borrowings, including advances from the Federal Home Loan Bank (FHLB) of Seattle and securities
sold under agreements to repurchase).



For additional
information about ASB, see the sections under Bank in HEIs MD&A, HEIs Quantitative and Qualitative Disclosures about Market Risk and Note 4 to HEIs Consolidated Financial Statements.



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The following table sets forth selected data for ASB for the years indicated:



|                                                                                          |  |                          |   |  |      |   |  |      |  
|----------------------------------------------------------------------------------------- |  | ------------------------ | - |  | ---- | - |  | ---- | -
|                                                                                          |  | Years ended December 31, |  
|                                                                                          |  | 2003                     |   |  | 2002 |   |  | 2001 |  
|Common equity to assets ratio                                                             |  |                          |   |  |      |   |  |      |  
|Average common equity divided by average total assets1                                    |  | 7.20                     | % |  | 7.20 | % |  | 6.65 | %
|Return on assets                                                                          |  |                          |   |  |      |   |  |      |  
|Net income for common stock divided by average total assets1,
2                           |  | 0.88                     |   |  | 0.92 |   |  | 0.81 |  
|Return on common equity                                                                   |  |                          |   |  |      |   |  |      |  
|Net income for common stock divided by average common equity1,
2                          |  | 12.2                     |   |  | 12.7 |   |  | 12.3 |  
|Tangible efficiency ratio                                                                 |  |                          |   |  |      |   |  |      |  
|Total general and administrative expenses divided by net interest income and other income |  | 61                       |   |  | 58   |   |  | 56   |  



|1 | Average balances calculated using the average daily balances (except for common equity, which
is calculated using the average month-end balance).
|- | -------------------------------------------------------------------------------------------------------------------------------------------------



|2 | In 2001, net income includes amortization of goodwill and other intangibles. In 2003 and
2002, goodwill is no longer amortized, but other intangibles are still amortized, and goodwill and other intangibles are tested for impairment at least annually.
|- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



ASBs tangible efficiency ratio  the cost of earning $1 of revenue  rose from 56% for 2001 to 61% for 2003 due to
expenditures toward the strategic transformation which began in 2002. In 2002, general and administrative expenses grew at a faster pace than net interest income and other income as ASB began implementation of strategic changes to become a
full-service community bank. It is expected that this increased expense level will continue in 2004.



Consolidated average balance sheet



The following table sets forth average balances of ASBs major balance sheet categories for the years indicated. Average balances have been calculated using the daily average balances.



|                                     |  |                          |           |      |   |           |  |   |          
|------------------------------------ |  | ------------------------ | --------- | ---- | - | --------- |  | - | ---------
|                                     |  | Years ended December 31,
|(in thousands)                       |  | 2003                     |           | 2002 |   | 2001     
|Assets                               |  |                          |           |      |   |           |  |   |          
|Investment securities                |  | $                        | 200,891   |      | $ | 246,321   |  | $ | 308,712  
|Mortgage-related securities          |  |                          | 2,707,395 |      |   | 2,654,302 |  |   | 2,345,630
|Loans receivable, net                |  |                          | 3,071,877 |      |   | 2,844,341 |  |   | 2,963,521
|Other                                |  |                          | 418,296   |      |   | 392,338   |  |   | 391,040  
|                                     |  |                          |           |      |   |           |  |   |          
|                                     |  | $                        | 6,398,459 |      | $ | 6,137,302 |  | $ | 6,008,903
|                                     |  |                          |           |      |   |           |  |   |          
|Liabilities and stockholders equity |  |                          |           |      |   |           |  |   |          
|Savings deposits                     |  | $                        | 2,663,325 |      | $ | 2,394,435 |  | $ | 2,059,486
|Term certificates                    |  |                          | 1,224,820 |      |   | 1,323,118 |  |   | 1,578,650
|Other borrowings                     |  |                          | 1,851,258 |      |   | 1,770,831 |  |   | 1,778,766
|Other                                |  |                          | 123,167   |      |   | 132,223   |  |   | 117,366  
|Stockholders equity                 |  |                          | 535,889   |      |   | 516,695   |  |   | 474,635  
|                                     |  |                          |           |      |   |           |  |   |          
|                                     |  | $                        | 6,398,459 |      | $ | 6,137,302 |  | $ | 6,008,903
|                                     |  |                          |           |      |   |           |  |   |          



In 2003, the low
interest rate environment and continued strength in the Hawaii real estate market drove record loan production and an increase in average loans receivables. The average residential mortgage portfolio as of year-end 2003 grew by $193.6 million or
8.5% over the 2002 year-end average residential mortgage portfolio. ASBs average business portfolio increased by $51.9 million or 23.5% during 2003 as ASBs transformation to a full-service community bank continued. Average savings
deposits increased during the year as ASB continued to attract core deposits. Average term certificate balances decreased in 2003 as ASB did not aggressively pursue term certificates. Average other borrowings increased during 2003 to replace the
outflow of term certificates. In 2002, the increase in the average balance for mortgage-related securities was due to the exchange of loans for $0.4 billion of mortgage-related securities in 2001 and the investment of excess liquidity into
mortgage-related



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securities. In 2002, the decrease in the average balance of loans receivable was due to the exchange of
loans for mortgage-related securities in 2001 and the high loan prepayments in 2002 as result of the low interest rate environment. In 2002, the increase in savings deposits and the decrease in term certificates were due to ASBs efforts in
attracting low-costing core deposits and depositors not willing to have their funds invested for long periods of time at current interest rates as the low interest rate environment has brought term certificate interest rates down near core deposit
interest rates.



Asset/liability management



See HEIs Quantitative and Qualitative Disclosures about Market
Risk in HEIs Annual Report.



Interest income and interest
expense



See Results of operationsBank
in HEIs MD&A for a table of average balances, interest and dividend income, interest expense and weighted-average yields earned and rates paid for certain categories of interest-earning assets and interest-bearing liabilities for the years
ended December 31, 2003, 2002 and 2001.



The following table
shows the effect on net interest income of (1) changes in interest rates (change in weighted-average interest rate multiplied by prior year average portfolio balance) and (2) changes in volume (change in average portfolio balance multiplied by prior
period rate). Any remaining change is allocated to the above two categories on a pro rata basis.



|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|----------------------------------------- |  | -------------------------- | ------- | - | ------ | - | ------ | ----- |  | - | ------- | -
|                                          |  | Increase (decrease) due to |        
|(in thousands)                            |  | Rate                       |         |   | Volume |   |        | Total | 
|Year ended December 31, 2003 vs. 2002     |  |                            |         |   |        |   |        |       |  |   |         |  
|Income from interest-earning assets       |  |                            |         |   |        |   |        |       |  |   |         |  
|Loan portfolio                            |  | $                          | (19,637 | ) |        | $ | 15,503 |       |  | $ | (4,134  | )
|Mortgage-related securities               |  |                            | (30,425 | ) |        |   | 2,669  |       |  |   | (27,756 | )
|Investments                               |  |                            | (73     | ) |        |   | (1,439 | )     |  |   | (1,512  | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|                                          |  |                            | (50,135 | ) |        |   | 16,733 |       |  |   | (33,402 | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|Expense from interest-bearing liabilities |  |                            |         |   |        |   |        |       |  |   |         |  
|Deposits                                  |  |                            | (18,338 | ) |        |   | (1,485 | )     |  |   | (19,823 | )
|FHLB advances and other borrowings        |  |                            | (13,209 | ) |        |   | 3,474  |       |  |   | (9,735  | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|                                          |  |                            | (31,547 | ) |        |   | 1,989  |       |  |   | (29,558 | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|Net interest income                       |  | $                          | (18,588 | ) |        | $ | 14,744 |       |  | $ | (3,844  | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|Year ended December 31, 2002 vs. 2001     |  |                            |         |   |        |   |        |       |  |   |         |  
|Income from interest-earning assets       |  |                            |         |   |        |   |        |       |  |   |         |  
|Loan portfolio                            |  | $                          | (19,676 | ) |        | $ | (9,100 | )     |  | $ | (28,776 | )
|Mortgage-related securities               |  |                            | (35,306 | ) |        |   | 18,377 |       |  |   | (16,929 | )
|Investments                               |  |                            | (4,969  | ) |        |   | (2,747 | )     |  |   | (7,716  | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|                                          |  |                            | (59,951 | ) |        |   | 6,530  |       |  |   | (53,421 | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|Expense from interest-bearing liabilities |  |                            |         |   |        |   |        |       |  |   |         |  
|Deposits                                  |  |                            | (35,062 | ) |        |   | (7,838 | )     |  |   | (42,900 | )
|FHLB advances and other borrowings        |  |                            | (17,372 | ) |        |   | (431   | )     |  |   | (17,803 | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|                                          |  |                            | (52,434 | ) |        |   | (8,269 | )     |  |   | (60,703 | )
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  
|Net interest income                       |  | $                          | (7,517  | ) |        | $ | 14,799 |       |  | $ | 7,282   |  
|                                          |  |                            |         |   |        |   |        |       |  |   |         |  



Other income



In addition to net interest income, ASB
has various sources of other income, including fee income from servicing loans, fee income from financial products and services, fees on deposit accounts and other income. Other income totaled approximately $58.5 million in 2003, $53.0 million in
2002 and $45.0 million in 2001. The increase in other income for 2003 was due to net gains on sales of securities totaling $4.1 million compared to a net loss of $0.6 million in 2002, higher fee income from its debit and automated teller machines
(ATM) cards resulting from ASBs expansion of its debit card base and additional ATM services and higher fee income from its deposit liabilities as a result of restructuring of deposit products. Offsetting these increases were lower gains on
sales of loans in 2003 compared to 2002 and a lower accrual for the costs of administering delinquent loans in 2002. The increase in



18



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other income for 2002 was due to increases in fee income from its debit and ATM cards and higher fee income from its deposit liabilities. Increased fee
income from Bishop Insurance Agency of Hawaii, Inc. (BIA) which was acquired in March 2001 also contributed to the increase in other income. Offsetting these increases were lower fee income on loans serviced for others as ASB recorded writedowns of
its mortgage servicing rights due to faster prepayments on its servicing portfolio and a net loss of $0.6 million on the sale of securities compared to a net gain of $8.0 million in 2001.



Lending activities



General.Loans and mortgage-related securities of $5.8 billion represented 88.8% of total assets at December 31, 2003, compared to $5.7 billion, or 90.6%,
and $5.2 billion, or 86.7%, at December 31, 2002 and 2001, respectively. ASBs loan portfolio consists primarily of conventional residential mortgage loans, which are neither insured by the Federal Housing Administration nor guaranteed by the
Veterans Administration.



The following tables set forth the
composition of ASBs loan and mortgage-related securities portfolio:



|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|------------------------------------------------ |  | ------------ | --------- | - | ---------- | ------ | - | ------- | - | --------- | ---------- |  | ------ | ------- |  | - | ---------- | - |  | ------ | -
|                                                 |  | December 31, |          
|                                                 |  | 2003         |           |   | 2002       |        |   | 2001    |  
|(dollars in thousands)                           |  | Balance      |           |   | % of total |        |   | Balance |   |           | % of total |  |        | Balance |  |   | % of total |  
|Real estate loans1                               |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Conventional (1-4 unit residential)              |  | $            | 2,505,059 |   |            | 43.28  | % |         | $ | 2,389,852 |            |  | 41.70  | %       |  | $ | 2,294,372  |   |  | 44.02  | %
|Commercial real estate                           |  |              | 200,320   |   |            | 3.46   |   |         |   | 197,371   |            |  | 3.45   |         |  |   | 196,515    |   |  | 3.77   |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|                                                 |  |              | 2,705,379 |   |            | 46.74  |   |         |   | 2,587,223 |            |  | 45.15  |         |  |   | 2,490,887  |   |  | 47.79  |  
|Less                                             |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Deferred fees and discounts                      |  |              | (20,268   | ) |            | (0.35  | ) |         |   | (18,937   | )          |  | (0.33  | )       |  |   | (17,946    | ) |  | (0.34  | )
|Undisbursed loan funds                           |  |              | (27,021   | ) |            | (0.47  | ) |         |   | (21,412   | )          |  | (0.37  | )       |  |   | (22,910    | ) |  | (0.45  | )
|Allowance for loan losses                        |  |              | (14,734   | ) |            | (0.26  | ) |         |   | (23,708   | )          |  | (0.42  | )       |  |   | (26,085    | ) |  | (0.50  | )
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Total real estate loans, net                     |  |              | 2,643,356 |   |            | 45.66  |   |         |   | 2,523,166 |            |  | 44.03  |         |  |   | 2,423,946  |   |  | 46.50  |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Other loans                                      |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Consumer and other loans                         |  |              | 222,743   |   |            | 3.85   |   |         |   | 245,853   |            |  | 4.29   |         |  |   | 252,487    |   |  | 4.84   |  
|Commercial loans                                 |  |              | 286,068   |   |            | 4.94   |   |         |   | 247,114   |            |  | 4.31   |         |  |   | 197,333    |   |  | 3.79   |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|                                                 |  |              | 508,811   |   |            | 8.79   |   |         |   | 492,967   |            |  | 8.60   |         |  |   | 449,820    |   |  | 8.63   |  
|Less                                             |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Deferred fees and discounts                      |  |              | (606      | ) |            | (0.01  | ) |         |   | (416      | )          |  |       |         |  |   |           |   |  |       |  
|Undisbursed loan funds                           |  |              | (31       | ) |            |       |   |         |   | (1        | )          |  |       |         |  |   | (5         | ) |  |       |  
|Allowance for loan losses                        |  |              | (29,551   | ) |            | (0.51  | ) |         |   | (21,727   | )          |  | (0.38  | )       |  |   | (16,139    | ) |  | (0.31  | )
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Total other loans, net                           |  |              | 478,623   |   |            | 8.27   |   |         |   | 470,823   |            |  | 8.22   |         |  |   | 433,676    |   |  | 8.32   |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Mortgage-related securities, net of discounts    |  |              | 2,666,619 |   |            | 46.07  |   |         |   | 2,736,679 |            |  | 47.75  |         |  |   | 2,354,849  |   |  | 45.18  |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  
|Total loans and mortgage-related securities, net |  | $            | 5,788,598 |   |            | 100.00 | % |         | $ | 5,730,668 |            |  | 100.00 | %       |  | $ | 5,212,471  |   |  | 100.00 | %
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |         |  |   |            |   |  |        |  



|1 | Includes renegotiated loans. In 2001, ASB exchanged loans for $0.4 billion of mortgage-related securities.
|- | ----------------------------------------------------------------------------------------------------------



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|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|------------------------------------------------ |  | ------------ | --------- | - | ---------- | ------ | - | ------- | - | --------- | ---------- |  | ------ | -
|                                                 |  | December 31, |          
|                                                 |  | 2000         |           |   | 1999       |       
|(dollars in thousands)                           |  | Balance      |           |   | % of total |        |   | Balance |   |           | % of total | 
|Real estate loans1                               |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Conventional (1-4 unit residential)              |  | $            | 2,758,667 |   |            | 52.23  | % |         | $ | 2,769,101 |            |  | 53.40  | %
|Commercial real estate                           |  |              | 156,177   |   |            | 2.95   |   |         |   | 170,663   |            |  | 3.29   |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|                                                 |  |              | 2,914,844 |   |            | 55.18  |   |         |   | 2,939,764 |            |  | 56.69  |  
|Less                                             |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Deferred fees and discounts                      |  |              | (21,588   | ) |            | (0.41  | ) |         |   | (24,083   | )          |  | (0.46  | )
|Undisbursed loan funds                           |  |              | (17,559   | ) |            | (0.33  | ) |         |   | (19,368   | )          |  | (0.37  | )
|Allowance for loan losses                        |  |              | (24,800   | ) |            | (0.47  | ) |         |   | (22,319   | )          |  | (0.43  | )
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Total real estate loans, net                     |  |              | 2,850,897 |   |            | 53.97  |   |         |   | 2,873,994 |            |  | 55.43  |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Other loans                                      |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Consumer and other loans                         |  |              | 238,351   |   |            | 4.51   |   |         |   | 244,933   |            |  | 4.72   |  
|Commercial loans                                 |  |              | 134,784   |   |            | 2.55   |   |         |   | 106,098   |            |  | 2.05   |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|                                                 |  |              | 373,135   |   |            | 7.06   |   |         |   | 351,031   |            |  | 6.77   |  
|Less                                             |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Deferred fees and discounts                      |  |              |          |   |            |       |   |         |   |          |            |  |       |  
|Undisbursed loan funds                           |  |              | (58       | ) |            |       |   |         |   | (118      | )          |  |       |  
|Allowance for loan losses                        |  |              | (12,649   | ) |            | (0.24  | ) |         |   | (13,029   | )          |  | (0.25  | )
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Total other loans, net                           |  |              | 360,428   |   |            | 6.82   |   |         |   | 337,884   |            |  | 6.52   |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Mortgage-related securities, net of discounts    |  |              | 2,070,827 |   |            | 39.21  |   |         |   | 1,973,146 |            |  | 38.05  |  
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  
|Total loans and mortgage-related securities, net |  | $            | 5,282,152 |   |            | 100.00 | % |         | $ | 5,185,024 |            |  | 100.00 | %
|                                                 |  |              |           |   |            |        |   |         |   |           |            |  |        |  



|1 | Includes renegotiated loans.
|- | ----------------------------



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The following table summarizes ASBs loan portfolio, excluding loans held for sale, at December 31,
2003 and 2002, based upon contractually scheduled principal payments and expected prepayments allocated to the indicated maturity categories:



|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|---------------------------- |  | --------------- | --- | -------- | - | ------------ |  | ----- | ----- |  | - | -----
|December 31, 2003            |  | Due            
|(in millions)                |  | Less than1 year |     | 1-5years |   | After5 years |  | Total
|Residential loans            |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  | $               | 401 |          | $ | 866          |  | $     | 783   |  | $ | 2,050
|Adjustable                   |  |                 | 123 |          |   | 237          |  |       | 86    |  |   | 446  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 524 |          |   | 1,103        |  |       | 869   |  |   | 2,496
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|Commercial real estate loans |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  |                 | 5   |          |   | 19           |  |       | 17    |  |   | 41   
|Adjustable                   |  |                 | 28  |          |   | 47           |  |       | 84    |  |   | 159  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 33  |          |   | 66           |  |       | 101   |  |   | 200  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|Consumer loans               |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  |                 | 15  |          |   | 32           |  |       | 17    |  |   | 64   
|Adjustable                   |  |                 | 52  |          |   | 84           |  |       | 23    |  |   | 159  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 67  |          |   | 116          |  |       | 40    |  |   | 223  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|Commercial loans             |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  |                 | 91  |          |   | 57           |  |       | 29    |  |   | 177  
|Adjustable                   |  |                 | 59  |          |   | 43           |  |       | 7     |  |   | 109  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 150 |          |   | 100          |  |       | 36    |  |   | 286  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  | $               | 774 |          | $ | 1,385        |  | $     | 1,046 |  | $ | 3,205
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             | 
|December 31, 2002            |  | Due            
|(in millions)                |  | Less than1 year |     | 1-5years |   | After5 years |  | Total
|Residential loans            |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  | $               | 497 |          | $ | 484          |  | $     | 848   |  | $ | 1,829
|Adjustable                   |  |                 | 208 |          |   | 226          |  |       | 112   |  |   | 546  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 705 |          |   | 710          |  |       | 960   |  |   | 2,375
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|Commercial real estate loans |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  |                 | 6   |          |   | 26           |  |       | 26    |  |   | 58   
|Adjustable                   |  |                 | 19  |          |   | 43           |  |       | 77    |  |   | 139  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 25  |          |   | 69           |  |       | 103   |  |   | 197  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|Consumer loans               |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  |                 | 17  |          |   | 42           |  |       | 22    |  |   | 81   
|Adjustable                   |  |                 | 59  |          |   | 89           |  |       | 17    |  |   | 165  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 76  |          |   | 131          |  |       | 39    |  |   | 246  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|Commercial loans             |  |                 |     |          |   |              |  |       |       |  |   |      
|Fixed                        |  |                 | 90  |          |   | 36           |  |       | 13    |  |   | 139  
|Adjustable                   |  |                 | 54  |          |   | 42           |  |       | 12    |  |   | 108  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  |                 | 144 |          |   | 78           |  |       | 25    |  |   | 247  
|                             |  |                 |     |          |   |              |  |       |       |  |   |      
|                             |  | $               | 950 |          | $ | 988          |  | $     | 1,127 |  | $ | 3,065
|                             |  |                 |     |          |   |              |  |       |       |  |   |      



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Origination, purchase and sale of loans. Generally, residential and commercial real estate loans originated
by ASB are secured by real estate located in Hawaii. As of December 31, 2003, approximately $14.9 million of loans purchased from other lenders were secured by properties located in the continental United States. For additional information,
including information concerning the geographic distribution of ASBs mortgage-related securities portfolio and the geographic concentration of credit risk, see Note 12 to HEIs Consolidated Financial Statements.



The amount of loans originated during 2003, 2002, 2001, 2000 and 1999 were
$1.6 billion, $1.2 billion, $1.0 billion, $0.5 billion and $0.6 billion, respectively. The demand for loans is primarily dependent on the Hawaii real estate market, interest rates and loan refinancing activity. The increase in loan originations in
2003, 2002 and 2001 was due to the strength in the Hawaii real estate market and low interest rates which have resulted in increased affordability of housing for consumers and higher loan refinancings.



Residential mortgage lending.ASB is permitted to lend up to 100% of the
appraised value of the real property securing a loan. Its general policy is to require private mortgage insurance when the loan-to-value ratio of the property exceeds 80% of the lower of the appraised value or purchase price at origination. For
nonowner-occupied residential properties, the loan-to-value ratio may not exceed 90% of the lower of the appraised value or purchase price at origination.



Construction and development lending.ASB provides both fixed- and adjustable-rate loans for the construction of one-to-four unit residential and commercial
properties. Construction and development financing generally involves a higher degree of credit risk than long-term financing on improved, occupied real estate. Accordingly, all construction and development loans are priced higher than loans secured
by completed structures. ASBs underwriting, monitoring and disbursement practices with respect to construction and development financing are designed to ensure sufficient funds are available to complete construction projects. As of December
31, 2003, 2002 and 2001, ASB had construction and development loans of $72.8 million, $46.2 million and $52.0 million, which represented 2.3%, 1.5% and 1.8%, respectively, of ASBs gross loan portfolio. In 2003, the increase in construction and
development was due to an increase in commercial real estate lending. See Loan portfolio risk elements.



Multifamily residential and commercial real estate lending.ASB provides permanent financing and construction and development financing secured by
multifamily residential properties (including apartment buildings) and secured by commercial and industrial properties (including office buildings, shopping centers and warehouses) for its own portfolio as well as for participation with other
lenders. In 2003, 2002 and 2001, ASB originated $81.3 million, $66.0 million and $62.7 million loans secured by multifamily or commercial and industrial properties. Beginning in 2001, ASB enhanced its commercial real estate lending capabilities and
plans to continue to increase commercial real estate lending in the future. The objective of commercial real estate lending is to diversify ASBs loan portfolio as commercial and real estate loans tend to have higher yields and shorter
durations than residential mortgage loans.



Consumer lending.ASB
offers a variety of secured and unsecured consumer loans. Loans secured by deposits are limited to 90% of the available account balance. ASB also offers secured and unsecured VISA cards, automobile loans, general purpose consumer loans, home equity
lines of credit, checking account overdraft protection and unsecured lines of credit. In 2003, 2002 and 2001, gross consumer loan originations of $138.1 million, $131.8 million and $191.5 million, accounted for approximately 8.6%, 10.8% and 18.3%,
respectively, of ASBs total loan originations. In 2001, ASB increased its VISA credit card base by approximately 50%, primarily as a result of ASBs implementation of an aggressive series of mail solicitation campaigns to extend consumer
credit to existing customers.



Business lending.ASB is
authorized to make both secured and unsecured business loans to business entities. This lending activity is part of ASBs strategic transformation to a full-service community bank and is designed to diversify ASBs asset structure, shorten
maturities, improve rate sensitivity of the loan portfolio and attract business checking deposits. As of December 31, 2003, 2002 and 2001, business loans represented 9.2%, 8.3% and 6.9%, respectively, of ASBs total net loan portfolio.



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Loan origination fee and servicing income.In addition to interest earned on loans, ASB receives income
from servicing loans, for late payments and from other related services. Servicing fees are received on loans originated and subsequently sold by ASB through a securitization process and also on loans for which ASB acts as collection agent on behalf
of third-party purchasers. See Results of operationsBank in HEIs MD&A for a discussion of ASBs 2002 writedown of mortgage servicing rights.



ASB generally charges the borrower at loan settlement a loan origination fee of 1% of the amount borrowed. See Loans
receivable in Note 1 to HEIs Consolidated Financial Statements.



Loan portfolio risk elements.When a borrower fails to make a required payment on a loan and does not cure the delinquency promptly, the loan is classified as delinquent. If delinquencies are not cured promptly, ASB normally
commences a collection action, including foreclosure proceedings in the case of secured loans. In a foreclosure action, the property securing the delinquent debt is sold at a public auction in which ASB may participate as a bidder to protect its
interest. If ASB is the successful bidder, the property is classified in a real estate owned account until it is sold. ASBs real estate acquired in settlement of loans represented 0.12%, 0.19% and 0.24% of total assets at December 31, 2003,
2002 and 2001, respectively.



In addition to delinquent loans,
other significant lending risk elements include: (1) loans which accrue interest and are 90 days or more past due as to principal or interest, (2) loans accounted for on a nonaccrual basis (nonaccrual loans), and (3) loans on which various
concessions are made with respect to interest rate, maturity, or other terms due to the inability of the borrower to service the obligation under the original terms of the agreement (renegotiated loans). The level of delinquent and nonaccrual loans
represented 0.7%, 1.1%, 2.3%, 2.2%, and 2.4% of ASBs total net loans outstanding at December 31, 2003, 2002, 2001, 2000 and 1999, respectively. ASB had no loans that were 90 days or more past due on which interest was being accrued as of the
dates presented in the table below. The following table sets forth certain information with respect to nonaccrual and renegotiated loans as of the dates indicated:



|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|---------------------------------------------------- |  | ------------ | ----- | - | ---- | - | ------ | ---- |  | - | ------ | - |  | ---- | ------ | - |  | - | ------ | -
|                                                     |  | December 31, |      
|(in thousands)                                       |  | 2003         |       |   | 2002 |   |        | 2001 |  |   | 2000   |   |  | 1999 |       
|Nonaccrual loans                                    |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Real estate                                          |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|1-4 unit residential                                 |  | $            | 2,784 |   |      | $ | 9,783  |      |  | $ | 22,495 |   |  | $    | 26,738 |   |  | $ | 43,750 |  
|Income property                                      |  |              |      |   |      |   | 983    |      |  |   | 10,129 |   |  |      | 15,132 |   |  |   | 18,747 |  
|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Total real estate                                    |  |              | 2,784 |   |      |   | 10,766 |      |  |   | 32,624 |   |  |      | 41,870 |   |  |   | 62,497 |  
|Consumer                                             |  |              | 341   |   |      |   | 1,382  |      |  |   | 1,965  |   |  |      | 2,844  |   |  |   | 3,777  |  
|Commercial                                           |  |              | 2,236 |   |      |   | 3,633  |      |  |   | 3,018  |   |  |      | 2,872  |   |  |   | 2,192  |  
|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Total nonaccrual loans                               |  | $            | 5,361 |   |      | $ | 15,781 |      |  | $ | 37,607 |   |  | $    | 47,586 |   |  | $ | 68,466 |  
|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Nonaccrual loans to total net loans                  |  |              | 0.2   | % |      |   | 0.5    | %    |  |   | 1.3    | % |  |      | 1.4    | % |  |   | 2.1    | %
|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Renegotiated loans not included above               |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Real estate                                          |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|1-4 unit residential                                 |  | $            | 2,148 |   |      | $ |       |      |  | $ |       |   |  | $    | 48     |   |  | $ | 876    |  
|Income property                                      |  |              | 3,877 |   |      |   | 7,582  |      |  |   | 3,874  |   |  |      |       |   |  |   | 5,154  |  
|Commercial                                           |  |              | 1,919 |   |      |   | 2,175  |      |  |   | 2,681  |   |  |      |       |   |  |   |       |  
|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Total renegotiated loans                             |  | $            | 7,944 |   |      | $ | 9,757  |      |  | $ | 6,555  |   |  | $    | 48     |   |  | $ | 6,030  |  
|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Nonaccrual and renegotiated loans to total net loans |  |              | 0.4   | % |      |   | 0.9    | %    |  |   | 1.5    | % |  |      | 1.5    | % |  |   | 2.3    | %
|                                                     |  |              |       |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  



ASBs policy
generally is to place mortgage loans on a nonaccrual status (i.e., interest accrual is suspended) when the loan becomes 90 days or more past due or on an earlier basis when there is a reasonable doubt as to its collectibility.



In 2000, the $20.9 million decrease in nonaccrual loans was primarily due to
increased charge-offs and lower delinquencies. In 2001, the decrease in nonaccrual loans of $10.0 million was primarily due to lower delinquencies in residential loans and an income property loan taken into real estate owned. In 2002, the decrease
in nonaccrual loans of $21.8 million was due to $12.7 million lower delinquencies in residential loans, a $5.0 million payoff of an income property loan and a $4.1 million reclassification of an income property loan to accrual status. In 2003, the



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decrease in nonaccrual loans of $10.4 million was primarily due to $7.0 million lower delinquencies in residential loans as a result of improved credit
quality of ASBs loan portfolio due to the strong real estate market in Hawaii.



Allowance for loan losses.See Note 1 to HEIs Consolidated Financial Statements.



The following table presents the changes in the allowance for loan losses for the years indicated:



|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|------------------------------------------------------------------------------- |  | ------------------------ | ------ | - | ---- | - | ------ | ---- |  | - | ------ | - |  | ---- | ------ | - |  | - | ------ | -
|                                                                                |  | Years ended December 31, |       
|(dollars in thousands)                                                          |  | 2003                     |        |   | 2002 |   |        | 2001 |  |   | 2000   |   |  | 1999 |       
|Allowance for loan losses, beginning of year                                    |  | $                        | 45,435 |   |      | $ | 42,224 |      |  | $ | 37,449 |   |  | $    | 35,348 |   |  | $ | 39,779 |  
|Provision for loan losses                                                       |  |                          | 3,075  |   |      |   | 9,750  |      |  |   | 12,500 |   |  |      | 13,050 |   |  |   | 16,500 |  
|Charge-offs                                                                     |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Residential real estate loans                                                   |  |                          | 892    |   |      |   | 2,345  |      |  |   | 4,651  |   |  |      | 8,867  |   |  |   | 4,962  |  
|Commercial real estate loans                                                    |  |                          | 174    |   |      |   | 441    |      |  |   | 315    |   |  |      |       |   |  |   | 10,776 |  
|Consumer loans                                                                  |  |                          | 3,027  |   |      |   | 3,479  |      |  |   | 3,644  |   |  |      | 3,801  |   |  |   | 4,712  |  
|Commercial loans                                                                |  |                          | 2,601  |   |      |   | 1,479  |      |  |   | 1,013  |   |  |      | 670    |   |  |   | 1,209  |  
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Total charge-offs                                                               |  |                          | 6,694  |   |      |   | 7,744  |      |  |   | 9,623  |   |  |      | 13,338 |   |  |   | 21,659 |  
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Recoveries                                                                      |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Residential real estate loans                                                   |  |                          | 1,244  |   |      |   | 858    |      |  |   | 1,210  |   |  |      | 1,926  |   |  |   | 448    |  
|Commercial real estate loans                                                    |  |                          | 426    |   |      |   | 52     |      |  |   | 342    |   |  |      | 214    |   |  |   | 75     |  
|Consumer loans                                                                  |  |                          | 586    |   |      |   | 257    |      |  |   | 313    |   |  |      | 244    |   |  |   | 188    |  
|Commercial loans                                                                |  |                          | 213    |   |      |   | 38     |      |  |   | 33     |   |  |      | 5      |   |  |   | 17     |  
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Total recoveries                                                                |  |                          | 2,469  |   |      |   | 1,205  |      |  |   | 1,898  |   |  |      | 2,389  |   |  |   | 728    |  
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Allowance for loan losses, end of year                                          |  | $                        | 44,285 |   |      | $ | 45,435 |      |  | $ | 42,224 |   |  | $    | 37,449 |   |  | $ | 35,348 |  
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Ratio of allowance for loan losses, December 31, to average loans outstanding   |  |                          | 1.44   | % |      |   | 1.60   | %    |  |   | 1.42   | % |  |      | 1.16   | % |  |   | 1.11   | %
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Ratio of provision for loan losses during the year to average loans outstanding |  |                          | 0.10   | % |      |   | 0.34   | %    |  |   | 0.42   | % |  |      | 0.41   | % |  |   | 0.52   | %
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  
|Ratio of net charge-offs during the year to average loans outstanding           |  |                          | 0.14   | % |      |   | 0.23   | %    |  |   | 0.26   | % |  |      | 0.34   | % |  |   | 0.66   | %
|                                                                                |  |                          |        |   |      |   |        |      |  |   |        |   |  |      |        |   |  |   |        |  



The following table
sets forth the allocation of ASBs allowance for loan losses and the percentage of loans in each category to total loans at the dates indicated:



|                        |  |         |        |            |       |   |         |      |            |  |       |         |  |            |        |  |         |   |            |   |        |         |       |            |  |   |        |  |       |  
|----------------------- |  | ------- | ------ | ---------- | ----- | - | ------- | ---- | ---------- |  | ----- | ------- |  | ---------- | ------ |  | ------- | - | ---------- | - | ------ | ------- | ----- | ---------- |  | - | ------ |  | ----- | -
|December 31             |  | 2003    |        |            | 2002  |   |         | 2001 |            |  | 2000  |         |  | 1999       |       
|(dollars in thousands)  |  | Balance |        | % of total |       |   | Balance |      | % of total |  |       | Balance |  | % of total |        |  | Balance |   | % of total |   |        | Balance |       | % of total | 
|Residential real estate |  | $       | 4,031  |            | 78.0  | % |         | $    | 6,246      |  | 77.6  | %       |  | $          | 9,933  |  | 78.0    | % |            | $ | 13,224 |         | 83.9  | %          |  | $ | 14,394 |  | 84.2  | %
|Commercial real estate  |  |         | 6,008  |            | 6.2   |   |         |      | 6,343      |  | 6.4   |         |  |            | 9,031  |  | 6.7     |   |            |   | 8,928  |         | 4.7   |            |  |   | 7,963  |  | 5.2   |  
|Consumer                |  |         | 6,540  |            | 6.9   |   |         |      | 8,489      |  | 8.0   |         |  |            | 8,538  |  | 8.6     |   |            |   | 7,609  |         | 7.3   |            |  |   | 9,850  |  | 7.4   |  
|Commercial              |  |         | 14,758 |            | 8.9   |   |         |      | 12,118     |  | 8.0   |         |  |            | 6,388  |  | 6.7     |   |            |   | 4,126  |         | 4.1   |            |  |   | 3,060  |  | 3.2   |  
|Unallocated             |  |         | 12,948 |            | NA    |   |         |      | 12,239     |  | NA    |         |  |            | 8,334  |  | NA      |   |            |   | 3,562  |         | NA    |            |  |   | 81     |  | NA    |  
|                        |  |         |        |            |       |   |         |      |            |  |       |         |  |            |        |  |         |   |            |   |        |         |       |            |  |   |        |  |       |  
|                        |  | $       | 44,285 |            | 100.0 | % |         | $    | 45,435     |  | 100.0 | %       |  | $          | 42,224 |  | 100.0   | % |            | $ | 37,449 |         | 100.0 | %          |  | $ | 35,348 |  | 100.0 | %
|                        |  |         |        |            |       |   |         |      |            |  |       |         |  |            |        |  |         |   |            |   |        |         |       |            |  |   |        |  |       |  



|NA | Not applicable.
|-- | ---------------



In 2003, ASBs allowance for loan losses decreased by $1.2 million compared to an increase of $3.2 million in 2002. The decrease in 2003 was due to
lower net charge-offs as a result of lower delinquencies. The increasing value of Hawaii real estate and continued low interest rates gave debtors the opportunity to sell their properties or refinance before defaulting. ASB also continued to improve
its collection efforts. Residential, consumer and



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commercial real estate loan delinquencies continued to decrease during 2003 and lower loan loss reserves were required for those lines of business. The
growth in the commercial loan portfolio as a result of ASBs strategic focus of diversifying its loan portfolio from single-family home mortgages to commercial loans has required additional loan loss reserves. The unallocated component of the
allowance for loan losses, which takes into consideration economic trends and estimation errors that are not necessarily captured in determining the allowance for loan losses for each category, increased slightly. In 2002, ASBs allowance for
loan losses increased by $3.2 million compared to an increase of $4.8 million in 2001. The 2002 increase was due to a higher loans receivable balance and a higher unallocated component of the allowance for loan losses. The allowance was increased to
account for ASBs strategic focus of diversifying its loan portfolio from single-family home mortgages to commercial loans that have higher credit risk. Charge-offs were lower in 2002 compared to 2001 as a result of lower delinquencies. The
strong Hawaii real estate market and low interest rates gave debtors the opportunity to sell their properties or refinance before defaulting. In addition, ASB improved its collection efforts. Residential and commercial real estate loan delinquencies
decreased during 2002 and lower loan loss reserves were required for those lines of business. The allowance for loan losses on consumer loans remained essentially the same during 2002. In 2001, ASBs allowance for loan losses increased by $4.8
million. Charge-offs were lower in 2001 compared to 2000 as a result of lower delinquencies. The 2001 increase in the allowance for loan losses was due to the increase in commercial real estate and commercial loans in the loan portfolio that have
higher credit risk and a higher unallocated component of the allowance, which takes into consideration economic trends and estimation errors that are not necessarily captured in determining the allowance for loan losses for each loan category. In
2000, ASBs allowance for loan losses increased by $2.1 million. Charge-offs were lower in 2000 compared to 1999 as a result of lower delinquencies.



Investment activities



In recent years, ASBs investment portfolio consisted primarily of stock of the FHLB of Seattle, federal agency obligations and mortgage-related
securities. ASB owns private-issue mortgage-related securities as well as investment and mortgage-related securities issued by the Federal Home Loan Mortgage Corporation (FHLMC), Government National Mortgage Association (GNMA) and Federal National
Mortgage Association (FNMA). At December 31, 2003, the various securities rating agencies rated all of the private-issue mortgage-related securities as investment grade. ASB did not maintain a portfolio of securities held for trading during 2003,
2002 or 2001.



As of December 31, 2003, 2002 and 2001,
ASBs held-to-maturity investment portfolio consisted of $94.6 million, $89.5 million and $84.2 million, respectively, of investment in FHLB stock. The weighted-average rate on investments during 2003, 2002 and 2001 was 5.45%, 6.19% and 7.28%,
respectively. The amount that ASB is required to invest in FHLB stock is determined by regulatory requirements. See Regulation and other mattersBank regulationFederal Home Loan Bank System.



The following table summarizes ASBs investment portfolio, at December
31, 2003, based upon contractually scheduled principal payments and expected prepayments allocated to the indicated maturity categories:



|                           |  |                  |      |   |           |   |       |            |  |   |                |   |  |       |      |   |  |   |      
|-------------------------- |  | ---------------- | ---- | - | --------- | - | ----- | ---------- |  | - | -------------- | - |  | ----- | ---- | - |  | - | -----
|(in millions)              |  | Less than 1 year |      |   | 1-5 years |   |       | 6-10 years |  |   | After 10 years |   |  | Total
|Federal agency obligations |  | $                |     |   |           | $ | 50    |            |  | $ |               |   |  | $     |     |   |  | $ | 50   
|FHLMC, GNMA, FNMA          |  |                  | 598  |   |           |   | 1,292 |            |  |   | 371            |   |  |       | 104  |   |  |   | 2,365
|Private issue              |  |                  | 180  |   |           |   | 109   |            |  |   | 4              |   |  |       | 8    |   |  |   | 301  
|                           |  |                  |      |   |           |   |       |            |  |   |                |   |  |       |      |   |  |   |      
|                           |  | $                | 778  |   |           | $ | 1,451 |            |  | $ | 375            |   |  | $     | 112  |   |  | $ | 2,716
|                           |  |                  |      |   |           |   |       |            |  |   |                |   |  |       |      |   |  |   |      
|Weighted average yield     |  |                  | 4.53 | % |           |   | 4.40  | %          |  |   | 3.58           | % |  |       | 4.31 | % |  |   |      
|                           |  |                  |      |   |           |   |       |            |  |   |                |   |  |       |      |   |  |   |      



Note: ASB does not currently invest
in tax exempt obligations.



On January 1, 2001, ASB
reclassified a significant amount of securities from held-to-maturity to available-for-sale (see Derivative instruments and hedging activities in Note 1 to HEIs Consolidated Financial Statements). Securities classified as
available-for-sale are reported at fair value, with unrealized gains and losses excluded from earnings and reported in a separate component of stockholders equity (see Material estimates and critical accounting
policiesConsolidatedInvestment securities in HEIs MD&A). At December 31, 2003, ASB had



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mortgage-related securities issued by FHLMC, GNMA and FNMA valued at $2.4 billion and private-issue mortgage-related securities valued at $0.3 billion in its
available-for-sale investment portfolio.



Disposition of certain debt
securities and related litigation. See Note 4 to HEIs Consolidated Financial Statements.



Deposits and other sources of funds



General.Deposits traditionally have been the principal source of ASBs funds for use in lending, meeting liquidity requirements and making investments. ASB also derives funds from the receipt of interest and principal on
outstanding loans receivable and mortgage-related securities, borrowings from the FHLB of Seattle, securities sold under agreements to repurchase and other sources. ASB borrows on a short-term basis to compensate for seasonal or other reductions in
deposit flows. ASB also may borrow on a longer-term basis to support expanded lending or investment activities. Advances from the FHLB and securities sold under agreements to repurchase continue to be a significant source of funds that have a higher
cost of funds than core deposits.



Deposits.ASBs deposits
are obtained primarily from residents of Hawaii. In 2003 and 2002, ASB had average deposits of $3.9 billion and $3.7 billion, respectively. Net savings inflow in 2003, 2002 and 2001 was $225.5 million, $121.2 million and $94.9 million, respectively.
In the three years ended December 31, 2003, ASB had no deposits placed by or through a broker.



The following table illustrates the distribution of ASBs average deposits and average daily rates by type of deposit for the years indicated. Average balances have been calculated using the average daily
balances.



|                                        |  |                          |           |                    |       |   |                      |      |   |                |   |                    |  |       |                       |  |      |  
|--------------------------------------- |  | ------------------------ | --------- | ------------------ | ----- | - | -------------------- | ---- | - | -------------- | - | ------------------ |  | ----- | --------------------- |  | ---- | -
|                                        |  | Years ended December 31, |          
|                                        |  | 2003                     |           |                    | 2002  |  
|(dollars in thousands)                  |  | Averagebalance           |           | % of totaldeposits |       |   | Weightedaveragerate% |      |   | Averagebalance |   | % of totaldeposits |  |       | Weighted averagerate% | 
|Savings accounts                        |  | $                        | 1,352,507 |                    | 34.8  | % |                      | 0.56 | % |                | $ | 1,188,042          |  | 31.9  | %                     |  | 1.22 | %
|Negotiable order of withdrawal accounts |  |                          | 913,228   |                    | 23.5  |   |                      | 0.05 |   |                |   | 802,651            |  | 21.6  |                       |  | 0.13 |  
|Money market accounts                   |  |                          | 397,590   |                    | 10.2  |   |                      | 0.61 |   |                |   | 403,742            |  | 10.9  |                       |  | 1.51 |  
|Certificate accounts                    |  |                          | 1,224,820 |                    | 31.5  |   |                      | 3.54 |   |                |   | 1,323,118          |  | 35.6  |                       |  | 3.92 |  
|                                        |  |                          |           |                    |       |   |                      |      |   |                |   |                    |  |       |                       |  |      |  
|Total deposits                          |  | $                        | 3,888,145 |                    | 100.0 | % |                      | 1.38 | % |                | $ | 3,717,553          |  | 100.0 | %                     |  | 1.98 | %
|                                        |  |                          |           |                    |       |   |                      |      |   |                |   |                    |  |       |                       |  |      |  



|                                        |  |                              |           |                    |       |   |                       |      |  
|--------------------------------------- |  | ---------------------------- | --------- | ------------------ | ----- | - | --------------------- | ---- | -
|                                        |  | Year ended December 31, 2001 |          
|(dollars in thousands)                  |  | Average balance              |           | % oftotal deposits |       |   | Weighted averagerate% |     
|Savings accounts                        |  | $                            | 1,049,441 |                    | 28.9  | % |                       | 1.91 | %
|Negotiable order of withdrawal accounts |  |                              | 699,997   |                    | 19.2  |   |                       | 0.59 |  
|Money market accounts                   |  |                              | 310,048   |                    | 8.5   |   |                       | 2.40 |  
|Certificate accounts                    |  |                              | 1,578,650 |                    | 43.4  |   |                       | 5.38 |  
|                                        |  |                              |           |                    |       |   |                       |      |  
|Total deposits                          |  | $                            | 3,638,136 |                    | 100.0 | % |                       | 3.20 | %
|                                        |  |                              |           |                    |       |   |                       |      |  



At December 31, 2003,
ASB had $249.6 million in certificate accounts of $100,000 or more, maturing as follows:



|                                              |  |        |        
|--------------------------------------------- |  | ------ | -------
|(in thousands)                                |  | Amount
|Three months or less                          |  | $      | 79,954 
|Greater than three months through six months  |  |        | 33,121 
|Greater than six months through twelve months |  |        | 36,265 
|Greater than twelve months                    |  |        | 100,261
|                                              |  |        |        
|                                              |  | $      | 249,601
|                                              |  |        |        



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Deposit-insurance premiums and regulatory developments.The Savings Association Insurance Fund (SAIF)
insures the deposit accounts of ASB and other thrifts. The Bank Insurance Fund (BIF) insures the deposit accounts of commercial banks. The Federal Deposit Insurance Corporation (FDIC) administers the SAIF and BIF. In December 1997, ASB acquired
BIFassessable deposits as well as SAIFassessable deposits from Bank of America, FSB. Congress is currently considering legislation which would merge the SAIF and the BIF. This legislation is supported by the FDIC.



In December 1996, the FDIC adopted a risk-based base rate schedule for SAIF
deposits, effective January 1, 1997, that was identical to the existing risk-based base rate schedule for BIF deposits: zero to 27 cents per $100 of deposits. Added to this base rate schedule through 1999 was the assessment to fund the Financing
Corporations (FICOs) interest obligations, which assessment was initially set at 6.48 cents per $100 of deposits for SAIF deposits and 1.3 cents per $100 of deposits for BIF deposits (subject to quarterly adjustment). By law, the
FICOs assessment rate on deposits insured by the BIF had to be one-fifth the rate on deposits insured by the SAIF until January 1, 2000. Effective January 1, 2000, the assessment rate for funding FICO interest payments became identical for
SAIF and BIF deposits. The assessment rate for funding FICO interest payments is determined quarterly and, as a well capitalized thrift, ASBs base deposit insurance premium effective for the December 31, 2003 quarterly payment is
zero and its assessment for funding FICO interest payments is 1.54 cents per $100 of SAIF and BIF deposits, on an annual basis, based on deposits as of September 30, 2003.



Borrowings.ASB obtains advances from the FHLB of Seattle provided certain standards related to creditworthiness have been
met. Advances are secured by a blanket pledge of certain notes held by ASB and the mortgages securing them. To the extent that advances exceed the amount of mortgage loan collateral pledged to the FHLB of Seattle, the excess must be covered by
qualified marketable securities held under the control of and at the FHLB of Seattle or at an approved third party custodian. FHLB advances generally are available to meet seasonal and other withdrawals of deposit accounts, to expand lending and to
assist in the effort to improve asset and liability management. FHLB advances are made pursuant to several different credit programs offered from time to time by the FHLB of Seattle.



At December 31, 2003, 2002 and 2001, advances from the FHLB amounted to $1.0 billion, $1.2 billion and $1.0 billion,
respectively. The weighted-average rates on the advances from the FHLB outstanding at December 31, 2003, 2002 and 2001 were 4.28%, 5.10% and 5.41%, respectively. The maximum amount outstanding at any month-end during 2003, 2002 and 2001 was $1.1
billion, $1.2 billion and $1.2 billion, respectively. Advances from the FHLB averaged $1.0 billion, $1.1 billion and $1.2 billion during 2003, 2002 and 2001, respectively, and the approximate weighted-average rate on the advances was 4.62%, 5.29%
and 5.98%, respectively.



Securities sold under agreements to
repurchase are accounted for as financing transactions and the obligations to repurchase these securities are recorded as liabilities in the consolidated statements of financial condition. The securities underlying the agreements to repurchase
continue to be reflected in the asset accounts (see Note 4 to HEIs Consolidated Financial Statements). At December 31, 2003, 2002 and 2001, the entire outstanding amounts under these agreements of $831 million (including accrued interest of
$1.8 million), $667 million (including accrued interest of $6.4 million) and $683 million (including accrued interest of $4.9 million), respectively, were to purchase identical securities. The weighted-average rates on securities sold under
agreements to repurchase outstanding at December 31, 2003, 2002 and 2001 were 2.50%, 3.17% and 2.81%, respectively. The maximum amount outstanding at any month-end during 2003, 2002 and 2001 was $958 million, $751 million and $722 million,
respectively. Securities sold under agreements to repurchase averaged $807 million, $663 million and $629 million during 2003, 2002 and 2001, respectively, and the approximate weighted-average interest rate under those agreements was 2.63%, 3.11%
and 4.50%, respectively.



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The following table sets forth information concerning ASBs advances from the FHLB and securities
sold under agreements to repurchase at the dates indicated:



|                                               |  |              |           |   |      |   |           |      |  |   |           |  
|---------------------------------------------- |  | ------------ | --------- | - | ---- | - | --------- | ---- |  | - | --------- | -
|                                               |  | December 31, |          
|(dollars in thousands)                         |  | 2003         |           |   | 2002 |   |           | 2001 | 
|Advances from the FHLB                         |  | $            | 1,017,053 |   |      | $ | 1,176,252 |      |  | $ | 1,032,752 |  
|Securities sold under agreements to repurchase |  |              | 831,335   |   |      |   | 667,247   |      |  |   | 683,180   |  
|                                               |  |              |           |   |      |   |           |      |  |   |           |  
|Total borrowings                               |  | $            | 1,848,388 |   |      | $ | 1,843,499 |      |  | $ | 1,715,932 |  
|                                               |  |              |           |   |      |   |           |      |  |   |           |  
|Weighted-average rate                          |  |              | 3.48      | % |      |   | 4.40      | %    |  |   | 4.37      | %
|                                               |  |              |           |   |      |   |           |      |  |   |           |  



Competition



The banking industry in Hawaii is highly competitive. ASB is the third
largest financial institution in Hawaii and is in direct competition for deposits and loans, not only with the two larger institutions, but also with smaller institutions that are heavily promoting their services in certain niche areas, such as
providing financial services to small and medium-sized businesses. ASBs main competitors are banks, savings associations, credit unions, mortgage bankers, mortgage brokers, finance companies and brokerage firms. These competitors offer a
variety of financial products to retail and business customers.



The primary factors in competing for deposits are interest rates, the quality and range of services offered, marketing, convenience of locations, hours of operation and perceptions of the institutions financial soundness and safety.
Competition for deposits comes primarily from other savings institutions, commercial banks, credit unions, money market and mutual funds and other investment alternatives. In Hawaii, there were 2 thrifts, 6 FDIC-insured banks and approximately 100
credit unions at December 31, 2003. Additional competition for deposits comes from various types of corporate and government borrowers, including insurance companies. To meet competition, ASB offers a variety of savings and checking accounts at
competitive rates, convenient business hours, convenient branch locations with interbranch deposit and withdrawal privileges at each branch and convenient automated teller machines. ASB also conducts advertising and promotional campaigns.



The primary factors in competing for first mortgage and other
loans are interest rates, loan origination fees and the quality and range of lending products and services offered. Competition for origination of first mortgage loans comes primarily from mortgage banking and brokerage firms, commercial banks,
other savings institutions, insurance companies and real estate investment trusts. ASB believes that it is able to compete for such loans primarily through the competitive interest rates and loan fees it charges, the types of mortgage loan programs
it offers and the efficiency and quality of the services it provides its borrowers and the real estate business community.



In 2002, ASB began implementing a strategic plan to move from its traditional position as a thrift institution, focused on retail banking and residential
mortgages, to a full-service community bank. To make the shift, ASB continued to build its business and commercial real estate lines of business in 2002. The origination of business and commercial real estate loans involves risks different from
those associated with originating residential real estate loans. For example, the sources and level of competition may be different and credit risk is generally higher than for mortgage loans. These different risk factors are considered in the
underwriting and pricing standards established by ASB for its business and commercial real estate loans.



In September 2002, ASB launched its STAR initiative (Strategic & Tactical Alignment of Resources), in which four of its lines of businessRetail
Banking, Mortgage Banking, Commercial Real Estate and Commercial Bankingbegan implementing changes intended to increase profitability and enhance customer service.



There has been significant bank and thrift merger activity in Hawaii. Management cannot predict the impact, if any, of these
mergers on the Companys future competitive position, results of operations, financial condition or liquidity.



Credit Unions.The 1934 Federal Credit Union Act states that credit union membership shall be limited to groups having a common bond of occupation or
association or to groups in a well-defined geographical area. In 1982, the National Credit Union Administration expanded its definition of common bond to allow multiple common bondsi.e., small businesses that
lacked enough workers to form their own credit unions were allowed to join existing credit unions so long as each group of employees had its own bond. In February 1998, the Supreme Court decided that



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this expanded definition of common bond was impermissible, holding that the 1934 law required all members of a credit union to share a single
common bond. In August 1998, the Credit Union Membership Access Act became law, which, among other things, amended the 1934 law to retroactively authorize credit union membership based on multiple common bonds, as long as each of the relevant groups
has (with some exceptions) fewer than 3,000 members. The Credit Union Membership Access Act also facilitates the ability of insured credit unions to convert to mutual savings banks or savings associations, and requires that insured credit unions
meet capital standards similar to those enacted for banks and thrifts in 1991.



In December 1998, the National Credit Union Administration adopted final rules to implement the Credit Union Membership Access Act. The new rules appear to favor the creation of larger credit unions by facilitating
the merger of credit unions with fewer than 3,000 members. Under a Regulatory Flexibility Program that went into effect on March 1, 2002, the National Credit Union Administration allowed certain credit unions to expand the services offered to
members. It is too early to evaluate whether these developments will result in increased competition for ASB by credit unions.



See Certain factors that may affect future results and financial conditionBankRegulation of ASBFederal Thrift Charter in
HEIs MD&A for a discussion of the Gramm-Leach-Bliley Act of 1998.



Other



HEI Investments, Inc.



HEI Investment Corp. (HEIIC), incorporated in May 1984 primarily to make
passive investments in corporate securities and other long-term investments, changed its name to HEI Investments, Inc. (HEIII) in January 2000. HEIII is not an investment company under the Investment Company Act of 1940 and has no direct
employees. In February 2000, HEIII became a subsidiary of HEIPC.



HEIIIs long-term investments currently consist primarily of investments in leveraged leases. Since 1985, HEIII (then called HEIIC) has had a 15% ownership interest in an 818 MW coal-fired generating unit in Georgia, which is subject
to a leveraged lease agreement. In 1987, HEIIC purchased commercial buildings on leasehold properties located in the continental United States, along with the related lease rights and obligations. These leveraged, purchase-leaseback investments
include two major buildings housing operations of Hershey Foods in Pennsylvania and five supermarkets leased to The Kroger Co. in various states. HEIIIs investments in leveraged leases are accounted for in the Companys continuing
operations. For a discussion of HEIIIs former ownership interest in EPHE Philippines Energy Company, Inc. (EPHE), see Discontinued operations.



HEI Properties, Inc.



HEIDI Real Estate Corp., originally a subsidiary of HEIDI, was formed in February 1998. In September 1999, its name was changed to HEIPI and HEIDI
transferred ownership of HEIPI to HEI. HEIPI currently holds primarily venture capital investments. As of December 31, 2003, HEIPIs venture capital investments (in companies based in Hawaii and the U.S. mainland) amounted to $3.6 million.



The Old Oahu Tug Service, Inc.



On November 10, 1999, HTB changed its name to TOOTS. Prior to that date, HTB
(a former maritime transportation company) was the parent of YB (a regulated interisland cargo carrier). In November 1999, HTB sold substantially all of its operating assets and the stock of YB and ceased maritime freight transportation operations.
TOOTS currently administers certain employee and retiree-related benefits programs and monitors matters related its former operations and the operations of its former subsidiary.



Discontinued operations



For information concerning the Companys discontinued international power operations formerly conducted by HEIPC and its subsidiaries and its
discontinued residential real estate development business formerly conducted by MPC and its subsidiaries, see Certain factors that may affect future results and financial conditionConsolidatedDiscontinued operations and asset
dispositions in HEIs MD&A and Note 13 to HEIs Consolidated Financial Statements.



On March 6, 2000, a subsidiary of HEIII, HEIPC Philippines Holding Co., Inc., acquired a 50% interest in EPHE Philippines Energy Company, Inc. (EPHE),
which was the owner of approximately 91.7% of the common stock of East Asia Power Resources Corporation (EAPRC), a Philippines holding company primarily engaged in the electric



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generation business in Manila and Cebu. The Company wrote off this investment as of December 31, 2000 and subsequently classified the write-off in
discontinued operations. Subsequently HEIPC Philippines Holding Co., Inc. was dissolved and thereafter the capital stock it held in EPHE at the time of the dissolution was cancelled pursuant to an EPHE capital stock reduction approved by the
Philippine Securities and Exchange Commission.



The
Companys loss of its investment in EAPRC of approximately $90 million was recognized in 2000 for financial reporting purposes (including an income tax benefit of $35 million) and was included in HEIs 2001 income tax return as an ordinary
loss. In 2002, HEI requested that the Internal Revenue Service (IRS) concur with HEIs position that the loss was deductible against the operating income of its other operating subsidiaries. On January 6, 2004, the IRS signed a closing
agreement accepting HEIs treatment of the write-off in 2000 of its indirect investment in EAPRC as an ordinary loss for federal corporate income tax purposes in its 2001 tax return.



Regulation and other matters



Holding company regulation.HEI and HECO are holding companies within the meaning of the Public Utility Holding Company Act of 1935 (1935 Act). However,
under current rules and regulations, they are exempt from the comprehensive regulation of the SEC under the 1935 Act except for Section 9(a)(2) (relating to the acquisition of securities of other public utility companies) through compliance with the
requirement that they file annually Form U-3A-2 under the 1935 Act for holding companies which own utility businesses that are intrastate in character. The exemption afforded HEI and HECO may be revoked if the SEC finds that such exemption may
be detrimental to the public interest or the interest of investors or consumers. HEI and HECO may own or have interests in foreign utility operations without adversely affecting this exemption so long as the requirements of other exemptions
under the 1935 Act are satisfied. In connection with HEIPCs now-discontinued foreign electric utility operations, HEI had obtained the PUC certification which is a prerequisite to obtaining an exemption for foreign utility operations and to
the Companys maintenance of its exemption under the 1935 Act if it acquires such ownership interests. In 1996, HEI filed with the SEC a Form U-57, Notification of Foreign Utility Company Status, on behalf of HEI Power Corp. Guam
(for the HEIPC Groups Guam project, which has now been sold). In 1998, HEI filed two Form U-57s on behalf of Baotou Tianjiao Power Co., Ltd. (for the HEIPC Groups China project, which investment has been written off) and on behalf
of Cagayan Electric Power & Light Co., Inc. (for HEIPCs indirect subsidiarys investment in that entity, which subsidiary has now been sold). In March 2000, HEI filed a Form U-57 on behalf of EAPRC (for the HEIPC Groups
investment in that entity). With the discontinuance of HEIPCs international power operations, no further Form U-57 filings are contemplated.



Legislation has been introduced in Congress in the past that would repeal the 1935 Act, leaving the regulation of utility holding companies to be governed
by other federal and state laws. Management cannot predict if similar legislation will be proposed or enacted in the future or the final form it might take.



HEI is subject to an agreement entered into with the PUC (the PUC Agreement) when HECO became a subsidiary of HEI. The PUC Agreement, among other things,
requires HEI to provide the PUC with periodic financial information and other reports concerning intercompany transactions and other matters. It prohibits the electric utilities from loaning funds to HEI or its nonutility subsidiaries and from
redeeming common stock of the electric utility subsidiaries without PUC approval. Further, the PUC could limit the ability of the electric utility subsidiaries to pay dividends on their common stock. See Restrictions on dividends and other
distributions and Electric utility regulation (regarding the PUC review of the relationship between HEI and HECO).



As a result of the acquisition of ASB, HEI and HEIDI are subject to OTS registration, supervision and reporting requirements as savings and loan holding
companies. In the event the OTS has reasonable cause to believe that the continuation by HEI or HEIDI of any activity constitutes a serious risk to the financial safety, soundness, or stability of ASB, the OTS is authorized under the Home
Owners Loan Act of 1933, as amended, to impose certain restrictions in the form of a directive to HEI and any of its subsidiaries, or HEIDI and any of its subsidiaries. Such possible restrictions include limiting (i) the payment of dividends
by ASB; (ii) transactions between ASB, HEI or HEIDI, and the subsidiaries or affiliates of ASB, HEI or HEIDI; and (iii) the activities of ASB that might create a serious risk that the liabilities of HEI and its other affiliates, or HEIDI and its
other affiliates, may be imposed on ASB. Theoretically, this authority would allow the OTS to prohibit dividends, limit affiliate transactions or otherwise restrict activities as a result of losses suffered by HEI, HEIDI or their other subsidiaries,
and thus conceivably may



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be an indirect means of limiting affiliations between ASB and affiliates engaged in nonfinancial activities. See Restrictions on dividends and other
distributions.



OTS regulations also generally prohibit
savings and loan holding companies and their nonthrift subsidiaries from engaging in activities other than those which are specifically enumerated in the regulations. Such restrictions, if applicable to HEI and HEIDI, would significantly limit the
kinds of activities in which HEI and HEIDI and their subsidiaries may engage. However, the OTS regulations provide for an exemption which is available to HEI and HEIDI if ASB satisfies the qualified thrift lender (QTL) test discussed below. See
Bank regulationQualified thrift lender test. ASB must continue to meet the qualified thrift lender test in order to avoid restrictions on the activities of HEI and HEIDI and their subsidiaries. ASB met the QTL test at all times
during 2003, but the failure of ASB to satisfy the QTL test in the future could result in a need to divest ASB. If such divestiture were to be required, federal law limits the entities that might be eligible to acquire ASB.



OTS-regulated thrifts must file a quarterly Thrift Financial Report to
provide the OTS with specific information. Effective with the March 31, 2004 TRF, OTS will require greater detail concerning (i) holding companies such as HEI and HEIDI and (ii) transactions with affiliates. ASB has not yet analyzed the additional
costs of providing the more detailed information.



On February
10, 2004, OTS issued a notice of proposed rule making whereby the hourly fees charged by OTS in connection with OTS examinations of savings and loan holding companies would be replaced by payment to OTS of a semi-annual assessment of the
top-tier holding company in the holding company structure. For the HEI companies, that would be HEI itself. The assessment would consist of a base assessment amount (which OTS is proposing as $3,000) plus additional components based on the risk or
complexity of the holding companys business (which would in turn would be based on the holding companys OTS risk classification and total consolidated assets), its organizational form, and its condition based on the most recent OTS
examination rating assigned to the holding company. OTS will separately assess as conglomerates a limited number of large and complex enterprises. It is too early to determine whether the assessments under the proposed rules,
if implemented, would be more or less expensive to HEI than are the current examination fees.



HEI and HEIDI are prohibited, directly or indirectly, or through one or more subsidiaries, from (i) acquiring control of, or acquiring by merger or purchase of assets, another insured institution or holding company
thereof, without prior written OTS approval; (ii) acquiring more than 5% of the voting shares of another savings association or savings and loan holding company which is not a subsidiary; or (iii) acquiring or retaining control of a savings
association not insured by the FDIC. No director or officer of HEI or HEIDI, or person beneficially owning more than 25% of such holding companys voting shares, may, except with the prior approval of the OTS, (a) also serve as a director,
officer, or employee of any insured institution or (b) acquire control of any savings association not a subsidiary of such holding company.



ASB Realty Corporation, a subsidiary of ASB, is licensed as a nondepository financial services loan company under the Hawaii Code of Financial
Institutions. As a result of its direct or indirect voting control of ASB Realty Corporation, each of HEI, HEIDI and ASB has registered as a Financial Institution Holding Company and an Institution-Affiliated Party under the
Hawaii Code. As a Financial Institution Holding Company, HEI, HEIDI and ASB are subject to examination by the Hawaii Commissioner of Financial Institutions (Hawaii Commissioner) to determine whether their respective conditions or activities are
jeopardizing the safety and soundness of ASB Realty Corporations operations. However, the Hawaii Commissioner is authorized to conduct such an examination only if the Hawaii Commissioner has good cause to believe that the holding company is
experiencing financial adversity which might have a material negative impact on the safety and soundness of ASB Realty Corporation.



The Hawaii Commissioner has authority to issue a cease and desist order to ASB Realty Corporation, ASB, HEIDI and HEI, if, for example, the Commissioner
has reasonable grounds to believe that such entity is violating or about to violate the Hawaii Code or is engaged in or about to engage in illegal, unauthorized, unsafe or unsound practices. In appropriate circumstances, the Commissioner may also
have authority to order ASB Realty Corporation to correct any impairment of its capital and surplus and to prohibit ASB, HEIDI and HEI from participating in the affairs of ASB Realty Corporation.



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Restrictions on dividends and other distributions.HEI is a legal entity separate and distinct from its
various subsidiaries. As a holding company with no significant operations of its own, the principal sources of its funds are dividends or other distributions from its operating subsidiaries, borrowings and sales of equity. The rights of HEI and,
consequently, its creditors and shareholders, to participate in any distribution of the assets of any of its subsidiaries is subject to the prior claims of the creditors and preferred stockholders of such subsidiary, except to the extent that claims
of HEI in its capacity as a creditor are recognized.



The
abilities of certain of HEIs subsidiaries to pay dividends or make other distributions to HEI are subject to contractual and regulatory restrictions. Under the PUC Agreement, in the event that the consolidated common stock equity of the
electric utility subsidiaries falls below 35% of total electric utility capitalization (including in capitalization the current maturities of long-term debt, but excluding short-term borrowings), the electric utility subsidiaries would be
restricted, unless they obtained PUC approval, in their payment of cash dividends to 80% of the earnings available for the payment of dividends in the current fiscal year and preceding five years, less the amount of dividends paid during that
period. The PUC Agreement also provides that the foregoing dividend restriction shall not be construed to relinquish any right the PUC may have to review the dividend policies of the electric utility subsidiaries. The consolidated common stock
equity of HEIs electric utility subsidiaries was 53% of their total capitalization (including in capitalization the current maturities of long-term debt, but excluding short-term borrowings) as of December 31, 2003. As of December 31, 2003,
HECO and its subsidiaries had common stock equity of $944 million, of which approximately $449 million were not available for transfer to HEI without regulatory approval.



The ability of ASB to make capital distributions to HEI and other affiliates is restricted under federal law. Subject to a
limited exception for stock redemptions that do not result in any decrease in ASBs capital and would improve ASBs financial condition, ASB is prohibited from declaring any dividends, making any other capital distribution, or paying a
management fee to a controlling person if, following the distribution or payment, ASB would be deemed to be undercapitalized, significantly undercapitalized or critically undercapitalized. See Bank regulationPrompt corrective
action. All capital distributions are subject to an indication of no objection by the OTS. Also see Note 11 to HEIs Consolidated Financial Statements.



HEI and its subsidiaries are also subject to debt covenants, preferred stock resolutions and the terms of guarantees that
could limit their respective abilities to pay dividends. The Company does not expect that the regulatory and contractual restrictions applicable to HEI or its direct and indirect subsidiaries will significantly affect the operations of HEI or its
ability to pay dividends on its common stock.



Electric utility
regulation. The PUC regulates the rates, issuance of securities, accounting and certain other aspects of the operations of HECO and its electric utility subsidiaries. See the previous discussions under Electric utilityRates
and Electric utilityMost recent rate requests, and Recent rate requests and Regulation of electric utility rates in HECOs MD&A.



Any adverse decision or policy made or adopted by the PUC, or any prolonged delay in rendering a decision, could have a
material adverse effect on consolidated HECOs and the Companys financial condition, results of operations or liquidity.



The PUC has ordered the electric utility subsidiaries to develop plans for the integration of demand- and supply-side resources available to meet consumer
energy needs efficiently, reliably and at the lowest reasonable cost. See the previous discussion under Electric utilityIntegrated resource planning and requirements for additional generating capacity.



On December 30, 1996, the PUC issued an order instituting a proceeding to
identify and examine the issues surrounding electric competition and to determine the impact of competition on the electric utility infrastructure in Hawaii. See Competition in HECOs MD&A.



Certain transactions between HEIs electric public utility subsidiaries
(HECO, MECO and HELCO) and HEI and affiliated interests are subject to regulation by the PUC. All contracts (including summaries of unwritten agreements) made on or after July 1, 1988 of $300,000 or more in a calendar year for management,
supervisory, construction, engineering, accounting, legal, financial and similar services and for the sale, lease or transfer of property between a public utility and affiliated interests must be filed with the PUC to be effective, and the PUC may
issue cease and desist orders if such contracts are not filed. All such affiliated contracts for capital expenditures (except for real



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property) must be accompanied by comparative price quotations from two nonaffiliates, unless the quotations cannot be obtained without substantial expense.
Moreover, all transfers of $300,000 or more of real property between a public utility and affiliated interests require the prior approval of the PUC and proof that the transfer is in the best interest of the public utility and its customers. If the
PUC, in its discretion, determines that an affiliated contract is unreasonable or otherwise contrary to the public interest, the utility must either revise the contract or risk disallowance of the payments for ratemaking purposes. In ratemaking
proceedings, a utility must also prove the reasonableness of payments made to affiliated interests under any affiliated contract of $300,000 or more by clear and convincing evidence. An affiliated interest is defined by statute and
includes officers and directors of a public utility, every person owning or holding, directly or indirectly, 10% or more of the voting securities of a public utility, and corporations which have in common with a public utility more than one-third of
the directors of that public utility.



In January 1993, to
address community concerns expressed at the time, HECO proposed that the PUC initiate a review of the relationship between HEI and HECO and the effects of that relationship on the operations of HECO. The PUC opened a docket and initiated such a
review to determine whether the HEI-HECO relationship, HEIs diversified activities, and HEIs policies, operations and practices had resulted in or were having any negative effects on HECO, its electric utility subsidiaries and
ratepayers. In May 1994, the PUC selected a consultant, Dennis Thomas and Associates, to perform the review. In early 1995, Dennis Thomas and Associates issued its report (the Thomas report) to the PUC. The Thomas report concluded that on
balance, diversification has not hurt electric ratepayers. Other major findings were that (1) no utility assets have been used to fund HEIs nonutility investments or operations, (2) management processes within the electric utilities
operate without interference from HEI and (3) HECOs access to capital did not suffer as a result of HEIs involvement in nonutility activities and that diversification did not permanently raise or lower the cost of capital incorporated
into the rates paid by HECOs utility customers. The Thomas report also included a number of recommendations, most of which the Company has implemented. In December 1996, the PUC issued an order that adopted the Thomas report in its entirety,
ordered HECO to continue to provide the PUC with status reports on its compliance with the PUC agreement (pursuant to which HEI became the holding company of HECO) and closed the investigation and proceeding. The PUC has not required that the
Company implement all of the recommendations in the Thomas report. In the order, the PUC also stated that it adopted the recommendation of the DOD that HECO, MECO and HELCO present a comprehensive analysis of the impact that the holding company
structure and investments in nonutility subsidiaries have on a case-by-case basis on the cost of capital to each utility in future rate cases and remove such effects from the cost of capital. The PUC has accepted, in subsequent MECO and HELCO rate
cases, the presentations made by MECO and HELCO that there was no such impact in those cases. See also Holding company regulation.



HECO and its electric utility subsidiaries are not subject to regulation by the Federal Energy Regulatory Commission under the Federal Power Act, except
under Sections 210 through 212 (added by Title II of PURPA and amended by the Energy Policy Act of 1992), which permit the Federal Energy Regulatory Commission to order electric utilities to interconnect with qualifying cogenerators and small power
producers, and to wheel power to other electric utilities. Title I of PURPA, which relates to retail regulatory policies for electric utilities, and Title VII of the Energy Policy Act of 1992, which creates exempt wholesale generators
(EWGs) as a category that is exempt from the 1935 Act and addresses transmission access, also apply to HECO and its electric utility subsidiaries. HECO and its electric utility subsidiaries are also required to file various financial and operational
reports with the Federal Energy Regulatory Commission. The Company cannot predict the extent to which cogeneration, EWGs or transmission access will reduce its electrical loads, reduce its current and future generating and transmission capability
requirements or affect its financial condition, results of operations or liquidity.



Because they are located in the State of Hawaii, HECO and its subsidiaries are exempt by statute from limitations set forth in the Powerplant and Industrial Fuel Act of 1978 on the use of petroleum as a primary energy
source.



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Bank regulation. ASB, a federally chartered savings bank, and its holding companies are subject to the
regulatory supervision of the OTS and, in certain respects, the FDIC and the Hawaii Commissioner of Financial Institutions. See above under Holding company regulation. In addition, ASB must comply with Federal Reserve Board reserve
requirements and OTS liquidity requirements. See Liquidity and capital resourcesBank in HEIs MD&A.



Deposit insurance coverage.The Federal Deposit Insurance Act, as amended by the Federal Deposit Insurance Corporation Insurance Act of 1991 (FDICIA), and
regulations promulgated by the FDIC, govern insurance coverage of deposit amounts. Generally, the deposits maintained by a depositor in an insured institution are insured to $100,000, with the amount of all deposits held by a depositor in the same
capacity (even if held in separate accounts) aggregated for purposes of applying the $100,000 limit. For example, all deposits held in a depositors individual capacity are aggregated with each other but not with deposits maintained by such
depositor and his or her spouse in a qualifying joint account, these latter joint deposits being separately insured to an aggregate of $100,000. An individuals interest in deposits at the same institution in any combination of certain
retirement accounts and employee benefit plans will be added together and insured up to $100,000 in the aggregate.



Institutions that are well capitalized under the FDICs prompt corrective action regulations are generally able to provide
pass-through insurance coverage (i.e., insurance coverage that passes through to each owner/beneficiary of the applicable deposit) for the deposits of most employee benefit plans (i.e., $100,000 per individual participating, not $100,000
per plan). Consequently, the FDIC deposit insurance regulations require financial institutions to provide employee benefit plan depositors information, not otherwise available, on the institutions capital category and whether
pass-through deposit insurance is available. As of December 31, 2003, ASB was well capitalized.



Federal thrift charter. See Certain factors that may affect future results and financial conditionBankRegulation of ASBFederal Thrift
Charter in HEIs MD&A.



Recent legislation.The
Gramm-Leach-Bliley Act of 1998 (the Act) imposes on financial institutions an obligation to protect the security and confidentiality of its customers nonpublic personal information and, on February 1, 2001, the FDIC and OTS issued final
guidelines for the establishment of standards for safeguarding such information effective from July 1, 2001. On August 12, 2003, the FDIC and OTS issued a request for comment on a proposed interagency guidance describing the regulatory
agencies expectations that every financial institution develop a response program to protect against and address reasonably foreseeable risks associated with internal and external threats to the security of customer information maintained by
the financial institution or its service providers. The Act also requires public disclosure of certain agreements entered into by insured depository institutions and their affiliates in fulfillment of the Community Reinvestment Act of 1977, and the
filing of an annual report with the appropriate regulatory agencies. On January 10, 2001, the FDIC and the OTS issued final rules implementing these provisions of the Act, effective from April 1, 2001. Although the Act will continue to impose
additional compliance costs on ASB, ASB believes that any ongoing compliance costs will not be significant.



The International Money Laundering Abatement and Financial Anti-Terrorism Act of 2001 (the 2001 Act), which is part of the USA Patriot Act, imposes on
financial institutions a wide variety of additional obligations with respect to such matters as collecting information, monitoring relationships and reporting suspicious activities. Among other things, the 2001 Act requires the U.S. Treasury to
issue regulations establishing minimum requirements for verifying the identity of persons seeking to open an account, maintaining records of the information used for such verification, and consulting lists of known or suspected terrorists or
terrorist organizations. On May 9, 2003, various federal regulatory agencies including OTS jointly issued final rules requiring financial institutions to fully implement by October 1, 2003 a customer identification program. Additional compliance
costs resulting from the final rules are not material. The 2001 Act also requires financial institutions to establish anti-money laundering programs and, with respect to correspondent and private banking accounts of non-U.S. persons, to implement
appropriate due diligence policies to detect money laundering activities carried out through such accounts. ASB is monitoring the steps being taken by the regulatory agencies to implement these and other provisions of the 2001 Act.



Effective January 1, 2003, the OTS issued final regulations specifying the
record keeping and confirmation requirements applicable to thrifts and their subsidiaries engaged in effecting securities transactions for customers, which will apply to one of ASBs subsidiaries which effects securities transactions as an
agent. However, ASB does not believe the new requirements will result in significant additional compliance costs.



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Capital requirements. Under the Financial Institutions Reform, Recovery, and Enforcement Act of 1989 (FIRREA), the
OTS has set three capital standards for thrifts, each of which must be no less stringent than those applicable to national banks. As of December 31, 2003, ASB was in compliance with all of the minimum standards with a core capital ratio of 7.0%
(compared to a 4.0% requirement), a tangible capital ratio of 7.0% (compared to a 1.5% requirement) and total risk-based capital ratio of 15.6% (based on risk-based capital of $491.2 million, $239.2 million in excess of the 8.0% requirement).



Effective April 1, 1999, the OTS revised its risk-based
capital standards as part of the effort by the OTS, FDIC, the Board of Governors of the Federal Reserve System and the Office of the Comptroller of the Currency to implement the provisions of the Riegle Community Development and Regulatory
Improvement Act of 1994, which requires these agencies to work together to make uniform their respective regulations and guidelines implementing common statutory or supervisory policies. These OTS revisions affect the risk-based capital treatment
of: (1) construction loans on presold residential properties; (2) junior liens on 1- to 4-family residential properties; (3) investments in mutual funds; and (4) the core capital leverage ratio for institutions which do not have a composite rating
of 1 under the Uniform Financial Institution Rating System (i.e., the CAMELS rating system). Under the new rules, an institution with a composite rating of 1 under the CAMELS rating system must maintain core capital in an
amount equal to at least 3% of adjusted total assets. All other institutions must maintain a minimum core capital of 4% of adjusted total assets, and higher capital ratios may be required if warranted by particular circumstances. As of December 31,
2003, ASB met the applicable minimum core capital requirement of the revised OTS regulations.



Effective July 1, 2002, new OTS rules eliminated the requirement that one-to-four-family residential mortgage loans have a maximum loan-to-value ratio of not more than 80% at origination in order to qualify for a 50%
risk rate in calculating capital charges. The new rules conform OTS practice to the more flexible federal Interagency Guidelines for Real Estate Lending by requiring that qualifying mortgage loans be underwritten in accordance with prudent
underwriting standards, including standards (i) relating the amortized principal balance of the loan to the value of the property at origination and (ii) establishing acceptable forms of credit enhancement for loans exceeding loan-to-value
thresholds. In addition, the new rule eliminates the former requirement that a thrift must deduct from total capital the portion of a land loan or non-residential construction loan that exceeds an 80% loan-to-value ratio.



On January 1, 2002, new OTS regulations went into effect with respect to the
regulatory capital treatment of recourse obligations, residual interests, direct credit substitutes and asset- and mortgage-backed securities. The revised capital regulations affect institutions that (1) securitize and sell their assets but retain a
residual interest or provide recourse arrangements; (2) credit enhance third party assets; or (3) invest in third party asset- and mortgage-backed securities. Recourse obligations, residual interests, direct credit substitutes and asset- and
mortgage-backed securities are now risk-weighted based on their credit agency rating. The new regulations have had a slight positive impact on ASBs risk-based capital.



On July 1, 2002, new regulations went into effect which reduced the risk rating under the OTS risk-based capital rules
for claims on and claims guaranteed by qualifying securities firms, such as broker-dealers which are registered with the SEC and comply with net capital requirements, from 100% to 20%, and to zero percent for certain claims on qualifying
securities firms that are collateralized with, for example, cash deposits or securities issued by or guaranteed by the U.S.



Current OTS risk-based capital requirements are based on an internationally agreed framework for capital measurement (the 1988 Accord) that
was developed by the Basel Committee on Banking Supervision (BCBS). On April 29, 2003, BCBS released for comment proposed revisions to the 1988 Accord. BCBS expects to implement revisions to the 1998 Accord effective December 31, 2006.
On August 4, 2003, the federal financial institution regulatory agencies, including OTS, issued an advance notice of proposed rule making (Advance Notice) soliciting comment on possible changes to U.S. risk-based capital requirements in
light of the BCBS proposed revisions to the 1988 Accord. The Advance Notice describes the purpose of the BCBS proposal as making risk-based capital requirements more risk sensitive than are the requirements of the 1988 Accord and current U.S.
(including OTS) rules implementing the 1988 Accord. The possible changes to the U.S. rules described in the Advance Notice are greatest with respect to financial institutions with banking and thrift assets of $250 billion or more or total
on-balance-sheet foreign exposure of $10 billion or more. However, impacts on smaller financial institutions such as ASB are possible. ASB will continue to monitor regulatory developments.



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Affiliate transactions. Significant restrictions apply to certain transactions between ASB and its affiliates,
including HEI and its direct and indirect subsidiaries. FIRREA significantly altered both the scope and substance of such limitations on transactions with affiliates and provided for thrift affiliate rules similar to, but more restrictive than,
those applicable to banks. On November 27, 2002, the Federal Reserve Board (FRB) issued Regulation W, effective April 1, 2003 which, generally speaking, unifies in one public document FRBs prior interpretations of the statutory provisions
governing affiliate transactions. Although thrifts are excluded from Regulation W, on December 12, 2002, OTS issued an interim final rule, also effective April 1, 2003, which applies Regulation W to thrifts with modifications appropriate to the
greater restrictions under which thrifts operate. Most of these greater restrictions were carried over into the OTS final rule, which became effective November 6, 2003. For example, ASB is prohibited from making any loan or other extension of
credit to an entity affiliated with ASB unless the affiliate is engaged exclusively in activities which the Federal Reserve Board has determined to be permissible for bank holding companies. There are also various other restrictions which apply to
certain transactions between ASB and certain executive officers, directors and insiders of ASB. ASB is also barred from making a purchase of or any investment in securities issued by an affiliate, other than with respect to shares of a subsidiary of
ASB.



Financial Derivatives and Interest Rate Risk.In 1996, the Board
of Governors of the Federal Reserve System, the FDIC and the Office of the Comptroller of the Currency issued a joint agency policy statement to bankers to provide guidance on sound practices for managing interest rate risk. However, the OTS has
elected not to pursue a standardized policy towards interest rate risk and investment and derivatives activities with the other federal banking regulators.



On December 1, 1998, the OTS issued final rules on financial derivatives, effective January 1, 1999. The OTS views these
final rules as consistent with, although more detailed than, the 1996 joint policy statement. The purpose of these rules is to update the OTS rules on financial derivatives, which had remained virtually unchanged for over 15 years. Most
significantly, the new rules address interest rate swaps, a derivative instrument commonly used by thrifts to manage interest rate risk which was not addressed in the prior OTS rules. Currently ASB does not use interest rate swaps to manage interest
rate risk, but may do so in the future. Generally speaking, the new rules permit thrifts to engage in transactions involving financial derivatives to the extent these transactions are otherwise authorized under applicable law and are safe and sound.
The new rules have required ASB to revise its internal procedures for handling financial derivative transactions, including increased involvement of the ASB Board of Directors.



Concurrently with the issuance of the new rules of financial derivative transactions, the OTS also adopted on December 1,
1998 Thrift Bulletin 13a (TB 13a) for purpose of providing guidance on the management of interest rate risks, investment securities and derivatives activities. TB 13a also describes the guidelines OTS examiners will use in assigning the
Sensitivity to Market Risk component rating under the Uniform Financial Institutions Rating System (i.e., the CAMELS rating system). TB 13a became effective on December 1, 1998, and replaced several previous Thrift Bulletins dealing with
interest rate risk and securities activities.



Effective July
1, 2002, new OTS rules eliminated the interest rate risk component of the OTSs risk-based capital regulations. As a result of waivers granted by the Acting OTS Director, these regulations had never gone into effect and the OTS had relied
instead on the interest rate risk guidelines of TB 13a, which will continue in effect. The OTS will apply a 100% risk weight to all stripped, mortgage-related securities regardless of issuer or guarantor.



TB 13a updates the OTSs minimum standards for thrift institutions
interest rate risk management practices with regard to board-approved risk limits and interest rate risk measurement systems, and makes several significant changes. First, under TB 13a, institutions no longer set board-approved limits or provide
measurements for the plus and minus 400 basis point interest rate scenarios prescribed by the original TB 13. TB 13a also changes the form in which those limits should be expressed. Second, TB 13a provides guidance on how the OTS will assess the
prudence of an institutions risk limits. Third, TB 13a raises the size threshold above which institutions should calculate their own estimates of the interest rate sensitivity of Net Portfolio Value (NPV) from $500 million to $1 billion in
assets. Fourth, TB 13a specifies a set of desirable features that an institutions risk measurement methodology should utilize. Fifth, TB 13a provides an extensive discussion of sound practices for interest rate risk management.



TB 13a also contains guidance on thrifts investment and
derivatives activities by describing the types of analysis institutions should perform prior to purchasing securities or financial derivatives. TB13a also provides



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guidelines on the use of certain types of securities and financial derivatives for purposes other than reducing portfolio risk.



Finally, TB 13a provides detailed guidelines for implementing part of the
Notice announcing the revision of the CAMELS rating system, published by the Federal Financial Institutions Examination Council. That publication announced revised interagency policies that, among other things, established the Sensitivity to Market
Risk component rating (the S rating). TB 13a provides quantitative guidelines for an initial assessment of an institutions level of interest rate risk. Examiners have broad discretion in implementing those guidelines. It also
provides guidelines concerning the factors examiners consider in assessing the quality of an institutions risk management systems and procedures.



Liquidity. Effective July 18, 2001, the OTS removed the regulation that required a savings association to maintain an average daily balance of liquid assets of at
least 4% of their liquidity base and retained a provision requiring a savings association to maintain sufficient liquidity to ensure safe and sound operations. ASBs principal sources of liquidity are customer deposits, wholesale borrowings,
the sale of mortgage loans into the secondary market channels and the maturity and repayment of portfolio loans and mortgage-related securities. ASBs principal sources of borrowings are advances from the FHLB and securities sold under
agreements to repurchase from broker/dealers. ASB is approved by the FHLB to borrow up to 35% of assets to the extent it provides qualifying collateral and holds sufficient FHLB stock. At December 31, 2003, ASBs unused FHLB borrowing capacity
was approximately $1.3 billion. ASB utilizes growth in deposits, advances from the FHLB and securities sold under agreements to repurchase to fund maturing and withdrawable deposits, repay maturing borrowings, fund existing and future loans and make
investments. At December 31, 2003, ASB had commitments to borrowers for undisbursed loan funds and unused lines and letters of credit of $0.8 billion. Management believes ASBs current sources of funds will enable it to meet these obligations
while maintaining liquidity at satisfactory levels.



Supervision.The
adoption of FDICIA subjected the banking and thrift industries to heightened regulation and supervision. FDICIA made a number of reforms addressing the safety and soundness of the deposit insurance system, supervision of domestic and foreign
depository institutions and improvement of accounting standards. FDICIA also limited deposit insurance coverage, implemented changes in consumer protection laws and called for least-cost resolution and prompt corrective action with regard to
troubled institutions.



Pursuant to FDICIA, the federal banking
agencies promulgated regulations which apply to the operations of ASB and its holding companies. Such regulations address, for example, standards for safety and soundness, real estate lending, accounting and reporting, transactions with affiliates,
and loans to insiders.



Prompt corrective action.FDICIA establishes a
statutory framework that is triggered by the capital level of a savings association and subjects it to progressively more stringent restrictions and supervision as capital levels decline. The OTS rules implement the system of prompt corrective
action. In particular, the rules define the relevant capital measures for the categories of well capitalized, adequately capitalized, undercapitalized, significantly undercapitalized and
critically undercapitalized.



A savings association
that is undercapitalized or significantly undercapitalized is subject to additional mandatory supervisory actions and a number of discretionary actions if the OTS determines that any of the actions is necessary to resolve the
problems of the association at the least possible long-term cost to the SAIF. A savings association that is critically undercapitalized must be placed in conservatorship or receivership within 90 days, unless the OTS and the FDIC concur
that other action would be more appropriate. As of December 31, 2003, ASB was well-capitalized.



Interest rates.FDIC regulations restrict the ability of financial institutions that are undercapitalized to offer interest rates on deposits that are significantly higher than the rates offered by competing
institutions. As of December 31, 2003, ASB was well capitalized and thus not subject to these interest rate restrictions.



Qualified thrift lender test.FDICIA amended the QTL test provisions of FIRREA by reducing the percentage of assets thrifts must maintain in qualified thrift
investments from 70% to 65%, and changing the computation period to require that the percentage be reached on a monthly average basis in 9 out of the previous 12 months. The 1997 Omnibus Appropriations Act expanded the types of loans that
constitute qualified thrift investments from the traditional category of housing-related loans to include small business loans, education loans, loans made through



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credit card accounts, as well as a basket of other consumer loans and certain other types of assets not to exceed 20% of total assets. Savings associations
that fail to satisfy the QTL test by not holding the required percentage of qualified thrift investments are subject to various penalties, including limitations on their activities. Failure to satisfy the QTL test would also bring into
operation restrictions on the activities that may be engaged in by HEI, HEIDI and their other subsidiaries and could effectively result in the required divestiture of ASB. At all times during 2003, ASB was in compliance with the QTL test. As of
December 31, 2003, 88.7% of ASBs portfolio assets was qualified thrift investments. See Holding company regulation.



Federal Home Loan Bank System.ASB is a member of the FHLB System which consists of 12 regional FHLBs. The FHLB System provides a central credit facility for
member institutions. Historically, the FHLBs have served as the central liquidity facilities for savings associations and sources of long-term funds for financing housing. The FHLB may only make long-term advances to ASB for the purpose of providing
funds for financing residential housing. At such time as an advance is made to ASB or renewed, it must be secured by collateral from one of the following categories: (1) fully disbursed, whole first mortgages on improved residential property, or
securities representing a whole interest in such mortgages; (2) securities issued, insured or guaranteed by the U.S. Government or any agency thereof; (3) FHLB deposits; and (4) other real estate-related collateral that has a readily ascertainable
value and with respect to which a security interest can be perfected. The aggregate amount of outstanding advances secured by such other real estate-related collateral may not exceed 30% of ASBs capital.



As a result of the Gramm-Leach-Bliley Act, each regional FHLB is required to
formulate and submit for Federal Housing Finance Board (Board) approval a plan to meet new minimum capital standards to be promulgated by the Board. The Board issued the final regulations establishing the new minimum capital standards on January 30,
2001. As mandated by Gramm-Leach-Bliley, these regulations require each FHLB to maintain a minimum total capital leverage ratio of 5% of total assets and include risk-based capital standards requiring each FHLB to maintain permanent capital in an
amount sufficient to meet credit risk and market risk. In June 2001, the FHLB of Seattle formulated a capital plan to meet these new minimum capital standards, which plan was submitted to and approved by the Board. The capital plan requires ASB to
own capital stock in the FHLB of Seattle in an amount equal to the total of 3.5% of the FHLB of Seattles advances to ASB plus the greater of (i) 5% of the outstanding balance of loans sold to the FHLB of Seattle by ASB or (ii) 0.75% of
ASBs mortgage loans and pass through securities. At December 31, 2003, ASB was required under the capital plan to own capital stock in the FHLB of Seattle in the amount of $64.8 million and owned capital stock in the amount of $94.6 million,
or $29.8 million in excess of the requirement. Under the capital plan, stock in the FHLB of Seattle is subject to a 5-year notice of redemption. This 5-year notice period has an adverse but immaterial effect on ASBs liquidity.



Community Reinvestment.In 1977, Congress enacted the Community Reinvestment Act (CRA)
to ensure that banks and thrifts help meet the credit needs of their communities, including low- and moderate-income areas, consistent with safe and sound lending practices. The OTS will consider ASBs CRA record in evaluating an application
for a new deposit facility, including the establishment of a branch, the relocation of a branch or office, or the acquisition of an interest in another bank or thrift. On February 6, 2004, the OTS issued a notice of proposed rule making proposing
that certain discriminatory, illegal or abusive credit practices would adversely affect an institutions CRA rating. ASB currently holds an outstanding CRA rating.



Other laws.ASB is subject to federal and state consumer protection laws which affect lending activities, such as the
Truth-in-Lending Law, the Truth-in-Savings Act, the Equal Credit Opportunity Act, the Real Estate Settlement Procedures Act and several federal and state financial privacy acts. These laws may provide for substantial penalties in the event of
noncompliance. ASB believes that its lending activities are in compliance with these laws and regulations.



Environmental regulation. HEI and its subsidiaries are subject to federal and state statutes and governmental regulations pertaining to water quality, air quality and other environmental factors.



HECO, HELCO and MECO, like other utilities, are all subject to
periodic inspections by regulatory agencies. These inspections may result in the identification of items needing correction or other action. When the corrective or other necessary action is taken, no further regulatory action is expected. Except as
otherwise disclosed in this report (including in incorporated documents), the Company believes that each subsidiary has taken appropriate



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action on environmental conditions requiring action and that as a result of such actions, the environmental condition will not have a material adverse effect
on consolidated HECO or the Company.



Water quality controls.As part of
the process of generating electricity, water used for condenser cooling of the electric utility subsidiaries steam electric generating stations is discharged into ocean waters or into underground injection wells. The subsidiaries are
periodically required to obtain permits from the DOH in order to be allowed to discharge the water, including obtaining permit renewals for existing facilities and new permits for new facilities. The electric utility subsidiaries must obtain
National Pollutant Discharge Elimination System (NPDES) permits from the DOH to allow wastewater and storm water discharges into state and federal waters for their coastal generating stations and Underground Injection Control (UIC) permits for
wastewater discharge to underground injection wells for one MECO facility and several HELCO facilities.



In 2003, the DOH conducted NPDES permit compliance inspections at HELCOs Shipman generating station, HECOs Honolulu generating station, and
HECOs Waiau generating station. All facilities were found to be in compliance with NPDES permit requirements.



Section 316(b) of the Clean Water Act requires that the EPA ensure that the location, design, construction and capacity of power plant cooling water
intake structures reflect the best technology available for minimizing adverse environmental impacts. On February 16, 2004, the EPA Administrator signed a final regulation implementing Section 316(b). The regulation establishes location, design,
construction and capacity standards for existing cooling water intake systems that use large amounts of cooling water. Strong technology-based performance standards apply unless a facility shows that these standards will result in very high costs or
little environmental benefit at the facility site. EPA estimates that the rule affects approximately 550 facilities across the nation. The new rule, which is currently pending publication in the Federal Register, becomes effective 60 days after
publication and will apply to HECOs Kahe, Waiau and Honolulu generating stations. HECO will have 3.5 years from the effective date of the rule to demonstrate compliance. HECO is currently preparing and will conduct a monitoring program and
cost-benefit analysis to demonstrate that HECOs existing intake systems have minimal environmental impacts. Concurrently, HECO will evaluate alternative compliance mechanisms allowed by the rule, some of which could entail significant costs to
implement. HECO has not yet budgeted any such costs in its five-year capital expenditures forecast.



In 1994, HELCO constructed two UIC-permitted injection wells designed to receive wastewater from CT-4 and CT-5 once they become operational, as well as
from other existing activities at the Keahole power plant. Although these wells were installed and the UIC permit issued, the associated piping connections to the wells were not made due to anticipation of the forthcoming CT-4 and CT-5 generation
additions. In connection with the preconstruction stay originally issued for CT-4 and CT-5, HELCO registered the UIC wells as inactive. Because the land issue matter with CT-4 and CT-5 appeared to be resolved and construction activities resumed in
May 2002, HELCO submitted an application to DOH to reactivate the UIC permit for these wells. This application was put on hold following an October 2002 order of the Circuit Court for the Third Circuit of Hawaii that again halted construction.
Existing wastewater management activities did not require a UIC permit and were planned to be rerouted to the injection wells as a process improvement. After the Third Circuit Court vacated its construction stop order on November 12, 2003 (see Note
11 to HECOs Consolidated Financial Statements), a request was submitted to the DOH to resume processing the UIC permit and the UIC permit was issued to HELCO in the first quarter of 2004.



In 2000, the EPA introduced new regulations that prohibit the construction of
large capacity cesspools, many of which are regulated under the DOHs UIC permitting program. All large capacity cesspools must be permanently closed by April 2005. Some alternatives to using large capacity cesspools include connecting to
existing municipal sanitary sewer systems or installing large capacity septic treatment systems. HECO, MECO and HELCO are in the process of closing cesspools at the Kahe, Maalaea and Kahului generating stations and the Kanoelehua Base Yard. These
cesspools will be replaced with septic tank treatment systems. All companies are on schedule to comply with the April 2005 deadline.



The Federal Oil Pollution Act of 1990 (OPA) governs actual or threatened oil releases in navigable U.S. waters (inland waters and up to three miles
offshore) and waters of the U.S. exclusive economic zone (up to 200 miles to sea from the shoreline). In the event of an oil release to navigable U.S. waters, OPA establishes strict and joint and several liability for responsible parties for 1) oil
removal costs incurred by the federal government or the state, and 2) damages to natural resources and real or personal property. Responsible parties include vessel owners and



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operators of on-shore facilities. OPA imposes fines and jail terms ranging in severity depending on how the release was caused. OPA also requires that
responsible parties submit certificates of financial responsibility sufficient to meet the responsible partys maximum limited liability. HECO is currently involved in an ongoing investigation of the Honolulu Harbor area. (See Note 11 to
HECOs Consolidated Financial Statements.) Under the terms of the agreement for the sale of YB, HEI and TOOTS had certain environmental obligations arising from conditions existing prior to the sale of YB, including obligations with respect to
the Honolulu Harbor investigation. In 2003, TOOTS paid $250,000 in full settlement of this environmental obligation. See Note 3 to HEIs Consolidated Financial Statements.



EPA regulations under OPA also require that certain facilities that store petroleum prepare and implement Spill Prevention,
Containment and Countermeasure (SPCC) Plans in order to prevent releases of petroleum to navigable waters of the U.S. HECO, HELCO and MECO facilities subject to the SPCC program are in compliance with these requirements. On July 17, 2002, EPA
amended the SPCC regulations to include facilities, such as substations, that use (as opposed to store) petroleum products. HECO, HELCO and MECO have determined that the amended SPCC program applies to a number of their substations. By interim final
rule issued January 9, 2003, the EPA amended the revised regulations, which required development of the SPCC plans for affected facilities by April 17, 2003, and implementation of the plans by October 18, 2003. Concurrently, the EPA proposed a rule
to further extend compliance dates for the amended regulations by one year. On April 17, 2003, EPA issued its final rules that included an 18-month extension to the rules compliance dates. The longer time frame was intended to address concerns
raised by the regulated community, and to avoid a potentially overwhelming number of individual extension requests. The new compliance dates are August 17, 2004, to amend an existing SPCC Plan, and February 18, 2005, to implement the Plan. Regulated
facilities that start operations after August 16, 2002, through February 18, 2005, must prepare and implement an SPCC Plan by February 18, 2005. HECO, HELCO and MECO are currently developing SPCC plans for all facilities that are subject to the
amended SPCC requirements.



Air quality controls.The generating
stations of the utility subsidiaries operate under air pollution control permits issued by the DOH and, in a limited number of cases, by the EPA. The entire electric utility industry has been affected by the 1990 amendments to the Clean Air Act
(CAA), changes to the National Ambient Air Quality Standard (NAAQS) for ozone, and adoption of a NAAQS for fine particulate matter. Further significant impacts may occur if currently proposed legislation, rules and standards are adopted. If the
Clear Skies Bill is adopted as currently proposed, HECO, and to a lesser extent, HELCO and MECO will likely incur significant capital and operations and maintenance costs beginning one to two years after enactment. HECO boilers may be affected by
the air toxics provisions (Title III) of the CAA when the Maximum Allowable Control Technology (MACT) emission standards are established for those units. HECO believes that, if adopted as currently proposed, the recent EPA proposal to regulate
nickel emissions from oil-fired boilers may require significant capital investment for HECOs steam generating units. The public comment period on the proposed rule ends on March 30, 2004.



CAA operating permits (Title V permits) have been issued for all affected
generating units except for HELCOs Keahole CT-2, for which a permit is currently pending. Initial and follow-up source tests in 1989 and 1990 for HELCOs CT-2 generating unit indicated particulate emissions above permitted levels.
Following analysis, HECO (on behalf of HELCO) proposed that the permitted particulate limit be increased. EPA concurred with the recommendation. HECO and HELCO worked with the DOH, the manufacturer and a consultant to determine an appropriate new
emission limit for particulates as well as oxides of nitrogen. DOH prepared a draft permit incorporating the revised emission standards that was the subject of a public hearing on January 7, 2002. EPA is currently reviewing the draft permit and
HELCO anticipates EPAs approval. CT-2 continues to operate pending issuance of the revised permit. In 1998, HELCO settled two notice of violations (NOVs) issued by the DOH in 1992 and 1998 for non-compliance with emission limits during various
periods from 1990 through 1997. CT-2 is currently operating within all existing permit limits by virtue of its having passed its annual source tests since 1997.



On September 5, 2003, MECO received a NOV issued by the DOH alleging violations of opacity conditions in permits issued under the DOHs Air
Pollution Control Law for two generating units at MECOs Maalaea Power Plant. The NOV ordered MECO to immediately take corrective action to prevent further opacity incidents and pay a penalty of $1.6 million, unless MECO submitted a written
request for a hearing. In September 2003, MECO submitted a request for hearing and accrued $1.6 million for the potential penalty. An environmental penalty or a settlement of an environmental penalty is not tax deductible. On December 23, 2003, the
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a conditional settlement of the NOV, subject to public notice and a comment period, which ended on February 26, 2004 with no comments. The settlement
consists of a Proposed Consent Order that requires MECO to come into full compliance with the opacity rules for the units by December 31, 2004 and to pay a penalty of approximately $0.8 million to the DOH. The Proposed Consent Order would resolve
all civil liability of MECO to the DOH for all opacity violations from February 1, 1999 to December 31, 2004. MECO has made significant progress in reducing the number of opacity exceedances from Maalaea Units 12 and 13 and expects to achieve full
compliance with the opacity regulations during the Proposed Consent Order period without having to incur significant additional costs. The Consent Order (in the proposed form) is expected to be executed in March 2004.



Hazardous waste and toxic substances controls.The operations of the electric utility
and former freight transportation subsidiaries are subject to regulations promulgated by the EPA to implement the provisions of the Resource Conservation and Recovery Act (RCRA), the Superfund Amendments and Reauthorization Act and the Toxic
Substances Control Act. In 2001, the DOH obtained primacy to operate state-authorized RCRA (hazardous waste) programs. The DOHs state contingency plan and the State of Hawaii Environmental Response Law (ERL) rules were adopted in August 1995.



On both federal and state levels, RCRA provisions identify
certain wastes as hazardous and set forth measures that must be taken in the transportation, storage, treatment and disposal of these wastes. Some wastes generated at steam electric generating stations possess characteristics that subject them to
these EPA regulations. Since October 1986, all HECO generating stations have operated RCRA-exempt wastewater treatment units to treat potentially regulated wastes from occasional boiler waterside and fireside cleaning operations. Steam generating
stations at MECO and HELCO also operate similar RCRA-exempt wastewater management systems.



The EPA issued a final regulatory determination on May 22, 2000, concluding that fossil fuel combustion wastes do not warrant regulation as hazardous under Subtitle C of RCRA. This determination retains (or maintains)
the existing hazardous waste exemption for these types of wastes. It also allows for more flexibility in waste management strategies. The electric utilities waste characterization programs continue to demonstrate the adequacy of the existing
treatment systems. Waste recharacterization studies indicate that treatment facility wastestreams are nonhazardous.



RCRA underground storage tank (UST) regulations require all facilities with USTs used for storing petroleum products to comply with costly leak detection,
spill prevention and new tank standard retrofit requirements. All HECO, HELCO and MECO USTs currently meet these standards and continue in operation. In 2003, the DOH conducted UST compliance inspections at HECOs Ward Avenue Complex, Koolau
base yard and Waiau generating station, and at HELCOs Kanoelehua base yard. All facilities were found to be in compliance with UST requirements.



The DOH conducted RCRA compliance inspections at HECOs Ward Avenue Complex and MECOs Kahului Base Yard on October 3, 2003 and December 19,
2003, respectively. HECO addressed cited deficiencies at the Ward facility, while additional information is being prepared for submittal to the DOH for the Kahului Base Yard inspection. Neither facility anticipates enforcement action from the DOH.
In October 2003, the DOH and EPA initiated separate investigations at HECOs Waiau Generating Station for the alleged offsite transport, treatment and disposal of hydrochloric acid by a HECO contractor. As of February 13, 2004, HECO submitted
responses to all DOH requests for information relating to this matter and HECO is currently awaiting a response from the DOH. A decision about possible enforcement action by the DOH is still pending. At this time, HECO anticipates that the EPA will
not be pursuing separate enforcement action regarding this incident.



The Emergency Planning and Community Right-to-Know Act under Superfund Amendments and Reauthorization Act Title III requires HECO, MECO and HELCO to report potentially hazardous chemicals present in their facilities in order to provide the
public with information on these chemicals so that emergency procedures can be established to protect the public in the event of hazardous chemical releases. All HECO, MECO and HELCO facilities are in compliance with applicable annual reporting
requirements to the State Emergency Planning Commission, the Local Emergency Planning Committee and local fire departments. Since January 1, 1998, the steam electric industry category has been subject to Toxics Release Inventory (TRI) reporting
requirements. HECO, MECO and HELCO have timely filed release reports since 1998. In November 2002, the Company identified several discrepancies in previous TRI reports and submitted corrected reports to the EPA in February and August 2003.



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The Toxic Substances Control Act regulations specify procedures for the handling and disposal of
polychlorinated biphenyls (PCB), a compound found in transformer and capacitor dielectric fluids. HECO, MECO and HELCO have instituted procedures to monitor compliance with these regulations. In addition, HECO and its subsidiaries have implemented a
program to identify and replace PCB transformers and capacitors in the HECO system. In 1998, the EPA published the final rule on the PCB disposal amendments. The amended rule clarified certain procedures and provides some flexibility within the
context of a complex regulatory program governing the use, handling and disposal of equipment and materials containing PCBs. The EPA believes that this rule will result in substantial cost savings to the regulated community while protecting against
unreasonable risk of injury to health and the environment from exposure to PCBs. On October 21, 2003, HECO voluntarily notified the EPA of a minor one-year storage violation regarding a single drum containing PCB-contaminated debris. The EPA issued
a warning letter to HECO on December 3, 2003. HECO subsequently provided the EPA with follow-up information to document the appropriate disposal of the drum. The EPA has indicated it will take no further enforcement action on this matter. All HECO,
MECO and HELCO facilities are currently believed to be in compliance with PCB regulations.



The ERL, as amended, governs releases of hazardous substances, including oil, in areas within the states jurisdiction. Responsible parties under the ERL are jointly, severally and strictly liable for a release
of a hazardous substance into the environment. Responsible parties include owners or operators of a facility where a hazardous substance comes to be located and any person who at the time of disposal of the hazardous substance owned or operated any
facility at which such hazardous substance was disposed. The DOH issued final rules (or State Contingency Plan) implementing the ERL on August 17, 1995.



On July 30, 2002, personnel at MECOs Maalaea Generating Station discovered a leak in an underground diesel fuel line. MECO immediately discontinued
using the fuel line and notified the DOH of the release. MECO replaced the leaking fuel line with a temporary aboveground line and then constructed a new aboveground fuel line and concrete containment trough as a permanent replacement. MECO also
notified the U.S. Fish & Wildlife Service (USFWS), which manages the Kealia Pond National Wildlife Refuge that is located south of the Maalaea facility. MECO constructed a sump at the point of the leak to remove fuel from the subsurface. To
date, MECO has recovered over 11,600 gallons of diesel fuel from the estimated 19,000-gallon release. In addition, MECO has installed soil borings and groundwater monitoring wells to assess the vertical and horizontal impacts of the fuel release.
The investigation indicates that limited free phase fuel migration has occurred beneath the Maalaea facility and in a small portion of the buffer zone immediately to its south. The buffer zone is undeveloped property owned by MECO that separates the
Maalaea facility from the Wildlife Refuge. Although monitoring wells indicate diesel fuel likely migrated to a small portion of the Wildlife Refuge that shares a common boundary with the facility, wells installed in the Wildlife Refuge itself
indicate that migration has not been significant in that area. As a precautionary measure, with the guidance and consent of the USFWS and the DOH, MECO installed an interception trench in the buffer zone and in a small part of the Wildlife Refuge.
The interception trench is designed to capture and facilitate removal of any fuel migrating from the impacted areas and to act as a barrier to migration beyond the trench. Based on results of the latest monitoring study in December 2003, the
interception trench continues to operate as designed. Based on the results of the subsurface investigation and the location and design of the interception trench, management believes that the risk of the fuel release affecting wildlife, sensitive
wildlife habitat or the ocean, which lies approximately one-quarter mile south of the Maalaea facility, is minimal. MECO estimates that it will incur approximately $0.8 million to successfully remediate the impacts of the release, and expensed the
$0.8 million in 2002.



HECO, HELCO and MECO, like other
utilities, periodically identify leaking petroleum-containing equipment such as USTs, piping and transformers. In a few instances, small amounts of PCBs have been identified in the leaking equipment. Each subsidiary reports releases from such
equipment when and as required by applicable law and addresses impacts due to the releases in compliance with applicable regulatory requirements. Except as otherwise disclosed herein, the Company believes that each subsidiarys costs of
responding to any such releases to date will not have a material adverse effect on the respective subsidiary or the Company.



ASB may be subject to the provisions of Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) and regulations promulgated
thereunder. CERCLA imposes liability for environmental cleanup costs on certain categories of responsible parties, including the current owner and operator of a facility and prior owners or operators who owned or operated the facility at the time
the hazardous substances were released or disposed.



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CERCLA exempts persons whose ownership in a facility is held primarily to protect a security interest, provided that they do not participate in the
management of the facility. Although there may be some risk of liability for ASB for environmental cleanup costs in the event ASB forecloses on, and becomes the owner of, property with environmental problems, the Company believes the risk is not as
great for ASB as it may be for other depository institutions that have a larger portfolio of commercial loans.



Securities ratings



See
Liquidity and capital resources in HEIs MD&A for the Standard & Poors (S&P) and Moodys Investors Services (Moodys) ratings of HEIs and HECOs securities. These ratings are not
recommendations to buy, sell or hold any securities; such ratings may be subject to revision or withdrawal at any time by the rating agencies; and each rating should be evaluated independently of any other rating. These ratings reflect only the view
of the applicable rating agency at the time the ratings are issued, from whom an explanation of the significance of such ratings may be obtained. There is no assurance that any such credit rating will remain in effect for any given period of time or
that such rating will not be lowered, suspended or withdrawn entirely by the applicable rating agency if, in such rating agencys judgment, circumstances so warrant. Any such lowering, suspension or withdrawal of any rating may have an adverse
effect on the market price or marketability of HEIs and/or HECOs securities, which could increase the cost of capital of HEI and HECO. Neither HEI nor HECO management can predict future rating agency actions or their effects on the
future cost of capital of HEI or HECO.



Revenue bonds are
issued by the Department of Budget and Finance of the State of Hawaii for the benefit of HECO and its subsidiaries, but the source of their repayment are the unsecured obligations of HECO and its subsidiaries under loan agreements and notes issued
to the Department, including HECOs guarantees of its subsidiaries obligations. The payment of principal and interest due on all revenue bonds currently outstanding are insured either by MBIA Insurance Corporation, by Ambac Assurance
Corporation, or by XL Capital Assurance, Inc. and the ratings of those bonds are based on the ratings of the obligations of the bond insurer rather than HECO.



Research and development



HECO and its subsidiaries expensed approximately $3.1 million, $2.8 million and $2.6 million in 2003, 2002 and 2001, respectively, for research and
development. Contributions to the Electric Power Research Institute accounted for more than half of the expenses. There were also expenses in the areas of energy conservation, new technologies, environmental and emissions controls, and expenses for
studies relative to technologies that are applicable or may be applicable in the future to HECO, its subsidiaries and their customers.



Employee relations



At December 31, 2003 and 2002, the Company had 3,197 and 3,220 full-time employees, respectively, as follows:



|                          |  |       |  |      
|------------------------- |  | ----- |  | -----
|December 31               |  | 2003  |  | 2002 
|HEI                       |  | 44    |  | 44   
|HECO and its subsidiaries |  | 1,862 |  | 1,894
|ASB and its subsidiaries  |  | 1,285 |  | 1,272
|Other subsidiaries        |  | 6     |  | 10   
|                          |  |       |  |      
|                          |  | 3,197 |  | 3,220
|                          |  |       |  |      



The employees of HEI
and its direct and indirect subsidiaries, other than the electric utilities, are not covered by any collective bargaining agreement. Of the 1,862 full time employees of HECO and its subsidiaries at December 31, 2003 approximately 59% were covered by
collective bargaining agreements. See Collective bargaining agreements in HECOs MD&A.



43



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|ITEM 2. | PROPERTIES
|------- | ----------



HEI leases office space from a nonaffiliated lessor in downtown Honolulu under a lease that expires on March 31, 2006. HEI also subleases office space from HECO in downtown Honolulu. The properties of
HEIs subsidiaries are as follows:



Electric utility



See page 5 for the Generation statistics of
HECO and its subsidiaries, including net generating and firm purchased capability, reserve margin and annual load factor.



The electric utilities overhead and underground transmission and distribution systems (with the exception of substation buildings and contents) have
a replacement value roughly estimated at $2 billion and are uninsured because the amount of transmission and distribution system insurance available is limited and the premiums are extremely high.



Electric lines are located over or under public and nonpublic properties. See
page 2 for a discussion of the nonexclusive franchises of HECO and subsidiaries. Most of the leases, easements and licenses for HECOs, HELCOs and MECOs lines have been recorded.



HECO owns and operates three generating plants on the island of Oahu at Honolulu,
Waiau and Kahe, with an aggregate net generating capability of 1,208.6 MW at December 31, 2003. The three plants are situated on HECO-owned land having a combined area of 535 acres and one 3 acre parcel of land under a lease expiring December 31,
2018. In addition, HECO owns a total of 123 acres of land on which substations, transformer vaults, distribution baseyards and the Kalaeloa cogeneration facility are located.



HECO owns overhead transmission lines, overhead distribution lines, underground cables, poles (fully owned or jointly owned)
and steel or aluminum high voltage transmission towers. The transmission system operates at 46,000 volts and 138,000 volts. The total capacity of HECOs transmission and distribution substations was 6,656,300-kilovoltamperes at December 31,
2003.



HECO owns buildings and approximately 11.5 acres of land
located in Honolulu which houses its operating, engineering and information services departments and a warehousing center. It also leases an office building and certain office spaces in Honolulu. The lease for the office building expires in November
2004, with an option to further extend the lease to November 2014. The leases for certain office spaces expire on various dates through November 30, 2007 with options to extend to various dates through November 30, 2017.



HECO owns 19.2 acres of land at Barbers Point used to situate fuel oil
storage facilities with a combined capacity of 970,700 barrels. HECO also owns fuel oil tanks at each of its plant sites with a total maximum usable capacity of 844,600 barrels.



HELCO owns and operates five generating plants on the island of Hawaii. These plants at Hilo (2), Waimea, Kona and Puna have an
aggregate net generating capability of 146.1 MW as of December 31, 2003 (excluding a small run-of-river hydro unit and one small windfarm). The plants are situated on HELCO-owned land having a combined area of approximately 43 acres. HELCO also owns
6 acres of land in Kona, which is used for a baseyard, and one acre of land in Hilo, which houses its administrative offices. HELCO also leases 4 acres of land for its baseyard in Hilo under a lease expiring in 2030. The deeds to the sites located
in Hilo contain certain restrictions which do not materially interfere with the use of the sites for public utility purposes. HELCO occupies 78 acres of land for the windfarm, pursuant to a long-term operating agreement.



MECO owns and operates two generating plants on the island of Maui, at Kahului and
Maalaea, with an aggregate net generating capability of 229.2 MW as of December 31, 2003. The plants are situated on MECO-owned land having a combined area of 28.6 acres. MECO also owns fuel oil storage facilities at these sites with a total maximum
usable capacity of 176,355 barrels. MECO owns two 1 MW stand-by diesel generators and a 6,000 gallon fuel storage tank located in Hana. MECO owns 65.7 acres of undeveloped land at Waena. The Waena land is currently being used for agricultural
purposes by the former landowner under a license agreement dated November 19, 1996. The license agreement was originally scheduled to expire on December 31, 2004 but has been extended, effective January 1, 2005, on a month-to-month basis until the
area is required for development by MECO for utility purposes, or February 28, 2006, whichever comes first.



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MECOs administrative offices and engineering and distribution departments are located on 9.1 acres
of MECO-owned land in Kahului.



MECO also owns and operates
smaller distribution systems, generation systems (with an aggregate net capability of 22.1 MW as of December 31, 2003) and fuel storage facilities on the islands of Lanai and Molokai, primarily on land owned by MECO.



Bank



ASB owns and leases several office buildings in downtown Honolulu and owns land and an operations center in the Mililani Technology
Park on Oahu.



The following table sets forth the number of
bank branches owned and leased by ASB by island:



|                  |  |                    |  |        |  |      
|----------------- |  | ------------------ |  | ------ |  | -----
|                  |  | Number of branches
|December 31, 2003 |  | Owned              |  | Leased |  | Total
|Oahu              |  | 8                  |  | 39     |  | 47   
|Maui              |  | 3                  |  | 5      |  | 8    
|Kauai             |  | 3                  |  | 3      |  | 6    
|Hawaii            |  | 2                  |  | 4      |  | 6    
|Molokai           |  |                   |  | 1      |  | 1    
|                  |  |                    |  |        |  |      
|                  |  | 16                 |  | 52     |  | 68   
|                  |  |                    |  |        |  |      



At December 31, 2003,
the net book value of branches and office facilities is approximately $43 million. Of this amount, $34 million represents the net book value of the land and improvements for the branches and office facilities owned by ASB and $9 million represents
the net book value of ASBs leasehold improvements. The leases expire on various dates from January 2004 through July 2033 and many of the leases have extension provisions.



|ITEM 3. | LEGAL PROCEEDINGS
|------- | -----------------



Except as identified in Item 1. Business, including information incorporated by reference in Item 1, there are no known material pending legal
proceedings to which HEI or any of its subsidiaries is a party or to which any of their property is subject. Certain HEI subsidiaries are involved in ordinary routine litigation incidental to their respective businesses.



Discontinued operations



See Note 13 to HEIs Consolidated Financial Statements.



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##### Table of Contents

|ITEM 4. | SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
|------- | ---------------------------------------------------



HEI and HECO:



During the fourth quarter of 2003, no matters were submitted to a vote of security holders of the Registrants.



EXECUTIVE OFFICERS OF THE REGISTRANT (HEI)



The following persons are, or may be deemed to be, executive officers of HEI. Their ages are given as of February 11, 2004 and their years of company service are given as of December 31, 2003. Officers are appointed to serve until the
meeting of the HEI Board of Directors after the next Annual Meeting of Shareholders (which will occur on April 20, 2004) and/or until their successors have been appointed and qualified (or until their earlier resignation or removal). Company service
includes service with an HEI subsidiary.



|                                                                                                                                                                                                                                                                                                                   |  |                                        
|------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------ |  | ---------------------------------------
|HEI Executive Officers                                                                                                                                                                                                                                                                                             |  | Business experience for past five years
|Robert F. Clarke, age 61                                                                                                                                                                                                                                                                                           |  |                                        
|Chairman of the Board, President and Chief Executive Officer                                                                                                                                                                                                                                                       |  | 9/98 to date                           
|Director                                                                                                                                                                                                                                                                                                           |  | 4/89 to date                           
|(Company service: 16 years)                                                                                                                                                                                                                                                                                        |  |                                        
|                                                                                                                                                                                                                                                                                                                   | 
|Eric K. Yeaman, age 36                                                                                                                                                                                                                                                                                             |  |                                        
|Financial Vice President, Treasurer and Chief Financial Officer                                                                                                                                                                                                                                                    |  | 01/03 to date                          
|(Company service: 11 1⁄2 months)                                                                                                                                                                                                                                                                                     |  |                                        
|Eric K. Yeaman, prior to joining HEI, served as Chief Operating and Financial Officer of Kamehameha Schools from 4/02 to 1/03, Chief Financial Officer of
Kamehameha Schools from 7/00 to 4/02 and Senior Manager  Audit and Advisory Services of Arthur Andersen LLP (at Arthur Andersen LLP from 9/89 to 7/00). |  |                                        
|                                                                                                                                                                                                                                                                                                                   | 
|Peter C. Lewis, age 69                                                                                                                                                                                                                                                                                             |  |                                        
|Vice President  Administration and Corporate Secretary                                                                                                                                                                                                                                                            |  | 1/99 to date                           
|(Company service: 35 years)                                                                                                                                                                                                                                                                                        |  |                                        
|                                                                                                                                                                                                                                                                                                                   | 
|Charles F. Wall, age 64                                                                                                                                                                                                                                                                                            |  |                                        
|Vice President and Corporate Information Officer                                                                                                                                                                                                                                                                   |  | 7/90 to date                           
|(Company service: 13 years)                                                                                                                                                                                                                                                                                        |  |                                        
|                                                                                                                                                                                                                                                                                                                   | 
|Andrew I. T. Chang, age 64                                                                                                                                                                                                                                                                                         |  |                                        
|Vice President  Government Relations                                                                                                                                                                                                                                                                              |  | 4/91 to date                           
|(Company service: 18 years)                                                                                                                                                                                                                                                                                        |  |                                        
|                                                                                                                                                                                                                                                                                                                   | 
|Curtis Y. Harada, age 48                                                                                                                                                                                                                                                                                           |  |                                        
|Controller                                                                                                                                                                                                                                                                                                         |  | 1/91 to date                           
|(Company service: 14 years)                                                                                                                                                                                                                                                                                        |  |                                        



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##### Table of Contents

|                                                                                          |  |                                       
|----------------------------------------------------------------------------------------- |  | --------------------------------------
|HEI Executive Officers                                                                    |  | Business experiencefor past five years
|(continued)                                                                               |  |                                       
|                                                                                          | 
|T. Michael May, age 57                                                                    |  |                                       
|President and Chief Executive Officer, Hawaiian Electric Company, Inc.                    |  | 9/95 to date                          
|Director, Hawaiian Electric Industries, Inc.                                              |  | 9/95 to date                          
|Senior Vice President, Hawaiian Electric Industries, Inc.                                 |  | 9/95 to 4/01                          
|(Company service: 11 years)                                                               |  |                                       
|                                                                                          | 
|Constance H. Lau, age 51                                                                  |  |                                       
|President and Chief Executive Officer, American Savings Bank, F.S.B.                      |  | 6/01 to date                          
|Director, Hawaiian Electric Industries, Inc.                                              |  | 6/01 to date                          
|Senior Executive Vice President and Chief Operating Officer,American Savings Bank, F.S.B. |  | 12/99 to 6/01                         
|Treasurer, Hawaiian Electric Industries, Inc.                                             |  | 4/89 to 10/99                         
|(Company service: 19 years)                                                               |  |                                       



HEIs executive
officers, with the exception of Charles F. Wall and Andrew I. T. Chang, are also officers and/or directors of one or more of HEIs subsidiaries. Mr. May and Ms. Lau are deemed to be executive officers of HEI for purposes of this Item under the
definition of Rule 3b-7 of the SECs General Rules and Regulations under the Securities Exchange Act of 1934.



There are no family relationships between any executive officer of HEI and any other executive officer or director of HEI or any arrangements or
understandings, between any executive officer or director of HEI and any person, pursuant to which the executive officer or director of HEI was selected.



PART II



|ITEM 5. | MARKET FOR REGISTRANTS COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
|------- | ---------------------------------------------------------------------



HEI:



The information required by this item is incorporated herein by reference to pages 3, 83 (Note 11, Regulatory restrictions on net assets) and
88 (Note 15, Quarterly information (unaudited)) of HEIs Consolidated Financial Statements. Certain restrictions on dividends and other distributions of HEI are described in this report under Item 1. BusinessRegulation
and other mattersRestrictions on dividends and other distributions. HEIs common stock is traded on the New York Stock Exchange and the total number of holders of record of HEI common stock as of February 11, 2004, was 13,884.



In 2003, HEI issued an aggregate of 8,100 shares of
unregistered common stock pursuant to the HEI 1990 Nonemployee Director Stock Plan, as amended and restated effective May 1, 2002 (the HEI Nonemployee Director Plan). Under the HEI Nonemployee Director Plan, each HEI nonemployee director receives,
in addition to an annual cash retainer, an annual stock grant of 600 shares of HEI common stock (1,000 shares for the first time grant to a new HEI director) and each nonemployee subsidiary director who is not also an HEI nonemployee director
receives an annual stock grant of 300 shares of HEI common stock. The HEI Nonemployee Director Plan is currently the only plan for nonemployee directors and provides for annual stock grants (described above) and annual cash retainers for nonemployee
directors of HEI and its subsidiaries.



HEI did not register
the shares issued under the director stock plan since their issuance did not involve a sale as defined under Section 2(3) of the Securities Act of 1933, as amended. Participation by nonemployee directors of HEI and subsidiaries in the
director stock plans is mandatory and thus does not involve an investment decision.



47



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##### Table of Contents

Equity compensation plan information



Information as of December 31, 2003 about HEI common stock that may be issued upon the exercise of awards granted under all
of the Companys equity compensation plans was as follows:



|                                                   |  |                                                                                                     |  |                                                                                 |       |                                                                                                                                                     |          
|-------------------------------------------------- |  | --------------------------------------------------------------------------------------------------- |  | ------------------------------------------------------------------------------- | ----- | --------------------------------------------------------------------------------------------------------------------------------------------------- | ---------
|Plan category                                      |  | (a) Number of securities to be issued upon exercise of outstanding options, warrants and rights (1) |  | (b) Weighted-average exercise price of outstanding options, warrants and rights |       | (c) Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) (2)
|Equity compensation plans approved by shareholders |  | 849,039                                                                                             |  | $                                                                               | 38.04 |                                                                                                                                                     | 2,271,436
|                                                   |  |                                                                                                     |  |                                                                                 |       |                                                                                                                                                     |          



|(1) | This represents the number of shares under options outstanding as of December 31, 2003 and dividend equivalent shares accrued as of December 31, 2003 under such
options.
|--- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(2) | This represents the number of shares remaining available as of December 31, 2003, including 2,236,297 under the 1987 Stock Option and Incentive Plan of HEI as
amended and restated effective January 21, 2003 and 35,139 under the HEI Nonemployee Director Plan.
|--- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



HECO:



The information required with respect to Market information and holders is not applicable to HECO. Since the corporate restructuring on July 1, 1983, all the common stock of HECO has been held
solely by its parent, HEI, and is not publicly traded.



The
dividends declared and paid on HECOs common stock for the four quarters of 2003 and 2002 were as follows:



|               |  |      |            |      |   |           
|-------------- |  | ---- | ---------- | ---- | - | ----------
|Quarters ended |  | 2003 |            | 2002
|March 31       |  | $    | 15,290,000 |      | $ | 9,233,000 
|June 30        |  |      | 13,242,000 |      |   | 10,180,000
|September 30   |  |      | 13,917,000 |      |   | 11,925,000
|December 31    |  |      | 15,270,000 |      |   | 12,805,000



See the discussion of
regulatory restrictions on distributions in Note 12 to HECOs Consolidated Financial Statements.



|ITEM 6. | SELECTED FINANCIAL DATA
|------- | -----------------------



HEI:



The information required by this item is incorporated herein by reference to page 3 of HEIs Annual Report.



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##### Table of Contents

HECO:

Selected
Financial Data



Hawaiian Electric Company, Inc. and Subsidiaries



|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|-------------------------------------------------------- |  | ---- | ---------- | - | ---- | - | ---------- | ---- |  | - | ---------- | - |  | ---- | ---------- | - |  | - | --------- | -
|Years ended December 31                                  |  | 2003 |            |   | 2002 |   |            | 2001 |  |   | 2000       |   |  | 1999 |           
|(in thousands)                                           |  |      |            |   |      |   |            |      |  |   |            |   |  |      |           
|Income statement data                                    |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Operating revenues                                       |  | $    | 1,393,038  |   |      | $ | 1,252,929  |      |  | $ | 1,284,312  |   |  | $    | 1,270,635  |   |  | $ | 1,050,323 |  
|Operating expenses                                       |  |      | 1,268,200  |   |      |   | 1,117,772  |      |  |   | 1,148,980  |   |  |      | 1,137,474  |   |  |   | 927,482   |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Operating income                                         |  |      | 124,838    |   |      |   | 135,157    |      |  |   | 135,332    |   |  |      | 133,161    |   |  |   | 122,841   |  
|Other income                                             |  |      | 6,170      |   |      |   | 7,095      |      |  |   | 7,436      |   |  |      | 9,935      |   |  |   | 8,054     |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Income before interest and other charges                 |  |      | 131,008    |   |      |   | 142,252    |      |  |   | 142,768    |   |  |      | 143,096    |   |  |   | 130,895   |  
|Interest and other charges                               |  |      | 51,017     |   |      |   | 50,967     |      |  |   | 53,388     |   |  |      | 54,730     |   |  |   | 54,495    |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Income before preferred stock dividends of HECO          |  |      | 79,991     |   |      |   | 91,285     |      |  |   | 89,380     |   |  |      | 88,366     |   |  |   | 76,400    |  
|Preferred stock dividends of HECO                        |  |      | 1,080      |   |      |   | 1,080      |      |  |   | 1,080      |   |  |      | 1,080      |   |  |   | 1,178     |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Net income for common stock                              |  | $    | 78,911     |   |      | $ | 90,205     |      |  | $ | 88,300     |   |  | $    | 87,286     |   |  | $ | 75,222    |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|                                                         |  |      |            |   |     
|At December 31                                           |  | 2003 |            |   | 2002 |   |            | 2001 |  |   | 2000       |   |  | 1999 |           
|(dollars in thousands)                                   |  |      |            |   |      |   |            |      |  |   |            |   |  |      |           
|Balance sheet data                                       |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Utility plant                                            |  | $    | 3,531,299  |   |      | $ | 3,381,316  |      |  | $ | 3,270,855  |   |  | $    | 3,162,779  |   |  | $ | 3,034,517 |  
|Accumulated depreciation                                 |  |      | (1,290,929 | ) |      |   | (1,205,336 | )    |  |   | (1,120,858 | ) |  |      | (1,039,475 | ) |  |   | (960,347  | )
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Net utility plant                                        |  | $    | 2,240,370  |   |      | $ | 2,175,980  |      |  | $ | 2,149,997  |   |  | $    | 2,123,304  |   |  | $ | 2,074,170 |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Total assets                                             |  | $    | 2,581,256  |   |      | $ | 2,493,436  |      |  | $ | 2,423,836  |   |  | $    | 2,406,944  |   |  | $ | 2,304,076 |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Capitalization:1                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Short-term borrowings from non-affiliates and affiliate  |  | $    | 6,000      |   |      | $ | 5,600      |      |  | $ | 48,297     |   |  | $    | 113,162    |   |  | $ | 107,013   |  
|Long-term debt, net                                      |  |      | 699,420    |   |      |   | 705,270    |      |  |   | 685,269    |   |  |      | 667,731    |   |  |   | 646,029   |  
|Preferred stock not subject to mandatory redemption      |  |      | 34,293     |   |      |   | 34,293     |      |  |   | 34,293     |   |  |      | 34,293     |   |  |   | 34,293    |  
|HECO-obligated preferred securities of subsidiary trusts |  |      | 100,000    |   |      |   | 100,000    |      |  |   | 100,000    |   |  |      | 100,000    |   |  |   | 100,000   |  
|Common stock equity                                      |  |      | 944,443    |   |      |   | 923,256    |      |  |   | 877,154    |   |  |      | 825,012    |   |  |   | 806,103   |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Total capitalization                                     |  | $    | 1,784,156  |   |      | $ | 1,768,419  |      |  | $ | 1,745,013  |   |  | $    | 1,740,198  |   |  | $ | 1,693,438 |  
|                                                         |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Capital structure ratios (%)1                            |  |      |            |   |      |   |            |      |  |   |            |   |  |      |            |   |  |   |           |  
|Debt                                                     |  |      | 39.6       |   |      |   | 40.2       |      |  |   | 42.0       |   |  |      | 44.9       |   |  |   | 44.5      |  
|Preferred stock                                          |  |      | 1.9        |   |      |   | 1.9        |      |  |   | 2.0        |   |  |      | 2.0        |   |  |   | 2.0       |  
|HECO-obligated preferred securities of subsidiary trusts |  |      | 5.6        |   |      |   | 5.7        |      |  |   | 5.7        |   |  |      | 5.7        |   |  |   | 5.9       |  
|Common stock equity                                      |  |      | 52.9       |   |      |   | 52.2       |      |  |   | 50.3       |   |  |      | 47.4       |   |  |   | 47.6      |  



|1 | Includes amounts due within one year, short-term borrowings from nonaffiliates and affiliate, and sinking fund and optional redemption payments.
|- | ------------------------------------------------------------------------------------------------------------------------------------------------



HEI owns all of HECOs common stock. Therefore, per share
data is not meaningful.



See Note 11, Commitments and
Contingencies, in HECOs Notes to Consolidated Financial Statements for a discussion of certain contingencies that could adversely affect the Companys future results of operations and financial condition.



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|ITEM 7. | MANAGEMENTS DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
|------- | -------------------------------------------------------------------------------------



HEI:



The information required by this item is set forth in HEIs MD&A, incorporated herein by reference to pages 4 to 35 of HEIs Annual Report.



HECO:

Managements Discussion and Analysis of Financial Condition and Results of Operations



The following discussion should be read in conjunction with Hawaiian Electric Company, Inc.s (HECOs) consolidated financial statements and
accompanying notes.



Overview and strategy



HECO and its electric public utility subsidiaries
(collectively, the Company) are vertically integrated and regulated by the Hawaii Public Utilities Commission (PUC). Hawaii has not experienced any of the disaggregation or deregulation that has occurred in the industry on the U. S. mainland over
the past several years. Keys to achieving reasonable returns are containing costs, retaining customers by providing reliable service and maintaining close customer relationships, and receiving rate increases when needed. The success of the
Companys strategy will be heavily influenced by Hawaiis general economic conditions and tourism. Real gross state product grew by 2.9% in 2003 and the State of Hawaii Department of Business, Economic Development and Tourism (DBEDT) has
projected that gross state product will grow by 2.8% in 2004. However, if a strike in the concrete business on Oahu that began in early February 2004 continues, it may become increasingly difficult for the state economy to achieve such growth in
2004.



Reliability projects remain a priority for HECO and its
subsidiaries and significant progress was made in enhancing reliability in 2003. After years of delays, the Keahole power plant expansion on the island of Hawaii resumed construction in November 2003 and the units are now expected to go online in
the second quarter of 2004 and be fully operational by December 31, 2004, providing needed generation to the fast-growing communities in West Hawaii. A request to approve a new plan for the East Oahu Transmission Project, an important reliability
project for the major transmission grid on the island of Oahu, was filed with the PUC in December 2003. Also on Oahu, a new fuel oil pipeline has been approved by the PUC and is under construction.



Major infrastructure projects can have a pronounced impact on the communities
in which they are located. The Company has expanded its community outreach and consultation process so they can better understand and evaluate community concerns early in the process.



With large power users in its service territories, such as the U.S. military, hotels and state and local government,
management believes that retaining customers by maintaining customer satisfaction is a critical component in achieving KWH sales and revenue growth in Hawaii over time. The Company has established programs that offer these customers specialized
services and energy efficiency audits to help them save on energy costs.



HECO plans to file an application for a rate case in the second half of 2004, based on a 2005 test year. The final decision for the last rate case on Oahu was issued in 1995. HECO and its subsidiaries forecast that
cash flows from operations over the next five years will cover their capital expenditures and dividend requirements, except for slight increases in long-term debt from the drawdown of outstanding revenue bond proceeds and in short-term borrowings,
which will fluctuate during this period.



Besides installing
new generating units, the Companys long-term plan to meet Hawaiis future energy needs includes their support of energy conservation and efficiency through demand-side management programs and initiatives to pursue a range of energy
choices, including renewable energy and new power supply technologies such as distributed generation. In late 2002, HECO formed a new subsidiary, Renewable Hawaii, Inc. (RHI), which will invest up to $10 million in renewable energy projects to
advance the long-term development of renewable energy in Hawaii. Requests for proposals have been issued for projects and RHI is presently evaluating the viability of several projects.



Net income was $79 million in 2003 compared to $90 million in 2002. A swing of $24 million in retirement benefits expense,
from a credit of $10 million in 2002 to an expense of $14 million in 2003, was a primary cause of the decline. Pension expense in 2004 is expected to be $6 million lower than in 2003. KWH sales growth was up 2.4% for the year



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and growth was particularly strong at 5.1% for the island of Hawaii. Assuming a near-term resolution of the current strike and continuing strength in the
U.S. and Hawaii economies, management expects higher KWH sales again in 2004.



From time to time, the Company considers various strategies designed to enhance their competitive positions and to maximize shareholder value. These strategies may include the formation of new subsidiaries or the
acquisition or disposition of businesses. The Company may from time to time be engaged in preliminary discussions, either internally or with third parties, regarding potential transactions. Management cannot predict whether any of these strategies
or transactions will be carried out or, if so, whether they will be successfully implemented.



Economic conditions



Because it provides local electric utility services, the Companys operating results are significantly influenced by the strength of Hawaiis economy, which has been growing modestly. Growth in real gross state product was 2.7%
and 2.9% in 2002 and 2003, respectively.



Tourism is widely
acknowledged as the largest component of the Hawaii economy. Direct and indirect tourism dollars accounted for approximately 17% of 2002 gross state product, 22% of civilian jobs and 26% of state and local taxes based on a study conducted by DBEDT.
In 2000, visitor arrivals reached a high of 7 million. In 2001, arrivals were pacing 2000 levels when the terrorist acts of September 11thnegatively impacted tourism, especially Japanese arrivals. In 2003, the war in Iraq and the outbreak of SARS in Asia provided additional reasons for Japanese tourists not to travel. While tourism has since rebounded,
visitor arrivals have lagged the 2000 record arrival levels. Total visitor arrivals in 2003 were 6.3 million, down 0.7% from 2002, due to a combination of a weak international visitor market (down 9.0%) and a strong domestic market (up 3.2%).
Positives in 2003 tourism were: visitors stayed longer, evidenced by a 3.0% increase in total visitor days; hotel occupancy levels reached 72.8% through November 2003, 2.7% higher than occupancy rates for the same period of 2002; and visitor
expenditures are expected to be $10.5 billion for 2003, which would represent a 4.8% increase over 2002 visitor expenditures. Also in 2003, visitor days, which reflect both visitor arrivals and length of stay, were 62 million, also a record high for
Hawaii tourism.



Key non-tourism sectors in Hawaii,
particularly the military and residential real estate, are fueling economic growth. After remaining relatively stable over the last five years, the military is showing a growing presence with several key military construction projects slated to
begin in 2004, including $3 billion of housing renewal projects, $0.7 billion in construction for an Army Stryker Brigade and over $150 million to prepare for the arrival of eight C-17 cargo planes at Hickam Air Force Base.



In general, the construction industry in Hawaii has been doing well. Private
building permits were up 37.8% overall for the year through November 2003 compared with the same period in 2002, and were also up in all categoriesresidential (up 24.0%), commercial and industrial (up 110.7%) and additions and alterations (up
28.0%). Local economists anticipate year-end data to reflect 7% growth in construction in 2003 and have forecast a 17% increase for 2004. However, in early February 2004, employees of the principal manufacturers of concrete on Oahu went on strike,
causing a slowdown in construction in Hawaiihalting many construction projects and leading to hundreds of layoffs in the construction industry. The slowdown in construction activity will temporarily delay electricity demand from new customers.
A prolonged strike could significantly adversely affect Hawaiis construction industry and the Hawaii economy in general.



Hawaiis improving economy in 2003 is also reflected in other general economic statistics. Total salary and wage jobs increased by 2.2% in 2003
versus 2002. Hawaiis unemployment rate of 3.8% was well below the national average of 5.4% at the end of 2003. DBEDT also estimates real personal income growth of 3.5% in 2003 compared to 2002.



Given these positive trends in key non-tourism sectors and overall economic
indicators, DBEDT expects Hawaiis economy to grow moderately by 2.8% in 2004, excluding inflation, but achievement of such growth is subject to numerous variables and unknowns. Future growth in Hawaiis economy is expected to be tied
primarily to the rate of expansion in the mainland U.S. and Japan economies and increased military spending, and remains vulnerable to uncertainties in the worlds geopolitical environment.



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Results of Operations



|                                                                 |  |      |       |   |         |     |   |      |   |       |         |  |     |      |  |   |       |  
|---------------------------------------------------------------- |  | ---- | ----- | - | ------- | --- | - | ---- | - | ----- | ------- |  | --- | ---- |  | - | ----- | -
|(in millions, except per barrel amounts and number of employees) |  | 2003 |       |   | %change |     |   | 2002 |   |       | %change |  |     | 2001 | 
|Revenues1                                                        |  | $    | 1,393 |   |         | 11  |   |      | $ | 1,253 |         |  | (2  | )    |  | $ | 1,284 |  
|Expenses                                                         |  |      |       |   |         |     |   |      |   |       |         |  |     |      |  |   |       |  
|Fuel oil                                                         |  |      | 389   |   |         | 25  |   |      |   | 311   |         |  | (10 | )    |  |   | 347   |  
|Purchased power                                                  |  |      | 368   |   |         | 13  |   |      |   | 326   |         |  | (3  | )    |  |   | 338   |  
|Other                                                            |  |      | 511   |   |         | 6   |   |      |   | 481   |         |  | 4   |      |  |   | 464   |  
|Operating income                                                 |  |      | 125   |   |         | (8  | ) |      |   | 135   |         |  |    |      |  |   | 135   |  
|Allowance for funds used during construction                     |  |      | 6     |   |         | 6   |   |      |   | 6     |         |  | (11 | )    |  |   | 6     |  
|Net income                                                       |  |      | 79    |   |         | (13 | ) |      |   | 90    |         |  | 2   |      |  |   | 88    |  
|Return on average common equity                                  |  |      | 8.5   | % |         |     |   |      |   | 10.0  | %       |  |     |      |  |   | 10.4  | %
|Average price per barrel of fuel oil1                            |  | $    | 36.23 |   |         | 25  |   |      | $ | 29.10 |         |  | (13 | )    |  | $ | 33.49 |  
|Kilowatthour sales                                               |  |      | 9,775 |   |         | 2   |   |      |   | 9,544 |         |  | 2   |      |  |   | 9,370 |  
|Number of employees (at December 31)                             |  |      | 1,862 |   |         | (2  | ) |      |   | 1,894 |         |  | (2  | )    |  |   | 1,930 |  



|1 | The rate schedules contains energy cost adjustment clauses through which changes in fuel oil
prices and certain components of purchased energy costs are passed on to customers.
|- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Pension and other postretirement benefits



For 2003, the retirement benefit plan assets generated a total return of nearly 25% for realized and unrealized net gains of $144 million. In contrast, for 2002, 2001 and 2000, the realized and unrealized net losses
on retirement benefit plan assets were $106 million, $91 million and $30 million, respectively. Contributions to the retirement benefit plans totaled $31 million in 2003, compared to contributions of $7 million and $4 million during 2002 and 2001,
respectively. Contributions are expected to total $11 million in 2004. As of December 31, 2003 and 2002, the market value of such assets was $758 million and $627 million, respectively.



Based on various assumptions (e.g., discount rate and expected return on plan assets, which are noted below) and assuming no
further changes in retirement benefit plan provisions, the Companys accumulated other comprehensive income (AOCI) balance, net of tax benefits, related to the minimum pension liability at December 31, 2003 and 2002 and retirement benefits
expense (income), net of income taxes, for 2004 (estimated) will be, and 2003 and 2002 were, as follows:



|                                                           |  |                  |   |  |      |   |  |       |  
|---------------------------------------------------------- |  | ---------------- | - |  | ---- | - |  | ----- | -
|Years ended December 31                                    |  | (Estimated) 2004 |   |  | 2003 |   |  | 2002  |  
|($ in millions)                                            |  |                  |   |  |      |   |  |       |  
|                                                           |  |                  |  
|Consolidated HECO                                          |  |                  |   |  |      |   |  |       |  
|AOCI balance, net of tax benefits, December 31             |  | NA               |   |  | (0.2 | ) |  | (0.1  | )
|Retirement benefits expense (income), net of income taxes1 |  | 4.6              |   |  | 8.4  |   |  | (6.2  | )
|                                                           |  |                  |  
|Assumptions                                                |  |                  |   |  |      |   |  |       |  
|Discount rate, January1                                    |  | 6.25             | % |  | 6.75 | % |  | 7.25  | %
|Expected return on plan assets                             |  | 9.00             | % |  | 9.00 | % |  | 10.00 | %



|1 | Does not include impact of the Medicare Prescription Drug, Improvement and Modernization Act
of 2003.
|- | -----------------------------------------------------------------------------------------------------



|NA | Not available.
|-- | --------------



The 2004 estimated retirement benefits expenses, net of income taxes, are forward-looking statements subject to risks and uncertainties, including the
impact of plan changes during the year, if any, and the impact of actual information when received (e.g., actual participant demographics as of January 1, 2004).



| |  | In 2003, revenues increased by 11%, or $140 million, from 2002 primarily due to higher energy prices ($111 million), a 2.4% increase in KWH sales of
electricity ($32 million) and higher demand-side management
| | - | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



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| | (DSM) lost margins and shareholder incentives ($4 million), partly offset by lower DSM program and Integrated Resource Plan (IRP) costs to be recovered ($5
million). The increase in 2003 KWH sales from 2002 was primarily due to increases in the number of residential customers and residential and commercial usage resulting in part from an improving Hawaii economy (higher visitor days and strong real
estate market) and warmer weather (more air conditioning usage). The growth in sales was achieved despite the impact on tourism of concerns over the Japanese economy, the war in Iraq, terrorism and SARS. Cooling degree days were 4.4% higher in 2003
compared to 2002.
| | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Operating income was $10
million lower than 2002 mainly due to higher other expenses, primarily higher retirement benefit expenses.



Fuel oil expense and purchased power expense in 2003 increased by 25% and 13%, respectively, due primarily to higher fuel prices, which are generally
passed on to customers, and more KWHs generated and purchased.



Other expenses were up 6% in 2003 due to an 18% (or $24 million) increase in other operation expense; a 5% (or $5 million) increase in depreciation expense due to additions to plant in service in 2002, including HECOs
Kewalo-Kamoku 138 kilovolt (kV) line; a 9% (or $11 million) increase in taxes, other than income taxes, primarily due to the increase in revenues; partly offset by a 3% (or $2 million) decrease in maintenance expense due in part to less underground
distribution line corrective maintenance. As the Companies focused on capital expenditures to ensure reliability, ducted cables were installed to replace, rather than repair, direct buried cables when cable problems occurred.



Other operation expense increased 18% primarily due to higher
retirement benefits expense and environmental expenses (including higher emission fees). Pension and other postretirement benefit costs, net of amounts capitalized, swung $24 million over 2002 ($14 million expense in 2003 versus a $10 million credit
in 2002), partly due to revised assumptions (decreasing the discount rate 50 basis points to 6.75% and the long-term rate of return on assets 100 basis points to 9.0% as of December 31, 2002 compared to December 31, 2001). As of December 31, 2003,
the discount rate was further reduced to 6.25%, but retirement benefits expense in 2004 is expected to be $6 million lower than 2003 due to the improved performance of plan assets and contributions made in 2003. Other operation expense
for 2003 also included $3.1 million of charges related to a settlement reached in December 2003 involving the expansion of the existing plant at Keahole on the island of Hawaii (see Note 11 in HECOs Notes to Consolidated Financial
Statements), offset by lower DSM and IRP costs. In January 2004, the Department of Health of the State of Hawaii (DOH) announced that it intended to waive 2003 emissions fees; thus, 2003 emissions fees of $1.5 million, which were accrued in
2003, were reversed in the first quarter of 2004.



| |  | In 2002, revenues decreased by 2%, or $31 million, from 2001 primarily due to lower energy prices ($60 million), partly offset by a 1.9% increase in KWH sales of electricity ($25
million). The increase in 2002 KWH sales from 2001 was primarily due to increases in residential usage and the number of residential customers and a recovery in the local economy following the events of the September 11, 2001 terrorist attacks, in
spite of cooler temperatures which typically result in lower residential and commercial air conditioning usage. Operating income for 2002 was slightly lower than 2001. Fuel oil expense decreased 10% due primarily to lower fuel oil prices, partly
offset by more KWHs generated. Purchased power expense decreased 3% due primarily to lower fuel prices and lower purchased capacity payments to an IPP who was able to produce only an average of about 5.6 megawatt (MW) of firm capacity since April
2002 compared to the 30 MW the IPP contracted to provide to HELCO. Other expenses were up 4% due to a 5% increase in other operation expense (including $7 million lower retirement benefits income, net of amounts capitalized, primarily
due to a 25 basis points lower discount rate and the market performance of plan assets  i.e., $10 million retirement benefits income in 2002 compared to $17 million in 2001), an 8% increase in maintenance expense partly due to the timing and
larger scope of generating unit overhauls, a 5% increase in depreciation expense due to additions to plant in service in 2001, partly offset by a 1% decrease in taxes, other than income taxes. Allowance for funds used during construction (AFUDC) for
2002 was 11% lower than 2001 due to the lower base on which AFUDC was calculated. Interest expense decreased 6% from 2001 due to lower short-term borrowings and interest rates.
| | - | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



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Recent rate requests



HECO, HELCO and MECO initiate PUC proceedings from time to time to request electric rate increases to cover rising operating
costs (e.g., higher purchased power capacity charges) and the cost of plant and equipment, including the cost of new capital projects to maintain and improve service reliability. As of February 11, 2004, the return on average common equity (ROACE)
found by the PUC to be reasonable in the most recent final rate decision for each utility was 11.40% for HECO (decision and order (D&O) issued on December 11, 1995, based on a 1995 test year), 11.50% for Hawaii Electric Light Company, Inc.
(HELCO) (D&O issued on February 8, 2001, based on a 2000 test year) and 10.94% for Maui Electric Company, Limited (MECO) (amended D&O issued on April 6, 1999, based on a 1999 test year). For 2003, the actual simple average ROACEs (calculated
under the rate-making method and reported to the PUC) for HECO, HELCO and MECO were 9.20%, 6.61% and 10.08%, respectively. HELCOs actual ROACE for 2003 of 6.61%, compared to its allowed ROACE of 11.50%, reflects in part HELCOs decision
to discontinue accruing AFUDC, effective December 1, 1998, on its CT-4 and CT-5 generating units that are being installed at the Keahole power plant. The non-accrual of AFUDC (currently estimated at approximately $0.6 million after tax per month) is
expected to continue to have a negative impact on HELCOs ROACE for 2004.



As of February 11, 2004, the return on average rate base (ROR) found by the PUC to be reasonable in the most recent final rate decision for each utility was 9.16% for HECO, 9.14% for HELCO and 8.83% for MECO (D&Os
noted above). For 2003, the actual RORs (calculated under the rate-making method) for HECO, HELCO and MECO were 7.95%, 8.65% and 8.79%, respectively.



Hawaiian Electric Company, Inc. HECO has not initiated a rate case in about ten years, but in 2001 it committed to initiate a rate case within three years, using a
2003 or 2004 test year. The PUC later approved HECOs request that the time for initiating the rate case be extended by 12 months, with the result that the rate case is to be initiated in the second half of 2004, using a 2005 test year. See
Other regulatory matters, Demand-side management programs  agreements with the Consumer Advocate.



In October 2002, HECO filed an application with the PUC for approval to change its depreciation rates and to change to vintage amortization accounting for
selected plant accounts, which changes would have amounted to an estimated $4.2 million, or 6.3%, increase in HECOs annual depreciation expense based on a study of depreciation expense for 2000. In its application, HECO requested that the
effective date of the proposed changes coincide with the effective date of the rates established in HECOs next rate case proceeding so that HECOs financial results would not be negatively impacted by the depreciation rates and method
ultimately approved by the PUC. In July 2003, the Consumer Advocate submitted its direct testimony and recommended depreciation expense approximately $31.8 million, or 45%, less than HECOs requested $70.8 million in annual depreciation
expense. In March 2004, HECO and the Consumer Advocate reached an agreement, subject to PUC approval. Under the agreement, HECO would change its depreciation rates and change to vintage amortization accounting for selected plant accounts, effective
with the PUCs final decision and order in this application. If approved by the PUC, the settlement agreement would result in an estimated $65.0 million in annual depreciation expense for 2000.



Hawaii Electric Light Company, Inc. In early 2001, HELCO received a final D&O from
the PUC authorizing an $8.4 million, or 4.9% increase in annual revenues, effective February 15, 2001 and based on an 11.50% ROACE. The D&O included in rate base $7.6 million for pre-air permit facilities needed for the delayed Keahole power
plant expansion project that the PUC had also found to be used or useful to support the existing generating units at Keahole. The timing of a future HELCO rate increase request to recover costs relating to the delayed Keahole power plant expansion
project, i.e., adding two combustion turbines (CT-4 and CT-5) at Keahole, including the remaining cost of pre-air permit facilities, will depend on future circumstances. See HELCO power situation in Note 11 in HECOs Notes to
Consolidated Financial Statements.



On June 1, 2001, the
PUC issued an order approving a new standby service rate schedule rider for HELCO. The standby service rider issue had been bifurcated from the rate case decided by the PUC in February 2001. The rider provides the rates, terms and conditions for
obtaining backup and supplemental electric power from the utility when a customer obtains all or part of its electric power from sources other than HELCO.



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Other regulatory matters



Demand-side management programs - lost margins and shareholder incentives. HECO, HELCO and MECOs energy efficiency DSM
programs, currently approved by the PUC, provide for the recovery of lost margins and the earning of shareholder incentives.



Lost margins are accrued and collected prospectively based on the programs forecast levels of participation, and are subject to two adjustments
based on (1) the actual level of participation and (2) the results of impact evaluation reports. The difference between the adjusted lost margins and the previously collected lost margins are subject to refund or recovery, with any over- or
under-collection accruing interest at HECO, HELCO, or MECOs authorized rate of return on rate base. HECO, HELCO and MECO plan to file the impact evaluation report for the 2000-2002 period with the PUC in the fourth quarter of 2004 and adjust
the lost margin recovery as required. Past adjustments required for lost margins have not had a material effect on HECO, HELCO or MECOs financial statements.



Shareholder incentives are accrued currently and collected retrospectively based on the programs actual levels of
participation for the prior year. Beginning in 2001, shareholder incentives collected are subject to retroactive adjustment based on the results of impact evaluation reports, similar to the adjustment process for lost margins.



Demand-side management programs  agreements with the Consumer Advocate. In
October 2001, HECO and the Consumer Advocate finalized agreements, subject to PUC approval, for the continuation of HECOs three commercial and industrial DSM programs and two residential DSM programs until HECOs next rate case, which
HECO committed to file using a 2003 or 2004 test year. These agreements were in lieu of HECO continuing to seek approval of new 5-year DSM programs. Any DSM programs to be in place after HECOs next rate case will be determined as part of the
case. Under the agreements, HECO will cap the recovery of lost margins and shareholder incentives if such recovery would cause HECO to exceed its current authorized return on rate base (i.e. the rate of return on rate base found by the
PUC to be reasonable in the most recent rate case for HECO). HECO also agreed it will not pursue the continuation of lost margins recovery and shareholder incentives through a surcharge mechanism in future rate cases. In October 2001, HELCO and MECO
reached similar agreements with the Consumer Advocate and filed requests to continue their four existing DSM programs. In November 2001, the PUC issued orders (one of which was later amended) that, subject to certain reporting requirements and other
conditions, approved (1) the agreements regarding the temporary continuation of HECOs five existing DSM programs until HECOs next rate case and (2) the agreements regarding the temporary continuation of HELCOs and MECOs DSM
programs until one year after the PUC makes a revenue requirements determination in HECOs next rate case. Under the orders, however, HELCO and MECO are allowed to recover only lost margins and shareholder incentives accrued through the date
that interim rates are established in HECOs next rate case, but may request to extend the time of such accrual and recovery for up to one additional year. In 2002, MECOs revenues from shareholder incentives were $0.7 million lower than
the amount that would have been recorded if MECO had not agreed to cap such incentives when its authorized ROR was exceeded. Also in 2002, HELCO slightly exceeded its authorized ROR resulting in a reduction of revenues from shareholders incentives
for 2002 by $31,000 (recorded in January 2003). In 2002, HECO did not exceed its authorized ROR. In 2003, none of the electric utilities exceeded their respective authorized RORs.



As part of HECOs agreement with the Consumer Advocate regarding HECOs commercial, industrial and residential DSM
programs, the parties agreed in August 2003, and the PUC approved, that HECO could delay the filing of its next rate case by approximately 12 months, with the result that the rate case will be filed in the second half of 2004 using a 2005 test year.
The other components of the existing agreements, as approved by the PUC, would be continued under the new agreements.



Collective bargaining agreements



HECO, HELCO and MECO reached a new collective bargaining agreement in 2003 with the union which represents approximately 60% of its employees. See
Collective bargaining agreements in Note 11 in HECOs Notes to Consolidated Financial Statements.



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Legislation



Congress and the Hawaii legislature periodically consider legislation that could have positive or negative effects on the utilities and their customers.
For example, although it is currently stalled in a House-Senate conference committee, comprehensive energy legislation is still before Congress that could increase the domestic supply of oil as well as increase support for energy conservation
programs and mandate the use of renewables by utilities. The 2003 Hawaii legislature considered measures that would undertake a comprehensive audit of Hawaiis electric utility regulatory policies, energy policies and support for reducing
Hawaiis use of imported petroleum for electrical generation, and a measure to remove the cap on the amount of net energy metering the utilities would be required to make available to eligible customers. These measures were not enacted into
law. The legislature did, however, pass a more restricted bill calling for a management audit of the PUC and Consumer Advocate. Also, on June 26, 2003, the Governor signed into law the Hawaii State tax credit for renewable energy, which extends the
existing tax credit of 35% of the cost of residential solar water heating (up to $1,750) until at least 2008.



In its 2001 session, the Hawaii legislature passed a law establishing renewable portfolio standard goals for electric utilities of 7% by
December 31, 2003, 8% by December 31, 2005 and 9% by December 31, 2010. HECO, HELCO and MECO are permitted to aggregate their renewable portfolios in order to achieve these goals. Any electric utility whose percentage of sales of electricity
represented by renewable energy does not meet these goals will have to report to the PUC and provide an explanation for not meeting the renewables portfolio standard. The PUC could then grant a waiver from the standard or an extension for meeting
the standard. The PUC may also provide incentives to encourage electric utilities to exceed the standards or meet the standards earlier, or both, but as yet no such incentives have been proposed. The law also requires that electric utilities offer
net energy metering to solar, wind turbine, biomass or hydroelectric generating systems (or hybrid systems) with a capacity up to 10 kilowatts (i.e., a customer-generator may be a net user or supplier of energy and will make payments to or receive
credits from the electric utility accordingly).



The Company
currently supports renewable sources in various ways, including their solar water heating and heat pump programs and their purchased power contracts with nonutility generators using renewable sources (e.g., refuse-fired, geothermal, hydroelectric
and wind turbine generating systems). On December 30, 2003, HELCO signed an approximately 10 MW as-available wind power contract with Hawi Renewable Development. The electric utilities continue to initiate and support many renewable energy research
and development projects to help develop these technologies (e.g., photovoltaic projects). They are also conducting integrated resource planning to evaluate the use of more renewables and, in December 2002, HECO formed a nonregulated subsidiary,
Renewable Hawaii, Inc. (RHI), to invest in renewable energy projects. In 2003 and 2004, RHI solicited competitive proposals for investment opportunities in projects (1 MW or larger) to supply renewable energy on the islands of Oahu, Maui, Molokai,
Lanai and Hawaii. RHI is currently reviewing proposals received. RHI is seeking to take a passive, minority interest in such projects to help stimulate the addition of cost-effective, commercially viable renewable energy generation in the state of
Hawaii. Over 8% of consolidated electricity sales for 2003 were from renewable resources (as defined under the renewable portfolio standard law). While the Company thus met the 7% target for 2003 provided for in the 2001 Hawaii legislation, it
believes it may be difficult to meet the renewable portfolio standard goals in future years, particularly if sales of electricity increase as projected. Thus, at this time, management cannot predict the impact of this law or of other proposed
congressional and Hawaii legislation on the Company or its customers.



Effects of inflation



U.S. inflation, as
measured by the U.S. Consumer Price Index, averaged 2.3% in 2003, 1.6% in 2002 and 2.8% in 2001. Hawaii inflation, as measured by the Honolulu Consumer Price Index, averaged 2.3% in 2003, 1.2% in 2002 and 1.2% in 2001. Although the rate of inflation
over the past several years has been low, inflation continues to have an impact on the Companys operations.



Inflation increases operating costs and the replacement cost of assets. With significant physical assets, HECO and its subsidiaries replace assets at much
higher costs and must request and obtain rate increases to maintain adequate earnings. In the past, the PUC has generally approved rate increases to cover the effects of inflation. The PUC granted rate increases in 2001 and 2000 for HELCO, and in
1999 for MECO, in part to cover increases in construction costs and operating expenses due to inflation.



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Recent accounting pronouncements



See Recent accounting pronouncements and interpretations in Note 1 in HECOs Notes to Consolidated
Financial Statements.



Liquidity and capital
resources



The Company believes that its ability to
generate cash, both internally from operations and externally from issuances of equity and debt securities, commercial paper and bank borrowings, is adequate to maintain sufficient liquidity to fund its capital expenditures and investments and to
cover debt, retirement benefits and other cash requirements in the foreseeable future.



The Companys total assets were $2.6 billion at December 31, 2003 and $2.5 billion at December 31, 2002.



HECOs consolidated capital structure was as follows:



|                                                          |  |      |       |  |      |   |  |   |       |  |     |  
|--------------------------------------------------------- |  | ---- | ----- |  | ---- | - |  | - | ----- |  | --- | -
|December 31                                               |  | 2003 |       |  | 2002 |  
|(in millions)                                             |  |      |       |  |      |   |  |   |       | 
|Short-term borrowings                                     |  | $    | 6     |  |     | % |  | $ | 6     |  |    | %
|Long-term debt, net                                       |  |      | 699   |  | 39   |   |  |   | 705   |  | 40  |  
|HECO-obligated preferred securities of trust subsidiaries |  |      | 100   |  | 6    |   |  |   | 100   |  | 6   |  
|Preferred stock                                           |  |      | 34    |  | 2    |   |  |   | 34    |  | 2   |  
|Common stock equity                                       |  |      | 945   |  | 53   |   |  |   | 923   |  | 52  |  
|                                                          |  |      |       |  |      |   |  |   |       |  |     |  
|                                                          |  | $    | 1,784 |  | 100  | % |  | $ | 1,768 |  | 100 | %
|                                                          |  |      |       |  |      |   |  |   |       |  |     |  



As of February 11,
2004, the Standard & Poors (S&P) and Moodys Investors Services (Moodys) ratings of HECO securities were as follows:



|                                                          |  |      |  |        
|--------------------------------------------------------- |  | ---- |  | -------
|                                                          |  | S&P  |  | Moodys
|Commercial paper                                          |  | A-2  |  | P-2    
|Revenue bonds (senior unsecured, insured)                 |  | AAA  |  | Aaa    
|HECO-obligated preferred securities of trust subsidiaries |  | BBB- |  | Baa2   
|Cumulative preferred stock (selected series)              |  | NR   |  | Baa3   



|NR | Not rated.
|-- | ----------



The above ratings are not recommendations to buy, sell or hold any securities; such ratings may be subject to revision or withdrawal at any time by the rating agencies; and each rating should be evaluated
independently of any other rating.



In May 2002, S&P
revised its credit outlook on HECO securities to stable from negative, citing recovery in Hawaiis economy, moderate construction spending, aggressive cost containment, limited competitive pressures, steady banking operations, and
expectations for continued financial improvement.



The
rating agencies use a combination of qualitative measures (i.e., assessment of business risk that incorporates an analysis of the qualitative factors such as management, competitive positioning, operations, markets and regulation) as well as
quantitative measures (e.g., cash flow, debt, interest coverage and liquidity ratios) in determining the ratings of HECO securities.



From time to time, HECO utilizes short-term debt, principally commercial paper, to support normal operations and for other temporary requirements. From
time to time, HECO also borrows short-term from HEI for itself and on behalf of HELCO and MECO, and HECO may borrow from or loan to HELCO and MECO short-term. At December 31, 2003, HECO had $6 million and $26 million of short-term borrowings from
HEI and MECO, respectively, and HELCO had $11 million of short-term borrowings from HECO. HECO had an average outstanding balance of commercial paper for 2003 of $0.4 million and had no commercial paper outstanding at December 31, 2003. Management
believes that if HECOs commercial paper ratings were to be downgraded, they might not be able to sell commercial paper under current market conditions.



At December 31, 2003, HECO maintained bank lines of credit totaling $90 million (all maturing in 2004). These lines of credit are principally maintained
by HECO to support the issuance of commercial paper, but also may be drawn for general corporate purposes. Accordingly, the lines of credit are available for short-term liquidity in the event a rating agency downgrade were to reduce or eliminate
access to the commercial paper markets. There are



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In 2003, the Companys investing activities used $134 million in cash, primarily for capital
expenditures. Capital expenditures requiring the use of cash totaled approximately $147.0 million in 2003, of which $91.3 million was attributable to HECO, $29.4 million to HELCO and $26.3 million to MECO. Approximately 58% of the total 2003 capital
expenditures was for transmission and distribution projects and approximately 42% was for generation and general plant projects. Cash contributions in aid of construction received in 2003 totaled $13.0 million. Financing activities used net cash of
$74 million, including $66 million for the payment of common and preferred stock dividends and preferred securities distributions and $6 million for the net repayment of long-term debt. Operating activities provided cash of $206 million.



In September 2002, the Department of Budget and Finance of the State of
Hawaii issued, at a small discount, Series 2002A Special Purpose Revenue Bonds (SPRB) in the principal amount of $40 million with a maturity of 30 years and a fixed coupon interest rate of 5.10% (yield of 5.15%), and loaned the proceeds from the
sale to HECO. Payments on these revenue bonds are insured by a financial guaranty insurance policy issued by Ambac Assurance Corporation. As of December 31, 2003, $14 million of proceeds from the Series 2002A sale by the Department of Budget and
Finance of the State of Hawaii of special purpose revenue bonds issued for the benefit of HECO remain undrawn.



On May 1, 2003, the Department of Budget and Finance of the State of Hawaii issued, at a small discount, Refunding Series 2003A SPRB in the aggregate
principal amount of $14 million with a maturity of approximately 17 years and a fixed coupon interest rate of 4.75% (yield of 4.85%), and loaned the proceeds from the sale to HELCO. Also on May 1, 2003, the Department of Budget and Finance of the
State of Hawaii issued, at par, Refunding Series 2003B SPRB in the aggregate principal amount of $52 million with a maturity of approximately 20 years and a fixed coupon interest rate of 5.00% and loaned the proceeds from the sale to HECO and HELCO.
On June 2, 2003, the proceeds of these Refunding SPRB, together with additional funds provided by HECO and HELCO, were applied to refund a like principal amount of SPRB bearing higher interest coupons (HELCOs $4 million of 7.60% Series 1990B
SPRB and $10 million of 7.375% Series 1990C SPRB with original maturities in 2020, and HECOs and HELCOs aggregate $52 million of 6.55% Series 1992 SPRB with original maturities in 2022). Payments on the revenue bonds issued in May 2003
are insured by a financial guaranty insurance policy issued by XL Capital Assurance Inc.



As further explained in Note 10 in HECOs Notes to Consolidated Financial Statements, the Company maintains pension and other postretirement benefit plans. Funding for the pension plans is based upon
actuarially determined contributions that take into account the amount deductible for income tax purposes and the minimum contribution required under the Employee Retirement Income Security Act of 1974, as amended (ERISA). The Company was not
required to make any contributions to the pension plans to meet minimum funding requirements pursuant to ERISA for 2003, but the Companys Pension Investment Committee chose to make tax deductible contributions in 2003. Contributions to the
pension and postretirement benefit plans totaled $31 million in 2003. Contributions are expected to total $11 million in 2004. The Companys policy is to comply with directives from the PUC to fund the costs of the postretirement benefit plan.
These costs are ultimately collected in rates billed to customers. The Company reserves the right to change, modify or terminate the plans. From time to time in the past, benefits have changed. Depending on the performance of the assets held in the
plans trusts and numerous other factors, additional contributions may be required in the future to meet the minimum funding requirements of ERISA or to pay benefits to plan participants. The Company believes it will have adequate access to
capital resources to support any necessary funding requirements.



Net capital expenditures for 2004 through 2008 are estimated to total $0.8 billion. Consolidated cash flows from operating activities (net income, adjusted for noncash income and expense items such as depreciation, amortization and deferred
taxes), after the payment of common stock and preferred stock dividends, are expected to provide cash to cover the forecast consolidated net capital expenditures, except for a slight increase in short-term



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borrowings and in long-term debt from the drawdown of outstanding revenue bond proceeds. Short-term borrowings are expected to fluctuate during this forecast
period. Additional debt and/or equity financing may be required for various reasons, including increases in the costs of or an acceleration of the construction of capital projects, unbudgeted acquisitions or investments in new businesses,
significant increases in retirement benefit funding requirements that may be required if the market value of pension plan assets does not increase or there are changes in actuarial assumptions and other unanticipated expenditures not included in the
2004 through 2008 forecast.



Capital expenditures include the
costs of projects that are required to meet expected load growth, to improve reliability and to replace and upgrade existing equipment. Net capital expenditures for the five-year period 2004 through 2008 are currently estimated to total $0.8
billion. Approximately 52% of forecast gross capital expenditures (which includes the allowance for funds used during construction and capital expenditures funded by third-party contributions in aid of construction) is for transmission and
distribution projects, with the remaining 48% primarily for generation projects and general plant.



For 2004, net capital expenditures are estimated to be $194 million. Gross capital expenditures are estimated to be $216 million, including approximately
$102 million for transmission and distribution projects, approximately $88 million for generation projects and approximately $26 million for general plant and other projects. Investment in renewable projects through RHI in 2004 is estimated to be an
additional $1 million. Drawdowns of $2 million of proceeds from the Series 2002A sale of tax-exempt special purpose revenue bonds, cash flows from operating activities and short-term borrowings are expected to provide the cash needed for the net
capital expenditures in 2004.



Management periodically reviews
capital expenditure estimates and the timing of construction projects. These estimates may change significantly as a result of many considerations, including changes in economic conditions, changes in forecasts of KWH sales and peak load, the
availability of purchased power and changes in expectations concerning the construction and ownership of future generating units, the availability of generating sites and transmission and distribution corridors, the ability to obtain adequate and
timely rate increases, escalation in construction costs, the impacts of DSM programs and combined heat and power (CHP) installations, the effects of opposition to proposed construction projects and requirements of environmental and other regulatory
and permitting authorities.



Existing debt or trust preferred
securities may be refinanced (potentially at more favorable rates) with additional debt or equity financing (or both). The PUC must approve issuances, if any, of equity and long-term debt securities by HECO, HECO and MECO. In February 2004, the PUC
approved the issuance of trust preferred securities by HECO Capital Trust III to refinance the trust preferred securities issued by HECO Capital Trust I in 1997 and/or the trust preferred securities issued by HECO Capital Trust II in 1998. Depending
on interest rates and other conditions in the capital markets, the Companys current plans are to redeem the trust preferred securities of HECO Capital Trust I with the proceeds of the sale of the trust preferred securities of HECO Capital
Trust III and to utilize short-term borrowings from HEI and internal funds to effect the redemption of the trust preferred securities issued by HECO Capital Trust II. It is anticipated that HECO will pay down these short-term borrowings over time
with lower dividends to HEI. If these refinancings proceed, management expects to complete these redemptions in the second quarter of 2004.



See Note 11 in HECOs Notes to Consolidated Financial Statements for a discussion of fuel and power purchase commitments.



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Selected contractual obligations



The following table presents aggregated information about total principal, lease and fuel oil payments and minimum fixed
capacity purchase power charges due during the indicated periods under the specified contractual obligations:



|                                                                                  |  |                       |     |          |   |          |  |              |     |       |   |       |  |   |      
|--------------------------------------------------------------------------------- |  | --------------------- | --- | -------- | - | -------- |  | ------------ | --- | ----- | - | ----- |  | - | -----
|December 31, 2003                                                                 |  | Payment due by period
|(in millions)                                                                     |  | Lessthan1 year        |     | 1-3years |   | 4-5years |  | After 5years |     | Total
|Contractual obligations                                                           |  |                       |     |          |   |          |  |              |     |       |   |       |  |   |      
|Long-term debt, net                                                               |  | $                     |    |          | $ |         |  | $            |    |       | $ | 699   |  | $ | 699  
|HECO-obligated preferred securities of trust subsidiaries                         |  |                       |    |          |   |         |  |              |    |       |   | 100   |  |   | 100  
|Operating leases                                                                  |  |                       | 2   |          |   | 2        |  |              | 1   |       |   | 2     |  |   | 7    
|Fuel oil purchase obligations (estimate based on January 1, 2004 fuel oil prices) |  |                       | 350 |          |   |         |  |              |    |       |   |      |  |   | 350  
|Purchase power obligations minimum fixed capacity charges                        |  |                       | 123 |          |   | 236      |  |              | 234 |       |   | 1,491 |  |   | 2,084
|                                                                                  |  |                       |     |          |   |          |  |              |     |       |   |       |  |   |      
|                                                                                  |  | $                     | 475 |          | $ | 238      |  | $            | 235 |       | $ | 2,292 |  | $ | 3,240
|                                                                                  |  |                       |     |          |   |          |  |              |     |       |   |       |  |   |      



The table above does
not include other categories of obligations and commitments, such as interest payable, trade payables, obligations under purchase orders and amounts that may become payable in future periods under collective bargaining and other employment
agreements and employee benefit plans. As of December 31, 2003, the fair value of the assets held in trusts to satisfy the obligations of the pension and other postretirement benefit plans exceeded the pension plans accumulated benefit
obligation and the accumulated postretirement benefit obligation for retirees. Thus, no minimum funding requirements for retirement benefit plans have been included in the tables above.



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 its control and could cause future results of operations to differ materially from historical results. The following is a discussion of certain of these factors.



Economic conditions. Because its core business is providing local electric
utility services, the Companys operating results are significantly influenced by the strength of Hawaiis economy, which in turn is influenced by economic conditions in the mainland U.S. (particularly California) and Asia (particularly
Japan) as a result of the impact of those conditions on tourism. See Results of operations  Economic conditions.



Competition. The electric utility industry is competitive and the Companys success in meeting competition will continue to have a direct impact on the
Companys financial performance. The generation sector of the electric utility industry has become increasingly competitive in Hawaii. Although competition in the generation sector in Hawaii has been moderated by the scarcity of generation
sites, various permitting processes and lack of interconnections to other electric utilities, several independent power producers (IPPs) have established power purchase agreements with the Company, and customer self-generation, with or without
cogeneration, is a continuing competitive factor.



Recent developments
involving distributed generation. Historically, HECO, HELCO and MECO have been able to compete by offering customers economic alternatives that, among other things, employ energy efficient electrotechnologies such as the heat pump water
heater. However, the number of customer self-generation projects that are being proposed or installed in Hawaii, particularly those involving CHP systems, is growing. CHP systems are a form of distributed generation (DG), and produce electricity and
thermal energy from gas, propane or diesel-fired engines. In Hawaii, the thermal energy generally is used to heat water and, through an absorption chiller, drive an air conditioning system. The electric energy generated by these systems is usually
lower in output than the customers



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load, which results in continued connection to the utility grid to make up the difference in electricity demand and to
provide back up electricity.



The Company has initiated several
demonstration projects and other activities, including a small CHP demonstration project on Maui, to provide on-going evaluation of DG. The Company also has made a limited number of proposals to customers, subject to PUC review and approval, to
install and operate utility-owned CHP systems at the customers sites. Incremental generation from such customer-sited CHP systems, and other DG, is expected to complement traditional central station power, as part of the Companys plans
to serve their forecast load growth. To facilitate the offering of CHP systems, the Company signed a teaming agreement, in early 2003, with a manufacturer of packaged CHP systems, but the teaming agreement does not commit the Company to make any CHP
system purchases.



In July 2003, three vendors of DG/CHP
equipment and services proposed, in an informal complaint to the PUC, that the PUC open a proceeding to investigate the Companys provision of CHP services and the teaming agreement with another vendor, and to issue rules or orders to govern
the terms and conditions under which the Company will be permitted to engage in utility-owned DG at individual customers sites. In August 2003, the Company responded to the informal complaint, and to information requests from the PUC on the CHP
demonstration project and teaming agreement. In October 2003, the PUC opened an investigative docket to determine the potential benefits and impact of DG on Hawaiis electric distribution systems and markets and to develop policies and a
framework for DG projects deployed in Hawaii. The PUC also plans to address issues raised in the informal complaint filed by the three vendors of DG/CHP equipment. In March 2004, the PUC issued an order which granted motions by several parties to
intervene or participate without intervention in the DG docket. In its order, the PUC also ordered the parties and participants to meet to formulate for PUC approval by April 2, 2004, the issues, procedures, schedule and the degree of participation
by the participants.



In October 2003, the Company filed an
application for approval of a CHP tariff, under which it would provide CHP services to eligible commercial customers. Under the tariff, the Company would own, operate and maintain customer-sited, packaged CHP systems (and certain ancillary
equipment) pursuant to a standard form of contract with the customer. In March 2004, the PUC issued an order, in which it suspended the CHP tariff application until, at a minimum, the matters in the investigative docket on DG have been addressed.
Pending completion of the DG docket and approval of a tariff in the CHP application, the Company plans to request approval for individual CHP projects.



1996 competition docket and related proceedings. In 1996, the PUC instituted a proceeding to identify and examine the issues surrounding electric
competition and to determine the impact of competition on the electric utility infrastructure in Hawaii. Several of the parties submitted final statements of position to the PUC in 1998. HECOs position in the proceeding was that retail
competition is not feasible in Hawaii, but that some of the benefits of competition could be achieved through competitive bidding for new generation, performance-based rate-making (PBR) and innovative pricing provisions. The other parties to the
proceeding advanced numerous other proposals.



In May 1999, the
PUC approved HECOs standard form contract for customer retention that allows HECO to provide a rate option for customers who would otherwise reduce their energy use from HECOs system by using energy from a nonutility generator. Based on
HECOs current rates, the standard form contract provides a 2.77% and an 11.27% discount on base energy rates for qualifying Large Power and General Service Demand customers, respectively. In March 2000, the PUC approved
a similar standard form contract for HELCO which, based on HELCOs current rates, provides a 10.00% discount on base energy rates for qualifying Large Power and General Service Demand customers.



In December 1999, HECO, HELCO and MECO filed an application with the PUC
seeking permission to implement PBR in future rate cases. In early 2001, the PUC dismissed the PBR proposal without prejudice, indicating it declined at that time to change its current cost of service/rate of return methodology for determining
electric utility rates.



In January 2000, the PUC submitted to
the legislature a status report on its investigation of competition. The report stated that competitive bidding for new power supplies (i.e., wholesale generation competition) is a logical first step to encourage competition in Hawaiis
electric industry and that the PUC plans to proceed with an examination of the feasibility of competitive bidding and to review specific policies to encourage renewable energy resources in the power generation mix. The report stated that
further steps by the PUC will involve the development of specific



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policies to encourage wholesale competition and the continuing examination of other areas suitable for the development of
competition.



In October 2003, the PUC closed the
competition proceeding instituted in 1996. The PUC found that developments in other states indicate that, at best, implementation of retail access would be premature, and determined that no action will be taken to implement retail electric
competition in Hawaii at this time. The PUC concluded that projections of any potential benefits of restructuring Hawaiis electric industry are too speculative and that it has not been sufficiently demonstrated that all consumers in Hawaii
would continue to receive adequate, safe, reliable, and efficient energy services at fair and reasonable prices under a restructured market at this time. The PUC indicated it will take a cautious approach to restructuring and will continue to
monitor restructuring experiences in other states and at the federal level before proceeding with any major restructuring in Hawaii. The PUC determined that it was in the public interest to work within the current regulatory system to strive to
improve efficiency within the electric industry, and opened investigative dockets on competitive bidding and DG to move toward a more competitive electric industry environment under cost-based regulation. The stated purpose of the competitive
bidding investigation is to evaluate competitive bidding as a mechanism for acquiring or building new generating capacity in Hawaii. The PUC stated it would consider related filings on a case-by-case basis pending completion of the docket. The PUC
has made the electric utilities in Hawaii and the Consumer Advocate parties to the new proceedings. Motions to intervene or participate were filed by parties in the competitive bidding investigative docket. Management cannot predict the ultimate
outcome of these proceedings.



U.S. capital markets and interest rate
environment. Changes in the U.S. capital markets can have significant effects on the Company. For example, the Company estimates that consolidated retirement benefits expense, net of amounts capitalized and income taxes, will be $5 million
in 2004 as compared to $8 million in 2003, and that the Companys contributions to the retirement benefit plans will be $11 million in 2004 as compared to $31 million in 2003, partly as a result of the performance of HEIs retirement
benefit plans assets. See Quantitative and Qualitative Disclosures about Market Risk.



Technological developments. New technological developments (e.g., the commercial development of fuel cells or distributed generation) may impact the Companys future competitive position, results of
operations and financial condition.



Limited insurance. In the
ordinary course of business, the Company purchases insurance coverages (e.g., property and liability coverages) to protect itself against loss of or damage to its properties and against claims made by third-parties and employees for property damage
or personal injuries. However, the protection provided by such insurance is limited in significant respects and, in some instances, the Company has no coverage. For example, the Companys overhead and underground transmission and distribution
systems (with the exception of substation buildings and contents) have a replacement value roughly estimated at $2 billion and are uninsured because the amount of transmission and distribution system insurance available is limited and the premiums
are cost prohibitive. Similarly, the Company has no business interruption insurance as the premiums for such insurance would be cost prohibitive, particularly since the utilities are not interconnected to other systems. If a hurricane or other
uninsured catastrophic natural disaster should occur, and the PUC does not allow the Company to recover from ratepayers restoration costs and revenues lost from business interruption, the Companys results of operations and financial condition
could be materially adversely impacted. Also, certain of the Companys insurance has substantial deductibles or has limits on the maximum amounts that may be recovered. Insurers have also introduced new exclusions or limitations of
coverage for claims related to certain perils including, but not limited to, mold and terrorism. If a series of losses occurred, such as from a series of lawsuits in the ordinary course of business each of which were subject to the deductible
amount, or if the maximum limit of the available insurance were substantially exceeded, the Company could incur losses in amounts that would have a material adverse effect on its results of operations and financial condition.



Environmental matters. HECO and its subsidiaries 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. These laws and regulations, among other things,
require that certain environmental permits be obtained as a condition to constructing or operating certain facilities, and obtaining such permits can entail significant expense and cause substantial construction delays. Also, these laws and
regulations



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may be amended from time to time, including amendments that increase the burden and expense of compliance. Management
believes that the recovery through rates of most, if not all, of any costs incurred by HECO and its subsidiaries in complying with environmental requirements would be allowed by the PUC.



The entire electric utility industry is affected by the 1990 Amendments to the Clean Air Act, recent changes to the National
Ambient Air Quality Standard (NAAQS) for ozone, and adoption of a NAAQS for fine particulate matter. Possible changes to the federal New Source Review permitting regulations, as well as new regulatory programs, if enacted, regarding global warming
and mandating further reductions of certain air emissions will also pose challenges for the industry. If the Clear Skies Bill is adopted as currently proposed, HECO, and to a lesser extent, its subsidiaries, will likely incur significant capital and
operations and maintenance costs beginning one to two years after enactment.



HECO, HELCO and MECO, like other utilities, periodically identify leaking petroleum-containing equipment such as underground storage tanks, piping and transformers. The electric utilities report releases from such
equipment when and as required by applicable law and address impacts due to the releases in compliance with applicable regulatory requirements.



The Honolulu Harbor environmental investigation, described in Note 11 in HECOs Notes to Consolidated Financial Statements, is an ongoing
environmental investigation. Although this investigation is expected to entail significant expense over the next several years, management does not believe, based on information available to the Company at this time, that the costs of this
investigation or any other contingent liabilities relating to environmental matters will have a material adverse effect on the Company. However, there can be no assurance that a significant environmental liability will not be incurred by the
Company, including with respect to the Honolulu Harbor environmental investigation.



Regulation of electric utility rates. The PUC has broad discretion in its regulation of the rates charged by HECO, HELCO and MECO and in other matters. Any adverse D&O by the PUC concerning the level or method of
determining electric utility rates, the authorized returns on equity or other matters, or any prolonged delay in rendering a D&O in a rate or other proceeding, could have a material adverse effect on the Companys results of operations and
financial condition. Upon a showing of probable entitlement, the PUC is required to issue an interim D&O in a rate case within 10 months from the date of filing a completed application if the evidentiary hearing is completed (subject to
extension for 30 days if the evidentiary hearing is not completed). There is no time limit for rendering a final D&O. Interim rate increases are subject to refund with interest, pending the final outcome of the case. At December 31, 2003, HECO
and its subsidiaries had recognized $17 million of revenues with respect to interim orders regarding certain integrated resource planning costs, which revenues are subject to refund, with interest, to the extent they exceed the amounts allowed in
final orders.



Management cannot predict with certainty when
D&Os in future rate cases will be rendered or the amount of any interim or final rate increase that may be granted. There are no rate cases pending at this time. HECO, however, has committed to file a rate increase application in the second half
of 2004, using a 2005 test year.



The rate schedules of HECO,
HELCO and MECO include energy cost adjustment clauses under which electric rates charged to customers are automatically adjusted for changes in the weighted-average price paid for fuel oil and certain components of purchased power, and the relative
amounts of company-generated power and purchased power. In 1997 PUC decisions approving the electric utilities fuel supply contracts, the PUC noted that, in light of the length of the fuel supply contracts and the relative stability of fuel
prices, the need for continued use of energy cost adjustment clauses would be the subject of investigation in a generic docket or in a future rate case. The Company believes that the energy cost adjustment clauses continue to be necessary. These
clauses were continued in the most recent HELCO and MECO rate cases (final D&Os issued in February 2001 and April 1999, respectively).



Consultants periodically conduct depreciation studies for the Company to determine whether the existing approved rates and methods used to calculate
depreciation accruals are appropriate for the production, transmission, distribution and general plant accounts. If it is determined that the existing rates and methods are no longer appropriate, changes to those rates are recommended as part of the
study. In October 2002, HECO filed an application with the PUC for approval to change its depreciation rates and to change to vintage amortization accounting for selected plant accounts, which changes would have amounted to an approximate $4.2
million, or 6.3%, increase in depreciation expense based on a study of depreciation expense for 2000. In its application, HECO requested that the effective date of the proposed changes coincide with the effective date of the rates established in
HECOs next rate case proceeding so that HECOs financial results would not be impacted by the depreciation rates



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and method ultimately approved by the PUC. In March 2004, HECO and the Consumer Advocate reached a settlement agreement
in this application, subject to PUC approval. See previous section called Recent rate requests.



Fuel oil and purchased power. HECO, HELCO and MECO rely on fuel oil suppliers and independent power producers to deliver fuel oil and power, respectively. The Company estimates that 78% of the net energy
generated and purchased in 2004 will be generated from the burning of oil. Purchased KWHs provided approximately 39.2% of the total net energy generated and purchased in 2003 compared to 38.0% in 2002 and 39.0% in 2001.



Failure by the Companys oil suppliers to provide fuel pursuant to
existing supply contracts, or failure by a major independent power producer to deliver the firm capacity anticipated in its power purchase agreement, could interrupt the ability of the Company to deliver electricity, thereby materially adversely
affecting the Companys results of operations and financial condition. HECO, however, maintains an inventory of fuel oil in excess of one months supply, and HELCO and MECO maintain approximately a one months supply of both medium
sulfur fuel oil and diesel fuel. The Companys major sources of oil, through their suppliers, are in Alaska, Indonesia and the Far East. Some, but not all, of the Companys power purchase agreements require that the independent power
producers maintain minimum fuel inventory levels and all of the firm capacity power purchase agreements include provisions imposing substantial penalties for failure to produce the firm capacity anticipated by those agreements.



Other regulatory and permitting contingencies. Many public utility projects
require PUC approval and various permits (e.g., environmental and land use permits) from other agencies. Delays in obtaining PUC approval or permits can result in increased costs. If a project does not proceed or if the PUC disallows costs of the
project, the project costs may need to be written off in amounts that could have a material adverse effect on the Company. Two major capital improvement utility projects, the Keahole project and the East Oahu Transmission Project, have encountered
opposition and the Keahole project has been seriously delayed (although this project is now scheduled for completion during 2004). See Note 11 in HECOs Notes to Consolidated Financial Statements.



Material estimates and critical accounting policies



In preparing the consolidated financial statements and related disclosures
in conformity with accounting principles generally accepted in the United States of America, management is required to make estimates and assumptions that affect the reported amounts of assets and liabilities and the disclosure of contingent assets
and liabilities as of the date of the financial statements and the reported amounts of revenues and expenses during the period reported. Management reviews these estimates and assumptions periodically and reflects the effect of revisions in the
period that they are determined to be necessary. Actual results could differ significantly from those estimates.



Material estimates that are particularly susceptible to significant change in the case of the Company include the amounts reported for utility plant;
pension and other postretirement benefit obligations; contingencies and litigation; income taxes; regulatory assets and liabilities; and revenues.



In accordance with SEC Release No. 33-8040, Cautionary Advice Regarding Disclosure About Critical Accounting Policies, management has
identified the following accounting policies 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. Management has reviewed the material estimates and critical accounting policies with the HECO Audit Committee.



For additional discussion of the Companys accounting policies, see
Note 1 in HECOs Notes to Consolidated Financial Statements.



Utility plant. Utility plant is reported at cost. Self-constructed utility plant includes engineering, supervision, and administrative and general costs, and an allowance for the cost of funds used during the construction
period. These costs are recorded in construction in progress and are transferred to utility plant when construction is completed and the facilities are either placed in service or become useful for public utility purposes. Upon the retirement of
utility plant, no gain or loss is recognized. The cost of the utility plant retired is charged to accumulated depreciation. Amounts collected from customers for cost of removal (expected to exceed salvage value in the future) are included in
regulatory liabilities.



Management believes that the PUC will
allow recovery of utility plant in its electric rates. If the PUC does not allow recovery of any such costs, the Company would be required to write off the disallowed costs at that time. See the



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discussion in Note 11 in HECOs Notes to Consolidated Financial Statements concerning costs recorded in
construction in progress for CT-4 and CT-5 at Keahole and the proposed East Oahu Transmission Project.



Pension and other postretirement benefits obligations. Pension and other postretirement benefit (collectively, retirement benefits) costs/(returns) are charged/(credited) primarily to expense and utility
plant.



The Companys reported costs of providing
retirement benefits (described in Note 10 in HECOs Notes to Consolidated Financial Statements) are dependent upon numerous factors resulting from actual plan experience and assumptions of future experience. For example, pension and
other postretirement benefit costs are impacted by actual employee demographics (including age and compensation levels), the level of contributions to the plans and earnings on plan assets. Changes made to the provisions of the plans may also impact
current and future costs. (No changes were made to the retirement benefit plans provisions in 2003, 2002 and 2001 that have had a significant impact on recorded retirement benefit plan amounts.) Costs may also be significantly affected by
changes in key actuarial assumptions, including anticipated rates of return on plan assets and the discount rates used.



As a result of the factors listed above, significant portions of pension and other postretirement benefit costs recorded in any period do not reflect the
actual benefits provided to plan participants. For 2003 and 2002, the Company recorded other postretirement benefit expense, net of amounts capitalized, of approximately $7 million and $4 million, respectively, in accordance with the provisions of
Statement of Financial Accounting Standards (SFAS) No. 106, Employers Accounting for Postretirement Benefits Other Than Pensions. Actual payments of such benefits made to retirees during 2003 and 2002 were $7 million and $6
million, respectively. In accordance with SFAS No. 87, Employers Accounting for Pensions, changes in pension obligations associated with the factors noted above may not be immediately recognized as pension costs on the income
statement, but generally are recognized in future years over the remaining average service period of plan participants. For 2003 and 2002, the Company recorded non-cash pension expense (income), net of amounts capitalized, of approximately $7
million and $(14) million, respectively, and paid pension benefits of $36 million and $34 million, respectively.



The assumptions used by management in making benefit and funding calculations are based on current economic conditions. Changes in economic conditions
will impact the underlying assumptions in determining retirement benefit costs on a prospective basis. In selecting an assumed discount rate, the Company benchmarks its discount rate assumption to the Moodys 20-year AA Corporate Bond Composite
Index. In selecting an assumed rate of return on plan assets, the Company considers economic forecasts for the types of investments held by the plan and the past performance of plan assets.



As presented in Note 10 in HECOs Notes to Consolidated Financial
Statements, the Company has revised its discount rate as of December 31, 2003 compared to December 31, 2002. The change did not have an impact on reported costs in 2003; however, for future years, this change will have a significant impact.
Based upon the revised discount rate (decreased 50 basis points to 6.25%) and plan assets as of December 31, 2003, the Company estimates that retirement benefits expense, net of amounts capitalized and income taxes, will be $5 million in 2004 as
compared to $8 million in 2003. In determining the retirement benefit costs, assumptions can change from period to period, and such changes could result in material changes to these estimated amounts.



The Companys plan assets are primarily made up of equity and fixed
income investments. Fluctuations in actual equity market returns as well as changes in general interest rates may result in increased or decreased retirement benefit costs and contributions in future periods.



The following tables reflect the sensitivities of the projected benefit
obligation (PBO) and accumulated postretirement benefit obligation (APBO) as of December 31, 2003, and 2004 net income associated with a change in certain actuarial assumptions by the indicated basis points and constitute forward-looking
statements. Each sensitivity below reflects an evaluation of the change based solely on a change in that assumption as well as a related change in the contributions to the applicable retirement benefits plan.



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|                              |  |                                    |   |  |                   |       |   |                         |   |      |  
|----------------------------- |  | ---------------------------------- | - |  | ----------------- | ----- | - | ----------------------- | - | ---- | -
|Actuarial assumption          |  | Change inassumption inbasis points |   |  | Impact onPBO/APBO |       |   | Impact on2004 netincome |  
|($ in millions)               |  |                                    |   |  |                   |       |   |                         |  
|Pension benefits              |  |                                    |   |  |                   |       |   |                         |   |      |  
|Discount rate                 |  | 50                                 |   |  | $                 | (51.9 | ) |                         | $ | 1.2  |  
|                              |  | (50                                | ) |  |                   | 63.7  |   |                         |   | (3.4 | )
|Rate of return on plan assets |  | 50                                 |   |  |                   | NA    |   |                         |   | 1.8  |  
|                              |  | (50                                | ) |  |                   | NA    |   |                         |   | (1.8 | )
|Other benefits1               |  |                                    |   |  |                   |       |   |                         |   |      |  
|Discount rate                 |  | 50                                 |   |  |                   | (9.9  | ) |                         |   | 0.1  |  
|                              |  | (50                                | ) |  |                   | 10.9  |   |                         |   | (0.4 | )
|Health care cost trend rate   |  | 100                                |   |  |                   | 3.5   |   |                         |   | (0.2 | )
|                              |  | (100                               | ) |  |                   | (4.3  | ) |                         |   | 0.1  |  
|Rate of return on plan assets |  | 50                                 |   |  |                   | NA    |   |                         |   | 0.2  |  
|                              |  | (50                                | ) |  |                   | NA    |   |                         |   | (0.2 | )



|1 | Does not include impact of the Medicare Prescription Drug, Improvement and Modernization Act
of 2003.
|- | -----------------------------------------------------------------------------------------------------



|NA | Not applicable.
|-- | ---------------



Contingencies and litigation.The Company is subject to proceedings, lawsuits and other claims, including proceedings under laws and government regulations related to environmental matters.
Management assesses the likelihood of any adverse judgments in or outcomes to these matters as well as potential ranges of probable losses. A determination of the amount of reserves required, if any, for these contingencies is based on a careful
analysis of each individual issue often with the assistance of outside counsel. The required reserves may change in the future due to new developments in each matter or changes in approach in dealing with these matters, such as a change in
settlement strategy.



In general, environmental
contamination treatment costs are charged to expense, unless it is probable that the PUC would allow such costs to be recovered in future rates, in which case such costs would be capitalized as regulatory assets. Also, environmental costs are
capitalized if the costs extend the life, increase the capacity, or improve the safety or efficiency of property; the costs mitigate or prevent future environmental contamination; or the costs are incurred in preparing the property for sale. See
Environmental regulation in Note 11 in HECOs Notes to Consolidated Financial Statements for a description of the Honolulu Harbor investigation.



Income taxes. Deferred income tax assets and liabilities are established for the temporary differences between the financial
reporting bases and the tax bases of the Companys assets and liabilities at enacted tax rates expected to be in effect when such deferred tax assets or liabilities are realized or settled. The ultimate realization of deferred tax assets is
dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.



Management periodically evaluates its potential exposures from tax positions taken that have or could be challenged by taxing authorities. These potential
exposures result because taxing authorities may take positions that differ from those taken by management in the interpretation and application of statutes, regulations and rules. Management considers the possibility of alternative outcomes based
upon past experience, previous actions by taxing authorities (e.g., actions taken in other jurisdictions) and advice from tax experts. Management believes that the Companys provision for tax contingencies is reasonable. However, the ultimate
resolution of tax treatments disputed by governmental authorities may adversely affect the Companys current and deferred income tax amounts.



Regulatory assets and liabilities. HECO, HELCO and MECO are regulated by the PUC. In accordance with SFAS No. 71, Accounting for the Effects of
Certain Types of Regulation, the Companys financial statements reflect assets, liabilities, revenues and costs based on current cost-based rate-making regulations. The actions of regulators can affect the timing of recognition of
revenues, expenses, assets and liabilities.



Regulatory assets
represent incurred costs that have been deferred because they are probable of future recovery in customer rates. Regulatory liabilities represent amounts collected from customers for costs that are expected to be



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incurred in the future. Historically, the Company, like most electric utilities, had included net salvage (i.e., the cost
of removal in excess of salvage value) in accumulated depreciation. Recently, however, the Securities and Exchange Commission provided guidance indicating that net salvage meets the SFAS No. 71 definition of a regulatory liability. Accordingly, the
Company reclassified its accumulated net salvage as of December 31, 2003 (and all prior periods presented) from accumulated depreciation to regulatory liabilities. As of December 31, 2003, regulatory liabilities, net of regulatory assets, amounted
to $72 million. Regulatory assets and regulatory liabilities are itemized in Note 6 in HECOs Notes to Consolidated Financial Statements. Management continually assesses whether the regulatory assets are probable of future recovery
by considering factors such as changes in the applicable regulatory environment. Because current rates include the recovery of regulatory assets existing as of the last rate case and rates in effect allow the utilities to earn a reasonable rate of
return, management believes the regulatory assets as of December 31, 2003 are probable of recovery. This determination assumes continuation of the current political and regulatory climate in Hawaii, and is subject to change in the future.



Management believes its operations currently satisfy the SFAS
No. 71 criteria. If events or circumstances should change so that those criteria are no longer satisfied, the Company expects that the regulatory liabilities, net of regulatory assets, would be credited to income. In the event of unforeseen
regulatory actions or other circumstances, however, management believes that a material adverse effect on the Companys results of operations and financial position may result if regulatory assets have to be charged to expense without an
offsetting credit from regulatory liabilities.



Revenues. Revenues are based on rates authorized by the PUC and include revenues applicable to energy consumed in the accounting period but not yet billed to the customers. At December 31, 2003, revenues
applicable to energy consumed, but not yet billed to the customers, amounted to $60 million.



Revenue amounts recorded pursuant to a PUC interim order are subject to refund, with interest, pending a final order. At December 31, 2003, HECO and its subsidiaries had recognized $17 million of revenues with respect
to interim orders regarding certain integrated resource planning costs incurred since 1995, which revenues are subject to refund, with interest, to the extent they exceed the amounts allowed in final orders. If a refund were required, the revenues
to be refunded would be immediately reversed on the income statement. The Consumer Advocate has objected to the recovery of $2.5 million (before interest) of the $10.3 million of integrated resource planning costs incurred from 1995 through 2002,
and the PUCs decision is pending on this matter.



The
rate schedules of HECO, HELCO and MECO include energy cost adjustment clauses under which electric rates are adjusted for changes in the weighted-average price paid for fuel oil and certain components of purchased power, and the relative amounts of
company-generated power and purchased power. If the energy cost adjustment clauses were discontinued, the Companys results of operations could fluctuate significantly as a result of increases and decreases in fuel oil and purchased energy
prices. In 1997 PUC decisions approving the electric utilities fuel supply contracts, the PUC noted that, in light of the length of the fuel supply contracts and the relative stability of fuel prices, the need for continued use of energy cost
adjustment clauses would be the subject of investigation in a generic docket or in a future rate case. The Company believes that the energy cost adjustment clauses continue to be necessary and these clauses were continued in the 2001 and 1999 final
D&Os in HELCOs and MECOs most recent rate cases.



Consolidation of variable interest entities (VIEs). In December 2003, the Financial Accounting Standards Board (FASB) issued revised FASB Interpretation No. 46 (FIN No. 46R), Consolidation of Variable
Interest Entities, which addresses how a business enterprise should evaluate whether it has a controlling financial interest in an entity through means other than voting rights and accordingly should consolidate the entity. The Company
currently anticipates that application of FIN No. 46R will result in a deconsolidation of its subsidary trusts. The Company is evaluating the impact of applying FIN No. 46R in the first quarter of 2004 to its relationships with IPPs from whom it
purchases power and has not yet completed this analysis. A possible outcome of the analysis, however, is that HECO (or its subsidiaries, as applicable) may be found to meet the definition of a primary beneficiary of the IPPs, which finding may
result in the consolidation of the IPPs in the Companys consolidated financial statements. The consolidation of IPPs would have a material effect on the Companys consolidated financial statements, including the recognition of a
significant amount of assets and liabilities.



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|ITEM 7A. | QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
|-------- | ----------------------------------------------------------



HEI:



The information required by this item is incorporated herein by reference to pages 35 to 38 of HEIs Annual Report.



HECO:



HECO and its subsidiaries general policy is to manage interest rate risk through use of a combination of short-term debt, long-term debt (primarily fixed-rate debt) and preferred securities. As of December 31,
2003, management believes HECO and its subsidiaries are exposed to interest rate risk because of the periodic borrowing requirements, impact of the interest rates on the discount rate used to determine retirement benefits expenses and obligations
(see sections Pension and other postretirement benefits and Pension and other postretirement benefit obligations in Managements discussion and analysis of financial condition and results of operations and
Note 10 in HECOs Notes to consolidated financial statements) and the possible effect of interest rates on the electric utilities allowed rates of return (see Regulation of electric utility rates in HECOs
MD&A). Other than these exposures, management believes its exposure to interest rate risk is not material.



|ITEM 8. | FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
|------- | -------------------------------------------



HEI:



The information required by this item is incorporated herein by reference to pages 39 to 88 of HEIs Annual Report.



HECO:



The information required by this item is incorporated herein by reference to pages 1 to 39 of HECOs Consolidated Financial Statements.



|ITEM 9. | CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
|------- | ------------------------------------------------------------------------------------



HEI and HECO:



None



|ITEM 9A. | CONTROLS AND PROCEDURES
|-------- | -----------------------



HEI:



Robert F. Clarke, HEI Chief Executive Officer, and Eric K. Yeaman, HEI Chief Financial Officer, have evaluated the disclosure controls and procedures of HEI as of December 31, 2003. Based on their evaluations, as of
December 31, 2003, they have concluded that the disclosure controls and procedures (as defined in Rules 13a-14 and 15d-14 under the Securities Exchange Act of 1934) of the Company are effective.



HECO:



T. Michael May, HECO Chief Executive Officer, and Richard A. von Gnechten, HECO Chief Financial Officer, have evaluated the
disclosure controls and procedures of HECO as of December 31, 2003. Based on their evaluations, as of December 31, 2003, they have concluded that the disclosure controls and procedures (as defined in Rules 13a-14 and 15d-14 under the Securities
Exchange Act of 1934) of HECO are effective.



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PART III



|ITEM 10. | DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANTS
|-------- | ---------------------------------------------------



HEI:



Information for this item concerning the executive officers of HEI is set forth on pages 46 and 47 of this report. Information on the current HEI directors and their business experience and directorships is
incorporated herein by reference to the information under the captions Nominees for a Class III Director and Class II Directors, Continuing Class III Directors and Continuing Class I Directors, in HEIs 2004
Proxy Statement. The information on the HEI Audit Committee and the Board of Directors determination of HEIs Audit Committee financial experts and their names are incorporated by reference to the information under the captions Committees
of the Board  What Committees has the Board established and how often did they meet?, Committees of the Board  What are the primary functions of each of the four committees? and Audit Committee Report in the
2004 Proxy Statement.



Family relationships; director arrangements



There are no family relationships between any executive
officer or director of HEI and any other executive officer or director of HEI or any arrangement or understanding between any executive officer or director of HEI and any person, pursuant to which the executive officer or director of HEI was
selected.



Code of Conduct



Information on HEIs Code of Conduct is incorporated by reference to
the information under the caption Committees of the Board  What is the Companys philosophy on corporate governance? in the 2004 Proxy Statement. In connection with its periodic review of corporate governance trends and best
practices, the HEI Board of Directors adopted a Revised Code of Conduct, including the code of ethics for, among others, the chief executive officer and senior financial officers of HEI, which may be viewed on HEIs website at www.hei.com. HEI
also elects to disclose the information required by Form 8-K, Item 10, Amendments to the registrants code of ethics, or waiver of a provision of the code of ethics, through this website and such information will remain available on
this website for at least a 12-month period. A copy of the Revised Code of Conduct may be obtained free of charge upon written request from the HEI Vice President-Administration & Corporate Secretary, P.O. Box 730, Honolulu, Hawaii 96808-0730.



Section 16(a) beneficial ownership reporting compliance



For information required to be reported under this
caption, see the information under the caption Stock Ownership Information  Were Section 16(a) beneficial ownership reporting forms filed with the SEC? in HEIs 2004 Proxy Statement.



HECO:



Executive Officers



The following persons are, or may be deemed to be, executive officers of HECO. Their ages are given as of February 11, 2004 and their years of company
service are given as of December 31, 2003. Officers are appointed to serve until the meeting of the HECO Board of Directors after the next HECO Annual Meeting (which will occur in April 2004) and/or until their respective successors have been
appointed and qualified (or until their earlier resignation or removal). Company service includes service with HECO affiliates.



|                                                |  |                                       
|----------------------------------------------- |  | --------------------------------------
|HECO Executive Officers                         |  | Business experiencefor past five years
|Robert F. Clarke, age 61                        |  |                                       
|Chairman of the Board                           |  | 1/91 to date                          
|(Company service: 16 years)                     |  |                                       
|T. Michael May, age 57                          |  |                                       
|President, Chief Executive Officer and Director |  | 9/95 to date                          
|Chairman of the Board, MECO and HELCO           |  | 9/95 to date                          
|(Company service: 11 years)                     |  |                                       



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|                                                                                                                                                                                                                                                                                                                                          |  |                                       
|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | --------------------------------------
|HECO Executive Officers                                                                                                                                                                                                                                                                                                                   |  | Business experiencefor past five years
|(continued)                                                                                                                                                                                                                                                                                                                               |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|Robert A. Alm, age 52                                                                                                                                                                                                                                                                                                                     |  |                                       
|Senior Vice President  Public Affairs                                                                                                                                                                                                                                                                                                    |  | 7/01 to date                          
|(Company service: 2 years)                                                                                                                                                                                                                                                                                                                |  |                                       
|Robert A. Alm, prior to joining HECO, served as Executive Vice President of Financial Management Group at First Hawaiian Bank from 1/99 to 6/01.                                                                                                                                                                                          |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|Thomas L. Joaquin, age 60                                                                                                                                                                                                                                                                                                                 |  |                                       
|Senior Vice President  Operations                                                                                                                                                                                                                                                                                                        |  | 7/01 to date                          
|Vice President  Power Supply                                                                                                                                                                                                                                                                                                             |  | 7/95 to 06/01                         
|(Company service: 30 years)                                                                                                                                                                                                                                                                                                               |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|Karl E. Stahlkopf, age 63                                                                                                                                                                                                                                                                                                                 |  |                                       
|Senior Vice President  Energy Solutions and Chief Technology Officer                                                                                                                                                                                                                                                                     |  | 5/02 to date                          
|(Company service: 1 year)                                                                                                                                                                                                                                                                                                                 |  |                                       
|Karl E. Stahlkopf, prior to joining HECO, served as Vice President  Power Delivery and Utilization of the Electric Power Research Institute from 1/01 to
5/02; President and CEO of EPRI Solutions from 01/99 to 01/01; and Vice President  Energy Delivery and Utilization of the Electric Power Research Institute from 1/97 to 1/99. |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|William A. Bonnet, age 60                                                                                                                                                                                                                                                                                                                 |  |                                       
|Vice President  Government & Community Affairs                                                                                                                                                                                                                                                                                           |  | 5/01 to date                          
|President, Maui Electric Company, Inc                                                                                                                                                                                                                                                                                                     |  | 9/96 to 5/01                          
|(Company service: 18 years)                                                                                                                                                                                                                                                                                                               |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|Jackie Mahi Erickson, age 63                                                                                                                                                                                                                                                                                                              |  |                                       
|Vice President & General Counsel                                                                                                                                                                                                                                                                                                          |  | 3/03 to date                          
|Vice President  Customer Operations & General Counsel                                                                                                                                                                                                                                                                                    |  | 10/98 to 3/03                         
|(Company service: 22 years)                                                                                                                                                                                                                                                                                                               |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|Charles M. Freedman, age 57                                                                                                                                                                                                                                                                                                               |  |                                       
|Vice President  Corporate Relations                                                                                                                                                                                                                                                                                                      |  | 3/98 to date                          
|(Company service: 12 years)                                                                                                                                                                                                                                                                                                               |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|Chris M. Shirai, age 56                                                                                                                                                                                                                                                                                                                   |  |                                       
|Vice President  Energy Delivery                                                                                                                                                                                                                                                                                                          |  | 12/99 to date                         
|Manager, Engineering Department                                                                                                                                                                                                                                                                                                           |  | 7/96 to 11/99                         
|(Company service: 34 years)                                                                                                                                                                                                                                                                                                               |  |                                       
|                                                                                                                                                                                                                                                                                                                                          | 
|Thomas C. Simmons, age 55                                                                                                                                                                                                                                                                                                                 |  |                                       
|Vice President  Power Supply                                                                                                                                                                                                                                                                                                             |  | 2/02 to date                          
|Manager, Power Supply                                                                                                                                                                                                                                                                                                                     |  | 7/95 to 2/02                          
|(Company service: 32 years)                                                                                                                                                                                                                                                                                                               |  |                                       



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|                                                    |  |                                       
|--------------------------------------------------- |  | --------------------------------------
|HECO Executive Officers                             |  | Business experiencefor past five years
|(continued)                                         |  |                                       
|                                                    | 
|Richard A. von Gnechten, age 40                     |  |                                       
|Financial Vice President                            |  | 12/00 to date                         
|Assistant Treasurer and Manager, Financial Services |  | 5/00 to 11/00                         
|Manager, Customer Service                           |  | 12/96 to 5/00                         
|(Company service: 12 years)                         |  |                                       
|                                                    | 
|Patricia U. Wong, age 47                            |  |                                       
|Vice President  Corporate Excellence               |  | 3/98 to date                          
|(Company service: 13 years)                         |  |                                       
|                                                    | 
|Lorie Ann K. Nagata, age 45                         |  |                                       
|Treasurer                                           |  | 12/00 to date                         
|Manager, Management Accounting                      |  | 5/98 to date                          
|Assistant Treasurer                                 |  | 3/97 to 11/00                         
|(Company service: 21 years)                         |  |                                       
|                                                    | 
|Ernest T. Shiraki, age 56                           |  |                                       
|Controller                                          |  | 5/89 to date                          
|(Company service: 34 years)                         |  |                                       
|                                                    | 
|Molly M. Egged, age 53                              |  |                                       
|Secretary                                           |  | 10/89 to date                         
|(Company service: 23 years)                         |  |                                       



HECOs executive
officers, with the exception of Robert A. Alm, Jackie Mahi Erickson, Charles M. Freedman, Thomas L. Joaquin, Chris M. Shirai, Thomas C. Simmons and Patricia U. Wong, are also officers and/or directors of MECO, HELCO or Renewable Hawaii, Inc. HECO
executive officers Robert F. Clarke and Molly M. Egged are also officers of one or more of the affiliated nonutility HEI companies.



Board of Directors



The following is a list of current directors of HECO. The information is provided as of February 11, 2004.



|                      |  |     |  |                   
|--------------------- |  | --- |  | ------------------
|Director              |  | Age |  | Director since [2]
|Robert F. Clarke      |  | 61  |  | 1990              
|T. Michael May        |  | 57  |  | 1995              
|Shirley J. Daniel[1]  |  | 50  |  | 2002              
|Diane J. Plotts[1]    |  | 68  |  | 1991              
|James K. Scott        |  | 52  |  | 1999              
|Anne M. Takabuki[1]   |  | 47  |  | 1997              
|Barry K. Taniguchi[1] |  | 56  |  | 2001              
|Jeffrey N. Watanabe   |  | 60  |  | 1999              



|[1] | Audit committee member.
|--- | -----------------------



|[2] | Year indicates first year elected or appointed. All directors serve one year terms.
|--- | -----------------------------------------------------------------------------------



Anne M. Takabuki and Barry K. Taniguchi are the only nonemployee directors of HECO who are not directors of HEI. Ms.
Takabuki has been President of Wailea Golf LLC and Kauai Golf LLC since October 1, 2003. At Wailea Golf Resort, Inc. she was President from March 2003 to September 2003 and Vice President/Secretary and



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General Counsel from 1993 to February 2003. She also serves on the boards of Wailea Community Association and Kapiolani Medical Foundation and is a member of
the advisory Board of Directors of MECO. Mr. Taniguchi is President of KTA Super Stores. He also serves on the boards of ASB, Puna Plantation Hawaii, Limited, K. Taniguchi, Ltd. and numerous not-for-profit boards, including Hawaii Community
Foundation, Queens Health Systems and the Hawaii Island Economic Development Board, and is a member of the advisory Board of Directors of HELCO. Information concerning the directors of HECO who are also directors of HEI is set forth above
under HEI and in the referenced sections of HEIs 2004 Proxy Statement.



Committees of the HECO Board



During 2003, the Board of Directors of HECO had one standing committee, the Audit Committee, which was comprised of four nonemployee directors: Diane J. Plotts, Chairman, Shirley J. Daniel, Anne M. Takabuki and Barry
K. Taniguchi. The Audit Committee holds such meetings as it deems advisable to review the financial operations of HECO. In 2003, the Audit Committee held six meetings to review various matters with management, the internal auditor and HECOs
independent auditors, including the activities of the internal auditor, the results of the annual audit by the independent auditors and the consolidated financial statements which are included in HECOs 2002 Annual Report to Stockholder.



The independence of the HECO Audit Committee has been
determined by the Board of Directors in accordance with the definition of independence in the Audit Committee charter and current standards sets forth in the New York Stock Exchange Listed Company Manual. Mr. Taniguchi, Dr. Daniel and Ms. Plotts
have been determined by the Board of Directors to be the audit committee financial experts on the Audit Committee.



Attendance at meetings



In 2003, there were six regular bi-monthly meetings of the HECO Board of Directors. All incumbent directors attended at least 75% of the combined total
number of meetings of the Board and the Audit Committee on which they served (during the period of their service).



Family relationships; director arrangements



There are no family relationships between any executive officer or director of HECO and any other executive officer or director of HECO, or any
arrangement or understanding between any executive officer or director of HECO and any person pursuant to which the executive officer or director of HECO was selected.



Code of Conduct



In connection with its periodic review of corporate governance trends and best practices, the HEI Board of Directors adopted a Revised Code of Conduct,
including the code of ethics for, among others, the chief executive officer and senior financial officers of HECO, which may be viewed on HEIs website at www.hei.com. HECO also elects to disclose the information required by Form 8-K,
Item 10, Amendments to the registrants code of ethics, or waiver of a provision of the code of ethics, through this website and such information will remain available on this website for at least a 12-month period. A copy of the
Revised Code of Conduct may be obtained free of charge upon written request from the HEI Vice President-Administration & Corporate Secretary, P.O. Box 730, Honolulu, Hawaii 96808-0730.



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|ITEM 11. | EXECUTIVE COMPENSATION
|-------- | ----------------------



HEI:



The information required under this item for HEI is incorporated by reference to the information under the captions Board of Directors  How often did the Board of Directors meet in 2003?, Board
of Directors  How are directors compensated?, Board of Directors  Do nonemployee directors receive a retirement benefit?, Committees of the Board  What committees has the Board established and how often did
they meet? and Executive Compensation in HEIs 2004 Proxy Statement.



HECO:



Remuneration of HECO
Directors



In 2003, Anne M. Takabuki and Barry K.
Taniguchi were the only nonemployee HECO directors who were not also directors of HEI. Commencing May 1, 2003, they each received an annual cash retainer of $20,000 (paid quarterly) and 300 shares of HEI stock. In order to receive the fourth quarter
installment, directors are required to have attended at least 75% of the combined total of all the Board and Committee meetings on which the director serves. The nonemployee HECO directors who were also nonemployee HEI directors received an annual
cash retainer of $10,000, paid quarterly, for their service on the HECO Board. In 2003, the Chairman of the HECO Audit Committee was paid an additional annual cash retainer of $5,000. Employee members of the Board of Directors are not compensated
for attendance at any meeting of the Board or Committees of the Board. Information concerning the directors of HECO who are also directors of HEI is set forth above under HEI and in the referenced sections of HEIs 2004 Proxy
Statement.



Ms. Plotts is the only nonemployee HECO director
who will receive retirement benefits upon retirement from service as a director. Additional information concerning nonemployee director retirement benefits is incorporated by reference to the information under the caption Board of Directors
 Do nonemployee directors receive a retirement benefit? in HEIs 2004 Proxy Statement.



Summary compensation table



The following summary compensation table shows the annual and long-term compensation of the chief executive officer of HECO and the four other most highly compensated executive officers of HECO (collectively, the HECO
Named Executive Officers) who served at the end of 2003. All compensation amounts presented for T. Michael May are the same amounts presented in HEIs 2004 Proxy Statement.



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SUMMARY COMPENSATION TABLE



|                                                                                          |  |              |  |                       |  |                        |  |                                   |                               |          |                                      |                    |                     |                                |  |                 
|----------------------------------------------------------------------------------------- |  | ------------ |  | --------------------- |  | ---------------------- |  | --------------------------------- | ----------------------------- | -------- | ------------------------------------ | ------------------ | ------------------- | ------------------------------ |  | ----------------
|                                                                                          |  |              |  | Annual Compensation   |  | Long-term Compensation |  |                                  
|                                                                                          |  |              |  |                       |  |                        |  | OtherAnnual Compen- sation(2) ($) |                               | Awards   |                                      | Payouts            |                     | AllOther Compen- sation(6) ($)
|Name and Principal Position                                                               |  | Year         |  | Salary ($)            |  | Bonus(1) ($)           |  |                                   | Restricted Stock Award(3) ($) |          | Securities Underlying Options(4) (#) |                    | LTIP Payouts(5) ($) |                               
|T. Michael May President and Chief Executive Officer                                      |  | 200320022001 |  | 513,000472,000415,000 |  | 294,012286,960163,257  |  | 000                               |                               | 000      |                                      | 25,00025,00020,000 |                     | 154,368150,64554,540           |  | 8,2087,31418,881
|Robert A. Alm(7) Senior Vice President- Public Affairs                                    |  | 200320022001 |  | 238,000223,000100,000 |  | 165,99657,22730,367    |  | 000                               |                               | 000      |                                      | 6,00000            |                     | NANANA                         |  | 2,0581,6982,825 
|Thomas L. Joaquin Senior Vice President- Operations                                       |  | 200320022001 |  | 239,000223,000202,000 |  | 88,94949,38558,597     |  | 000                               |                               | 000      |                                      | 6,00003,000        |                     | NANANA                         |  | 4,7874,47511,745
|Karl C. Stahlkopf(8) Senior Vice President- Energy Solutions and Chief Technology Officer |  | 20032002     |  | 287,000187,000        |  | 69,88252,421           |  | 0100,000                          |                               | 0140,880 |                                      | 6,0000             |                     | NANA                           |  | 8,0184,929      
|Jackie Mahi Erickson Vice President & General Counsel                                     |  | 200320022001 |  | 194,000181,000175,000 |  | 90,92238,86947,844     |  | 000                               |                               | 000      |                                      | 3,00003,000        |                     | NANANA                         |  | 5,4204,92913,503



|NA | Not applicable (not participants in the plan).
|-- | ----------------------------------------------



|(1) | The HECO Named Executive Officers are eligible for an incentive award under the Companys annual Executive Incentive Compensation Plan (EICP). EICP bonus
payouts are reflected as compensation for the year earned. Also includes special awards in 2003 to Mr. Alm for $100,000, Mr. Joaquin for $24,000 and Ms. Erickson for $36,000.
|--- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(2) | Covers a signing bonus of $100,000 for Mr. Stahlkopf for 2002.
|--- | --------------------------------------------------------------



|(3) | On May 1, 2002, 3,000 shares of restricted stock were granted to Mr. Stahlkopf. On the date of grant, the closing price of HEI Common Stock was $46.96 on the New
York Stock Exchange. Quarterly dividends on the 3,000 shares of restricted stock are paid to Mr. Stahlkopf. The 3,000 shares of restricted stock become unrestricted on May 1, 2007. On December 31, 2003, the restricted stock value was $142,110 based
on the closing price of $47.37 per share on the New York Stock Exchange.
|--- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(4) | Options granted earn dividend equivalents as further described below under the headings Option grants in last fiscal year and Aggregated option
exercises and fiscal year-end option values.
|--- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(5) | Long-Term Incentive Plan (LTIP) payouts are determined in the first quarter of each year for the three-year cycle ending on December 31 of the previous calendar
year.
|--- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(6) | Represents amounts attributable each year by the Company for certain preretirement death benefits provided to the HECO Named Executive Officers. Additional
information concerning these death benefits is incorporated by reference to the information under the caption Executive Compensation  Compensation Committee Report on Executive Compensation  Other Compensation Plans in
HEIs 2004 Proxy Statement.
|--- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(7) | Mr. Alm joined HECO as the Senior Vice President-Public Affairs on July 1, 2001.
|--- | --------------------------------------------------------------------------------



|(8) | Mr. Stahlkopf joined HECO as the Senior Vice President-Energy Solutions and Chief Technology Officer on May 1, 2002.
|--- | --------------------------------------------------------------------------------------------------------------------



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Option grants in last fiscal year



The following table presents information on the nonqualified stock options to acquire HEI common stock which were granted in
2003 to the executives named in the HECO Summary Compensation Table. The practice of granting stock options, which may include dividend equivalent shares, has been followed each year since 1987.



OPTION GRANTS IN LAST FISCAL YEAR



|                     |  |                                                    |  |                                                          |   |  |                         |       |                 |                |                               |   |        
|-------------------- |  | -------------------------------------------------- |  | -------------------------------------------------------- | - |  | ----------------------- | ----- | --------------- | -------------- | ----------------------------- | - | -------
|                     |  | Number ofSecuritiesUnderlyingOptionsGranted (1)(#) |  | Percent ofTotal OptionsGranted toEmployees inFiscal Year |   |  | ExercisePrice ($/share) |       | Expiration Date |                | Grant DatePresentValue (2)($)
|T. Michael May       |  | 25,000                                             |  | 11                                                       | % |  | $                       | 40.98 |                 | April 21, 2013 |                               | $ | 227,500
|Robert A. Alm        |  | 6,000                                              |  | 3                                                        |   |  |                         | 40.98 |                 | April 21, 2013 |                               |   | 54,600 
|Thomas L. Joaquin    |  | 6,000                                              |  | 3                                                        |   |  |                         | 40.98 |                 | April 21, 2013 |                               |   | 54,600 
|Karl C. Stahlkopf    |  | 6,000                                              |  | 3                                                        |   |  |                         | 40.98 |                 | April 21, 2013 |                               |   | 54,600 
|Jackie Mahi Erickson |  | 3,000                                              |  | 1                                                        |   |  |                         | 40.98 |                 | April 21, 2013 |                               |   | 27,300 



|(1) | These options vest in four equal annual installments. Additional dividend equivalent shares
are granted at no additional cost throughout the four-year vesting period. Dividend equivalents are computed, as of each dividend record date, both with respect to the number of shares under the option and with respect to the number of dividend
equivalent shares previously credited to the participant and not issued during the period prior to the dividend record date. Accelerated vesting is provided in the event a change-in-control occurs. No stock appreciation rights have been granted
under the HEIs stock option plans.
|--- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(2) | Based on a Binomial Option Pricing Model, which is a variation of the Black-Scholes Option
Pricing Model calculated by the HEI Compensation Committees independent compensation consulting firm. For the stock options granted on April 21, 2003, with a 10-year option period, an exercise price of $40.98 which is equal to the fair market
value on the date of grant, and with additional dividend equivalent shares granted for the first four years of the option, the Binomial Value adjusted for forfeiture risk is $9.10 per share. The following assumptions were used in the model: Stock
Price: $40.98; Term: 10 years; Volatility: 0.1841; Risk-Free Interest Rate: 4.37 %; and Dividend Yield: 6.64%. The following were the valuation results: Binomial Option Value: $4.86; Dividend Credit Value: $4.24; and Total Value: $9.10.
|--- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



In calculating the grant date present values
set forth in the table, the volatility and dividend yield were based on the monthly closing stock prices and dividends for the three-year period preceding the grant date. The risk-free interest rate was fixed on the date of grant at the rate of
return on a stripped U.S. Treasury bill with a term to maturity approximately equal to the options expected life. Dividend equivalents are payable on the options for a period of four years. The value of the dividend equivalents was determined
on the basis of the dividend yield, using the monthly closing stock prices and dividends for the three-year period preceding the grant date. The use of different assumptions can produce significantly different estimates of the present value of
options. Consequently, the grant date present value set forth in the table is only theoretical and may not accurately represent present value. The actual value, if any, an optionee will realize will depend on the excess of the market value of the
HEI Common Stock over the exercise price on the date the option is exercised, plus the value of the dividend equivalents.



Aggregated option exercises and fiscal year-end option
values



The following table shows the stock options,
including dividend equivalents, exercised by the HECO Named Executive Officers in 2003. Also shown is the number of securities underlying unexercised options and the value of unexercised in the money options, including dividend equivalents, at the
end of 2003. HEI granted dividend equivalents to all HECO Named Executive Officers as part of the stock option grant, except Mr. Joaquins 1995 stock option grant.



Dividend equivalents permit a participant who exercises a stock option to obtain at no additional cost, in addition to the
option shares, the amount of dividends declared between the grant and the exercise of the option during the vesting period. Dividend equivalents are computed as of each dividend record date throughout the four-year vesting period, both with respect
to the number of shares under the option and the number of dividend equivalent shares previously credited to the HECO Named Executive Officer, which have not been exercised/issued during the period prior to the dividend record date.



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AGGREGATED OPTION EXERCISES IN LAST FISCAL YEAR AND

FISCAL YEAR-END OPTION VALUES



|                     |  |                              |  |                                             |                                |                             |                                |                                          |  |                                                                                                        |  |                                                                                              
|-------------------- |  | ---------------------------- |  | ------------------------------------------- | ------------------------------ | --------------------------- | ------------------------------ | ---------------------------------------- |  | ------------------------------------------------------------------------------------------------------ |  | ---------------------------------------------------------------------------------------------
|Name                 |  | Shares AcquiredOnExercise(#) |  | Dividend EquivalentsAcquired OnExercise (#) |                                | Value RealizedOn Options($) |                                | Value Realized On DividendEquivalents($) |  | Number of SecuritiesUnderlying Unexercised Options (Including Dividend Equivalents)
at Fiscal Year-End |  | Value of UnexercisedIn theMoney Options(Including Dividend Equivalents)at Fiscal Year-End (1)
|                     |  |                              |  |                                             | Exercisable/ Unexercisable (#) |                             | Exercisable/ Unexercisable ($)
|T. Michael May       |  | 10,000                       |  | 3,042                                       |                                | 74,500                      |                                | 129,788                                  |  | 50,686 /64,934                                                                                         |  | 976,510 /731,803                                                                             
|Robert A. Alm        |  |                             |  |                                            |                                |                            |                                |                                         |  |  /6,267                                                                                               |  |  /50,990                                                                                    
|Thomas L. Joaquin    |  |                             |  |                                            |                                |                            |                                |                                         |  | 12,637 / 8,033                                                                                         |  | 236,783 / 80,770                                                                             
|Karl C. Stahlkopf    |  |                             |  |                                            |                                |                            |                                |                                         |  |  / 6,267                                                                                              |  |  / 50,990                                                                                   
|Jackie Mahi Erickson |  |                             |  |                                            |                                |                            |                                |                                         |  | 1,861 / 4,900                                                                                          |  | 34,819 / 55,275                                                                              



|(1) | Values based on the closing price of $47.37 per share on the New York Stock Exchange on December 31, 2003.
|--- | ----------------------------------------------------------------------------------------------------------



Long-Term Incentive Plan awards table



A Long-Term Incentive Plan award made to Mr. May was the only such award
made to the HECO Named Executive Officers in 2003. Additional information required under this item is incorporated by reference to the information under the caption Executive Compensation  Long-Term Incentive Plan (LTIP) Award in
HEIs 2004 Proxy Statement.



Pension plans



Each of the HECO Named Executive Officers participates in the Retirement
Plan for Employees of Hawaiian Electric Industries, Inc. and Participating Subsidiaries (the Retirement Plan). In addition, Mr. May (but not the other HECO Named Executive Officers) participates in certain supplemental pension plans sponsored by
HEI. For additional information required under this item for Mr. May, see the information under the caption Executive Compensation  Pension Plans in HEIs 2004 Proxy Statement.



The Retirement Plan provides a monthly retirement pension for life.
Additional information required under this item is incorporated by reference to the information under the caption Executive Compensation  Pension Plans in HEIs 2004 Proxy Statement. As of December 31, 2003, the HECO Named
Executive Officers had the following number of years of credited service under the Retirement Plan: Mr. May, 11 years; Mr. Alm, 2 years; Mr. Joaquin, 30 years; Mr. Stahlkopf, 1 year; and Ms. Erickson, 22 years.



Change-in-Control Agreements



HECO does not have change-in-control agreements with any of the HECO Named
Executive Officers. Mr. May is the only HECO Named Executive Officer with whom HEI has a Change-in-Control Agreement. Additional information required under this item is incorporated by reference to the information under the caption Executive
Compensation  Change-in-Control Agreements in HEIs 2004 Proxy Statement.



Executive Management Compensation



The HEI Compensation Committee, composed of six independent nonemployee directors of HEI, approves executive compensation for the HECO Named Executive Officers. The information required to be disclosed concerning the
Compensation Committee is incorporated herein by reference to the information under the captions Committees of the Board and Executive Compensation  Compensation Committee Report on Executive Compensation in HEIs
2004 Proxy Statement. Actions of the HEI Compensation Committee are subject to ratification by the full HEI and HECO Boards of Directors (excluding any affected individuals).



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|ITEM 12. | SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
|-------- | --------------------------------------------------------------



HEI:



The information required under this item is incorporated by reference to the information under the captions Stock Ownership Information  How much stock do the Companys directors and executive
officers own? and Stock Ownership Information  Does anyone own more than 5% of the Companys stock? in HEIs 2004 Proxy Statement and Market for Registrants Common Equity and Related Stockholder
Mattersequity compensation plan information herein.



HECO:



HEI owns all of HECOs common
stock, which is HECOs only class of securities generally entitled to vote on matters requiring shareholder approval. HECO has also issued and has outstanding various series of preferred stock, the holders of which, upon certain defaults in
dividend payments, have the right to elect a majority of the directors of HECO.



The following table shows the shares of HEI common stock beneficially owned by each HECO director (other than those who are also directors of HEI), by each HECO Named Executive Officer (other than Mr. May, who is a
named executive officer of HEI) and by all HECO directors and all HECO executive officers as a group, as of February 11, 2004, based on information furnished by the respective individuals.



|                                                             |  |                               |  |                                     |  |                              |  |                   |  |         |  
|------------------------------------------------------------ |  | ----------------------------- |  | ----------------------------------- |  | ---------------------------- |  | ----------------- |  | ------- | -
|Amount of Common Stock and Nature of Beneficial Ownership    | 
|Name of Individual or Group                                  |  | Sole Voting orInvestmentPower |  | Shared Votingor InvestmentPower (1) |  | OtherBeneficialOwnership (2) |  | Stock Options (3) |  | Total   |  
|Directors                                                    |  |                               |  |                                     |  |                              |  |                   |  |         |  
|Anne M. Takabuki                                             |  | 2,969                         |  |                                    |  |                             |  |                  |  | 2,969   |  
|Barry K. Taniguchi                                           |  |                              |  | 2,345                               |  |                             |  |                  |  | 2,345   |  
|                                                             |  |                               |  |                                     | 
|Other HECO Named Executive Officers                          |  |                               |  |                                     |  |                              |  |                   |  |         |  
|Robert A. Alm                                                |  | 2,287                         |  |                                    |  |                             |  |                  |  | 2,287   |  
|Thomas L. Joaquin                                            |  | 6,686                         |  | 1,599                               |  | 35                           |  | 12,658            |  | 20,978  |  
|Karl C. Stahlkopf                                            |  | 3,537                         |  |                                    |  |                             |  |                  |  | 3,537   |  
|Jackie Mahi Erickson                                         |  | 5,036                         |  | 1,298                               |  |                             |  | 893               |  | 7,227   |  
|All directors and executive Officers as a group (21 persons) |  | 78,749                        |  | 15,089                              |  | 3,308                        |  | 161,539           |  | 258,685 | *



|* | HECO directors Clarke, Daniel, May, Plotts, Scott and Watanabe, who also serve on the HEI Board of Directors, are not shown separately in this table, but are included in the total
for all HECO directors and executive officers as a group. The information required as to these directors is incorporated by reference to the information under the caption Stock Ownership Information  How much stock do the Companys
directors and executive officers own? in HEIs 2004 Proxy Statement. The number of shares of common stock beneficially owned by any HECO director or by all HECO directors and officers as a group does not exceed 1% of the outstanding
common stock of HEI.
|- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|(1) | Shares registered in name of the individual and spouse.
|--- | -------------------------------------------------------



|(2) | Shares owned by spouse, children or other relatives sharing the home of the director or officer in which the director or officer disclaims personal
interest.
|--- | -------------------------------------------------------------------------------------------------------------------------------------------------------------



|(3) | Stock options, including accompanying dividend equivalents shares, exercisable within 60 days after February 11, 2004, under the 1987 Stock Option and Incentive
Plan.
|--- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------



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|ITEM 13. | CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
|-------- | ----------------------------------------------



HEI:



The information required under this item is incorporated by reference to the information under the captions Indebtedness of Management and Transactions with Directors and Executive Officers in
HEIs 2004 Proxy Statement.



HECO:



Information required under this item for HECO directors and officers who are
also directors or officers of HEI is incorporated by reference to the information under the captions Indebtedness of Management and Transactions with Directors and Executive Officers in HEIs 2004 Proxy Statement. In
addition, Karl C. Stahlkopf was indebted to HECO in the amount of $162,500 for an employee relocation loan made to him on May 22, 2002, prior to the enactment of the Sarbanes-Oxley Act of 2002. The loan was interest free with the principal balance
paid by the due date of May 22, 2003. Director Jeffrey Watanabe is a partner in the law firm of Watanabe Ing Kawashima & Komeiji LLP which performed legal services for HEI and certain of its subsidiaries (including HECO and HELCO) during 2003.



|ITEM 14. | PRINCIPAL ACCOUNTING FEES AND SERVICES
|-------- | --------------------------------------



HEI:



The information required under this item is incorporated by reference to the relevant information under the caption Audit Committee Report in HEIs 2004 Proxy Statement (but no other part of the
Audit Committee Report is incorporated by reference).



HECO:



Certain information required as to HECO under this item
is included in the disclosures for HEI under the caption Audit Committee Report in HEIs 2004 Proxy Statement, which is incorporated by reference above.



Fees of HECOs Principal Accountant



The following table sets forth the aggregate fees billed to HECO for the years ended December 31, 2003 and 2002 by KPMG LLP,
HECOs independent auditor:



|                                                                                                                                                                                                                                                                                                                  |  |      |         |      |   |        
|----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------- |  | ---- | ------- | ---- | - | -------
|                                                                                                                                                                                                                                                                                                                  |  | 2003 |         | 2002
|Audit fees (principally consisted of fees associated with the audit and quarterly reviews of the consolidated financial statements, issuances
of letters to underwriters, accounting consultations on matters reflected in the financial statements, review of registration statements, and issuance of consents) |  | $    | 365,000 |      | $ | 300,000
|Audit related fees (principally consisted of fees associated with the audit of the financial statements of certain employee benefit
plans)                                                                                                                                                                        |  |      | 9,000   |      |   | 8,000  
|Tax fees                                                                                                                                                                                                                                                                                                          |  |      |        |      |   |       
|All other fees                                                                                                                                                                                                                                                                                                    |  |      |        |      |   |       
|                                                                                                                                                                                                                                                                                                                  |  |      |         |      |   |        
|                                                                                                                                                                                                                                                                                                                  |  | $    | 374,000 |      | $ | 308,000
|                                                                                                                                                                                                                                                                                                                  |  |      |         |      |   |        



Pre-approval Policies



The HECO Audit Committee approved and adopted preapproval
policies and procedures for nonaudit services proposed to be performed by HECOs independent auditor. The policies and procedures were implemented in 2002. Departmental requests for nonaudit services are reviewed by senior management and, once
approved, are forwarded to the Chair of the Audit Committee for preapproval. The Audit Committee ratifies the Chairs preapproval at its next scheduled meeting. In addition, the HECO Audit Committee reviewed the professional fees billed by KPMG
LLP and determined that the provision of nonaudit services was compatible with the maintenance of the auditors independence.



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##### Table of Contents

PART IV



|ITEM 15. | EXHIBITS, FINANCIAL STATEMENT SCHEDULES AND REPORTS ON FORM 8-K
|-------- | ---------------------------------------------------------------



(a)(1) Financial statements



The following financial statements for HEI and HECO are included in this report on the pages indicated below:



|                                                                                                         |  |                                                                      |  |     
|-------------------------------------------------------------------------------------------------------- |  | -------------------------------------------------------------------- |  | ----
|                                                                                                         |  | Pages in HEIsAnnual Reportand HECOsConsolidatedFinancialStatements
|                                                                                                         |  | HEI                                                                  |  | HECO
|Independent Auditors Report                                                                             |  | 39                                                                   |  | 39  
|Consolidated Statements of Income, Years ended December 31, 2003, 2002 and 2001                          |  | 40                                                                   |  | 1   
|Consolidated Statements of Retained Earnings, Years ended December 31, 2003, 2002 and 2001               |  | NA                                                                   |  | 1   
|Consolidated Balance Sheets, December 31, 2003 and 2002                                                  |  | 41                                                                   |  | 2   
|Consolidated Statements of Capitalization, December 31, 2003 and 2002                                    |  | NA                                                                   |  | 3-4 
|Consolidated Statements of Changes in Stockholders Equity, Years ended December 31, 2003, 2002 and 2001 |  | 42                                                                   |  | NA  
|Consolidated Statements of Cash Flows, Years ended December 31, 2003, 2002 and 2001                      |  | 43                                                                   |  | 5   
|Notes to Consolidated Financial Statements                                                               |  | 44-88                                                                |  | 6-38



|NA | Not applicable.
|-- | ---------------



(a)(2) Financial statement schedules



The following financial statement schedules for HEI and HECO are included in this report on the pages indicated below:



|                             |  |                                                                                                                                                                                      |  |                     |  |     
|---------------------------- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------ |  | ------------------- |  | ----
|                             |  |                                                                                                                                                                                      |  | Page/s in Form 10-K
|                             |  |                                                                                                                                                                                      |  | HEI                 |  | HECO
|Independent Auditors Report |  | 81                                                                                                                                                                                   |  | 82                 
|Schedule I                   |  | Condensed Financial Information of Registrant, Hawaiian Electric Industries, Inc. (Parent Company) as of December 31, 2003 and 2002 and Years
ended December 31, 2003, 2002 and 2001 |  | 83-85               |  | NA  
|Schedule II                  |  | Valuation and Qualifying Accounts, Years ended December 31, 2003, 2002 and 2001                                                                                                      |  | 86                  |  | 86  



|NA | Not applicable.
|-- | ---------------



Certain schedules, other than those listed, are omitted because they are not required, or are not applicable, or the required information is shown in the
consolidated financial statements (including the notes) included in HEIs Consolidated Financial Statements and HECOs Consolidated Financial Statements, which are included in this report.



79



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##### Table of Contents

(a)(3) Exhibits



Exhibits for HEI and HECO and their subsidiaries are listed in the Index to Exhibits found on pages 87 through 97 of this Form 10-K. The
exhibits listed for HEI and HECO are listed in the index under the headings HEI and HECO, respectively, except that the exhibits listed under HECO are also considered exhibits for HEI.



(b) Reports on Form 8-K



HEI and HECO:



Subsequent to September 30, 2003, HEI and/or HECO filed Current Reports, Forms 8-K, with the SEC as follows:



|                                      |  |              |  |                                                                                                                                                                      
|------------------------------------- |  | ------------ |  | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Dated (filing date)                   |  | Registrant/s |  | Items reported                                                                                                                                                       
|October 27, 2003 (October 27, 2003)   |  | HEI/HECO     |  | Items 5 and 12. HEIs October 27, 2003 news release (HEI reports third quarter 2003 earnings)                                                                        
|                                      |  |             
|November 11, 2003 (November 12, 2003) |  | HEI/HECO     |  | Item 5. HELCO power situation update                                                                                                                                 
|                                      |  |             
|November 25, 2003 (November 25, 2003) |  | HEI/HECO     |  | Item 5. HEIs November 25, 2003 news release (HEI to webcast and teleconference financial analyst presentation on Tuesday, December 2, 2003)                         
|                                      |  |             
|December 10, 2003 (December 10, 2003) |  | HEI/HECO     |  | Item 5. Pension and other postretirement benefits and HELCO power situation updates                                                                                  
|                                      |  |             
|December 31, 2003 (January 2, 2004)   |  | HEI          |  | Item 5. Disposition of certain debt securities update                                                                                                                
|                                      |  |             
|January 6, 2004 (January 8, 2004)     |  | HEI/HECO     |  | Item 5. HEIPC and Settlement of Maalaea Units 12 and 13 notice and finding of violation updates                                                                      
|                                      |  |             
|January 13, 2004 (January 14, 2004)   |  | HEI/HECO     |  | Item 5. HEIs January 13, 2004 news release (HEI to webcast and teleconference 2003 year-end earnings on Tuesday, January 20, 2004)                                  
|                                      |  |             
|January 20, 2004 (January 21, 2004)   |  | HEI/HECO     |  | Items 5 and 12. HEIs January 20, 2004 news release (HEI reports 2003 year-end and fourth quarter earnings) and pension and other postretirement benefits information
|                                      |  |             
|February 26, 2004 (February 26, 2004) |  | HEI/HECO     |  | Item 7. HEIs 2003 Annual Report to Shareholders, HECOs Consolidated 2003 Financial Statements and 906 certifications                                               



80



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##### Table of Contents

[KPMG LLP letterhead]



Independent Auditors Report



The Board of
Directors and Stockholders

Hawaiian Electric Industries, Inc.:



Under date of February 11, 2004, we reported on the consolidated balance sheets of Hawaiian Electric Industries, Inc. and subsidiaries as of December 31, 2003 and 2002,
and the related consolidated statements of income, changes in stockholders equity and cash flows for each of the years in the three-year period ended December 31, 2003, as contained in the 2003 annual report to stockholders. These consolidated
financial statements and our report thereon are incorporated by reference in the Companys annual report on Form 10-K for the year 2003. In connection with our audits of the aforementioned consolidated financial statements, we also audited the
related financial statement schedules as listed in the accompanying index under Item 15.(a)(2). These financial statement schedules are the responsibility of the Companys management. Our responsibility is to express an opinion on these
financial statement schedules based on our audits.



In our opinion, such
financial statement schedules, when considered in relation to the basic consolidated financial statements taken as a whole, present fairly, in all material respects, the information set forth therein.



As discussed in note 1 of notes to consolidated financial statements, effective January 1,
2002, the Company changed its method of accounting for goodwill and other intangible assets and for stock-based compensation.



|                 
|-----------------
|                 
|/s/ KPMG LLP     
|                 
|Honolulu, Hawaii 
|February 11, 2004



81



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[KPMG LLP letterhead]



Independent Auditors Report



The Board of
Directors and Stockholder

Hawaiian Electric Company, Inc.:



Under date of February 11, 2004, we reported on the consolidated balance sheets and consolidated statements of capitalization of Hawaiian Electric Company, Inc. (a
subsidiary of Hawaiian Electric Industries, Inc.) and subsidiaries as of December 31, 2003 and 2002, and the related consolidated statements of income, retained earnings and cash flows for each of the years in the three-year period ended December
31, 2003. These consolidated financial statements and our report thereon are incorporated by reference in the Companys annual report on Form 10-K for the year 2003. In connection with our audits of the aforementioned consolidated financial
statements, we also audited the related financial statement schedule as listed in the accompanying index under Item 15.(a)(2). The financial statement schedule is the responsibility of the Companys management. Our responsibility is to express
an opinion on the financial statement schedule based on our audits.



In our
opinion, such financial statement schedule, when considered in relation to the basic consolidated financial statements taken as a whole, presents fairly, in all material respects, the information set forth therein.



|                 
|-----------------
|                 
|/s/ KPMG LLP     
|                 
|Honolulu, Hawaii 
|February 11, 2004



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##### Table of Contents

Hawaiian Electric Industries, Inc.

SCHEDULE I  CONDENSED FINANCIAL INFORMATION OF REGISTRANT

HAWAIIAN
ELECTRIC INDUSTRIES, INC. (PARENT COMPANY)

CONDENSED BALANCE SHEETS



|                                                                                                               |  |              |           |      |   |          
|-------------------------------------------------------------------------------------------------------------- |  | ------------ | --------- | ---- | - | ---------
|                                                                                                               |  | December 31,
|(in thousands)                                                                                                 |  | 2003         |           | 2002
|Assets                                                                                                         |  |              |           |      |   |          
|Cash and equivalents                                                                                           |  | $            | 12,009    |      | $ | 25,059   
|Advances to and notes receivable from subsidiaries                                                             |  |              | 6,000     |      |   | 5,600    
|Available-for-sale investment securities                                                                       |  |              | 12,124    |      |   | 7,971    
|Accounts receivable                                                                                            |  |              | 11,970    |      |   | 1,593    
|Property, plant and equipment, net                                                                             |  |              | 1,815     |      |   | 2,089    
|Deferred income tax assets                                                                                     |  |              | 16,289    |      |   | 13,110   
|Other assets                                                                                                   |  |              | 5,281     |      |   | 4,152    
|Net assets of discontinued operations                                                                          |  |              |          |      |   | 787      
|Investments in subsidiaries, at equity                                                                         |  |              | 1,532,101 |      |   | 1,512,423
|                                                                                                               |  |              |           |      |   |          
|                                                                                                               |  | $            | 1,597,589 |      | $ | 1,572,784
|                                                                                                               |  |              |           |      |   |          
|Liabilities and stockholders equity                                                                           |  |              |           |      |   |          
|Liabilities                                                                                                    |  |              |           |      |   |          
|Accounts payable                                                                                               |  | $            | 8,350     |      | $ | 8,108    
|Notes payable to subsidiaries                                                                                  |  |              | 14,371    |      |   | 10,922   
|Long-term debt, net                                                                                            |  |              | 365,000   |      |   | 401,000  
|Loan from HEI Preferred Funding, LP (8.36% due in 2017)                                                        |  |              | 103,000   |      |   | 103,000  
|Other                                                                                                          |  |              | 12,845    |      |   | 3,454    
|Net liabilities of discontinued operations                                                                     |  |              | 4,992     |      |   |         
|                                                                                                               |  |              |           |      |   |          
|                                                                                                               |  |              | 508,558   |      |   | 526,484  
|                                                                                                               |  |              |           |      |   |          
|Stockholders equity                                                                                           |  |              |           |      |   |          
|Preferred stock, no par value, authorized 10,000 shares; issued: none                                          |  |              |          |      |   |         
|Common stock, no par value, authorized 100,000 shares; issued and outstanding: 37,919 shares and 36,809 shares |  |              | 888,431   |      |   | 839,503  
|Retained earnings                                                                                              |  |              | 197,774   |      |   | 176,118  
|Accumulated other comprehensive income                                                                         |  |              | 2,826     |      |   | 30,679   
|                                                                                                               |  |              |           |      |   |          
|                                                                                                               |  |              | 1,089,031 |      |   | 1,046,300
|                                                                                                               |  |              |           |      |   |          
|                                                                                                               |  | $            | 1,597,589 |      | $ | 1,572,784
|                                                                                                               |  |              |           |      |   |          
|Note to Balance Sheets                                                                                         |  |              |           |      |   |          
|Long-term debt consisted of the following:                                                                     |  |              |           |      |   |          
|Promissory notes, 4.0 - 7.6%, due in various years from 2004 through 2014                                      |  | $            | 365,000   |      | $ | 301,000  
|Promissory note, 5.5%, paid in 2003                                                                            |  |              |          |      |   | 100,000  
|                                                                                                               |  |              |           |      |   |          
|                                                                                                               |  | $            | 365,000   |      | $ | 401,000  
|                                                                                                               |  |              |           |      |   |          



The aggregate payments
of principal required subsequent to December 31, 2003 on long-term debt are $1 million in 2004, $37 million in 2005, $110 million in 2006, $10 million in 2007 and $50 million in 2008.



As of December 31, 2003, HEI has a General Agreement of Indemnity in favor of SAFECO Insurance Company for losses in
connection with any insurance/surety bonds they issue to HEI, including $10 million in mail insurance, a $1 million transfer agent errors and omissions bond and a $0.5 million self-insured automobile bond.



HEI guarantees payment by HEI Capital Trust I (the Trust) of distributions on
the trust securities insofar as the Trust has funds sufficient for the payment of such distributions. HEI guarantees payment by HEI Preferred Funding, LP (the Partnership) of distributions on the Partnership Preferred Securities insofar as such
distributions have been declared by the Partnership and the Partnership has sufficient funds for the payment of such distributions.



83



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##### Table of Contents

Hawaiian Electric Industries, Inc.

SCHEDULE I  CONDENSED FINANCIAL INFORMATION OF REGISTRANT (continued)

HAWAIIAN ELECTRIC INDUSTRIES, INC. (PARENT COMPANY)

CONDENSED STATEMENTS OF INCOME



|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|------------------------------------------------------------ |  | ------------------------ | ------- | - | ---- | - | ------- | ---- |  | - | ------- | -
|                                                             |  | Years ended December 31, |        
|(in thousands)                                               |  | 2003                     |         |   | 2002 |   |         | 2001 | 
|Revenues1, 2                                                 |  | $                        | 10,765  |   |      | $ | (3,881  | )    |  | $ | (5,338  | )
|Equity in income from continuing operations of subsidiaries  |  |                          | 142,354 |   |      |   | 152,725 |      |  |   | 143,730 |  
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|                                                             |  |                          | 153,119 |   |      |   | 148,844 |      |  |   | 138,392 |  
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|Expenses:                                                    |  |                          |         |   |      |   |         |      |  |   |         |  
|Operating, administrative and general                        |  |                          | 15,927  |   |      |   | 15,633  |      |  |   | 10,481  |  
|Depreciation of property, plant and equipment                |  |                          | 403     |   |      |   | 891     |      |  |   | 1,047   |  
|Taxes, other than income taxes                               |  |                          | 345     |   |      |   | 460     |      |  |   | 472     |  
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|                                                             |  |                          | 16,675  |   |      |   | 16,984  |      |  |   | 12,000  |  
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|Operating income                                             |  |                          | 136,444 |   |      |   | 131,860 |      |  |   | 126,392 |  
|Interest expense                                             |  |                          | 33,993  |   |      |   | 37,576  |      |  |   | 43,539  |  
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|Income from continuing operations before income tax benefits |  |                          | 102,451 |   |      |   | 94,284  |      |  |   | 82,853  |  
|Income tax benefits                                          |  |                          | 15,597  |   |      |   | 23,933  |      |  |   | 24,893  |  
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|Income from continuing operations                            |  |                          | 118,048 |   |      |   | 118,217 |      |  |   | 107,746 |  
|Loss from discontinued subsidiary operations                 |  |                          | (3,870  | ) |      |   |        |      |  |   | (24,041 | )
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  
|Net income                                                   |  | $                        | 114,178 |   |      | $ | 118,217 |      |  | $ | 83,705  |  
|                                                             |  |                          |         |   |      |   |         |      |  |   |         |  



|1 | 2003 revenues include $9.3 million from the settlement of lawsuits in the fourth quarter of 2003.
|- | -------------------------------------------------------------------------------------------------



|2 | 2002 and 2001 revenues include $4.5 million and $8.7 million, respectively, of writedowns of the income notes that HEI purchased in connection with the termination
of ASBs investment in trust certificates in 2001. There were no writedowns of the income notes in 2003. See Disposition of certain debt securities in BusinessBankAmerican Savings Bank, F.S.B.
|- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



The Companys financial reporting policy
for income tax allocations is based upon a separate entity concept whereby each subsidiary provides income tax expense (or benefits) as if each were a separate taxable entity. The difference between the aggregate separate tax return income tax
provisions and the consolidated financial reporting income tax provision is charged or credited to HEIs separate tax provision.



84



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Hawaiian Electric Industries, Inc.

SCHEDULE I  CONDENSED FINANCIAL INFORMATION OF REGISTRANT (continued)

HAWAIIAN ELECTRIC INDUSTRIES, INC. (PARENT COMPANY)

CONDENSED STATEMENTS OF CASH FLOWS



|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|------------------------------------------------------------------------------------------------------- |  | ------------------------ | -------- | - | ---- | - | -------- | ---- |  | - | -------- | -
|                                                                                                        |  | Years ended December 31, |         
|(in thousands)                                                                                          |  | 2003                     |          |   | 2002 |   |          | 2001 | 
|Cash flows from operating activities                                                                    |  |                          |          |   |      |   |          |      |  |   |          |  
|Income from continuing operations                                                                       |  | $                        | 118,048  |   |      | $ | 118,217  |      |  | $ | 107,746  |  
|Adjustments to reconcile income from continuing operations to net cash provided by operating activities |  |                          |          |   |      |   |          |      |  |   |          |  
|Equity in net income of continuing subsidiaries                                                         |  |                          | (142,354 | ) |      |   | (152,725 | )    |  |   | (143,730 | )
|Common stock dividends/distributions received from subsidiaries                                         |  |                          | 89,722   |   |      |   | 78,599   |      |  |   | 62,944   |  
|Depreciation of property, plant and equipment                                                           |  |                          | 403      |   |      |   | 891      |      |  |   | 1,047    |  
|Other amortization                                                                                      |  |                          | 448      |   |      |   | 500      |      |  |   | 579      |  
|Writedowns of income notes                                                                              |  |                          |         |   |      |   | 4,499    |      |  |   | 8,652    |  
|Deferred income taxes                                                                                   |  |                          | (4,769   | ) |      |   | (6,495   | )    |  |   | (6,778   | )
|Changes in assets and liabilities                                                                       |  |                          |          |   |      |   |          |      |  |   |          |  
|Decrease (increase) in accounts receivable                                                              |  |                          | (10,377  | ) |      |   | 239      |      |  |   | (638     | )
|Increase (decrease) in accounts payable                                                                 |  |                          | 242      |   |      |   | 31       |      |  |   | (346     | )
|Increase (decrease) in taxes accrued                                                                    |  |                          | 10,787   |   |      |   | 10,988   |      |  |   | (47,603  | )
|Changes in other assets and liabilities                                                                 |  |                          | 6,669    |   |      |   | 5,266    |      |  |   | 4,709    |  
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Net cash provided by (used in) operating activities                                                     |  |                          | 68,819   |   |      |   | 60,010   |      |  |   | (13,418  | )
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Cash flows from investing activities                                                                    |  |                          |          |   |      |   |          |      |  |   |          |  
|Net decrease (increase) in advances to and notes receivable from subsidiaries                           |  |                          | (400     | ) |      |   | 42,697   |      |  |   | (39,533  | )
|Purchase of investments                                                                                 |  |                          |         |   |      |   |         |      |  |   | (27,929  | )
|Capital expenditures                                                                                    |  |                          | (131     | ) |      |   | (396     | )    |  |   | (916     | )
|Additional investments in subsidiaries                                                                  |  |                          | (145     | ) |      |   | (325     | )    |  |   | (1,424   | )
|Other                                                                                                   |  |                          | 17       |   |      |   | 480      |      |  |   | 16       |  
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Net cash provided by (used in) investing activities                                                     |  |                          | (659     | ) |      |   | 42,456   |      |  |   | (69,786  | )
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Cash flows from financing activities                                                                    |  |                          |          |   |      |   |          |      |  |   |          |  
|Net increase in notes payable to subsidiaries with original maturities of three months or less          |  |                          | 3,449    |   |      |   | 4,608    |      |  |   | 2,675    |  
|Proceeds from issuance of long-term debt                                                                |  |                          | 100,000  |   |      |   |         |      |  |   | 100,000  |  
|Repayment of long-term debt                                                                             |  |                          | (136,000 | ) |      |   | (59,500  | )    |  |   | (60,500  | )
|Net proceeds from issuance of common stock                                                              |  |                          | 29,824   |   |      |   | 32,451   |      |  |   | 78,937   |  
|Common stock dividends                                                                                  |  |                          | (75,119  | ) |      |   | (73,412  | )    |  |   | (67,015  | )
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Net cash provided by (used in) financing activities                                                     |  |                          | (77,846  | ) |      |   | (95,853  | )    |  |   | 54,097   |  
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Net cash provided by (used in) discontinued operations                                                  |  |                          | (3,364   | ) |      |   | (709     | )    |  |   | 47,585   |  
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Net increase (decrease) in cash and equivalents                                                         |  |                          | (13,050  | ) |      |   | 5,904    |      |  |   | 18,478   |  
|Cash and equivalents, January 1                                                                         |  |                          | 25,059   |   |      |   | 19,155   |      |  |   | 677      |  
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  
|Cash and equivalents, December 31                                                                       |  | $                        | 12,009   |   |      | $ | 25,059   |      |  | $ | 19,155   |  
|                                                                                                        |  |                          |          |   |      |   |          |      |  |   |          |  



Supplemental disclosures of noncash
activities:



In 2003, 2002 and 2001, $0.9 million, $0.8 million
and $0.8 million, respectively, of HEI advances to HEIDI were converted to equity in noncash transactions.



Under the HEI Dividend Reinvestment and Stock Purchase Plan, common stock dividends reinvested by shareholders in HEI common stock in noncash transactions
amounted to $17 million in 2003, $17 million in 2002 and $16 million in 2001.



85



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##### Table of Contents

Hawaiian Electric Industries, Inc.

and Hawaiian Electric Company, Inc.

SCHEDULE II  VALUATION AND QUALIFYING
ACCOUNTS

Years ended December 31, 2003, 2002 and 2001



|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|------------------------------------------------------------------------------------- |  | ----------------------------- | ------ | --------------------------- | - | ----------------------- | ------ | - | ---------- | ------ |  | ---------------------- | ----- | --- |  | - | ------
|Col. A                                                                                |  | Col. B                        |        | Col. C                      |   |                         | Col. D |   |            | Col. E
|(in thousands)                                                                        |  |                               |        | Additions                   |   |                         |        |   |            |       
|Description                                                                           |  | Balanceat begin-ning ofperiod |        | Charged tocosts andexpenses |   | Chargedto otheraccounts |        |   | Deductions |        |  | Balance atend ofperiod
|2003                                                                                  |  |                               |        |                             |   |                         |        |   |            |        |  |                       
|Allowance for uncollectible accountsHawaiian Electric Company, Inc. and subsidiaries |  | $                             | 998    |                             | $ | 1,721                   |        | $ | 803        | (a)    |  | $                      | 2,615 | (b) |  | $ | 907   
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|Allowance for uncollectible interest (ASB)                                            |  | $                             | 730    |                             |   |                        |        |   |           |        |  | $                      | 575   |     |  | $ | 155   
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|Allowance for losses for loans receivable (ASB)                                       |  | $                             | 45,435 |                             | $ | 3,075                   |        | $ | 2,469      | (a)    |  | $                      | 6,694 | (b) |  | $ | 44,285
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|                                                                                      |  |                               |        |                             |  
|2002                                                                                  |  |                               |        |                             |   |                         |        |   |            |        |  |                       
|Allowance for uncollectible accountsHawaiian Electric Company, Inc. and subsidiaries |  | $                             | 1,260  |                             | $ | 1,444                   |        | $ | 1,286      | (a)    |  | $                      | 2,992 | (b) |  | $ | 998   
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|Allowance for uncollectible interest (ASB)                                            |  | $                             | 2,710  |                             |   |                        |        |   |           |        |  | $                      | 1,980 |     |  | $ | 730   
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|Allowance for losses for loans receivable (ASB)                                       |  | $                             | 42,224 |                             | $ | 9,750                   |        | $ | 1,205      | (a)    |  | $                      | 7,744 | (b) |  | $ | 45,435
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|                                                                                      |  |                               |        |                             |  
|2001                                                                                  |  |                               |        |                             |   |                         |        |   |            |        |  |                       
|Allowance for uncollectible accountsHawaiian Electric Company, Inc. and subsidiaries |  | $                             | 939    |                             | $ | 1,930                   |        | $ | 1,246      | (a)    |  | $                      | 2,855 | (b) |  | $ | 1,260 
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|Allowance for uncollectible interest (ASB)                                            |  | $                             | 2,978  |                             |   |                        |        |   |           |        |  | $                      | 268   |     |  | $ | 2,710 
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       
|Allowance for losses for loans receivable (ASB)                                       |  | $                             | 37,449 |                             | $ | 12,500                  |        | $ | 1,898      | (a)    |  | $                      | 9,623 | (b) |  | $ | 42,224
|                                                                                      |  |                               |        |                             |   |                         |        |   |            |        |  |                        |       |     |  |   |       



|(a) | Primarily bad debts recovered.
|--- | ------------------------------



|(b) | Bad debts charged off.
|--- | ----------------------



86



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INDEX TO EXHIBITS



The exhibits designated by an
asterisk (*) are filed herein. The exhibits not so designated are incorporated by reference to the indicated filing. A copy of any exhibit may be obtained upon written request for a $0.20 per page charge from the HEI Shareholder Services Division,
P.O. Box 730, Honolulu, Hawaii 96808-0730.



|            |  |                                                                                                                                                                                                                                                                                                        
|----------- |  | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                            
|HEI:        |  |                                                                                                                                                                                                                                                                                                        
|            | 
|3(i).1      |  | HEIs Restated Articles of Incorporation (Exhibit 4(b) to Registration No. 33-7895).                                                                                                                                                                                                                   
|            | 
|3(i).2      |  | Articles of Amendment of HEI, amending HEIs Restated Articles of Incorporation (Exhibit 4(b) to Registration No. 33-40813).                                                                                                                                                                           
|            | 
|3(i).3      |  | Statement of Issuance of Shares of Preferred or Special Classes in Series for HEI Series A Junior Participating Preferred Stock (Exhibit 3(i).3 to HEIs Annual Report on Form 10-K for
the fiscal year ended December 31, 1997, File No. 1-8503).                                                     
|            | 
|3(ii)       |  | HEIs Amended and Restated By-Laws. (Exhibit 3(ii) to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 2001, File No. 1-8503).                                                                                                                                                  
|            | 
|4.1         |  | Agreement to provide the SEC with instruments which define the rights of holders of certain long-term debt of HEI and its subsidiaries (Exhibit 4.1 to HEIs Annual Report on Form 10-K
for the fiscal year ended December 31, 1992, File No. 1-8503).                                                 
|            | 
|4.2(a)      |  | Rights Agreement, dated as of October 28, 1997, between HEI and Continental Stock Transfer & Trust Company, as Rights Agent, which includes as Exhibit B thereto the Form of Rights
Certificates (Exhibit 1 to HEIs Form 8-A, dated October 28, 1997, File No. 1-8503).                               
|            | 
|4.2(b)      |  | First Amendment, dated as of May 7, 2003, to Rights Agreement (dated as of October 28, 1997) between HEI and Continental Stock Transfer & Trust Company, as Rights Agent (Exhibit 4.1 to
HEIs Quarterly Report on Form 10-Q for the quarter ended March 31, 2003, File No. 1-8503).                   
|            | 
|4.3         |  | Indenture, dated as of October 15, 1988, between HEI and Citibank, N.A., as Trustee (Exhibit 4 to Registration No. 33-25216).                                                                                                                                                                          
|            | 
|4.4(a)      |  | First Supplemental Indenture dated as of June 1, 1993 between HEI and Citibank, N.A., as Trustee, to Indenture dated as of October 15, 1988 between HEI and Citibank, N.A., as Trustee (Exhibit
4(a) to HEIs Quarterly Report on Form 10-Q for the quarter ended September 30, 1993, File No. 1-8503).
|            | 
|4.4(b)      |  | Second Supplemental Indenture dated as of April 1, 1999 between HEI and Citibank, N.A., as Trustee, to Indenture dated as of October 15, 1988 between HEI and Citibank, N.A., as Trustee
(Exhibit 4.1 to HEIs Quarterly Report on Form 10-Q for the quarter ended March 31, 1999, File No. 1-8503).   
|            | 
|4.4(c)      |  | Third Supplemental Indenture dated as of August 1, 2002 between HEI and Citibank, N.A., as Trustee, to Indenture dated as of October 15, 1988 between HEI and Citibank, N.A., as Trustee
(Exhibit 4 to HEIs Current Report on Form 8-K dated August 16, 2002, File No. 1-8503).                       



87



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##### Table of Contents

|            |  |                                                                                                                                                                                                                                                                                                         
|----------- |  | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                             
|            | 
|4.5(a)      |  | Pricing Supplement No. 11 to Registration Statement on Form S-3 of HEI (Registration No. 33-58820) filed on December 1, 1995 in connection with the sale of Medium-Term Notes, Series B
(Exhibit 4.8 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1995, File No. 1-8503). 
|            | 
|4.5(b)      |  | Pricing Supplement No. 12 to Registration Statement on Form S-3 of HEI (Registration No. 33-58820) filed on February 12, 1996 in connection with the sale of Medium-Term Notes, Series B
(Exhibit 4.9 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1995, File No. 1-8503).
|            | 
|4.5(c)      |  | Pricing Supplements Nos. 13 through 14 to Registration Statement on Form S-3 of HEI (Registration No. 33-58820) filed on September 26, 1997 in connection with the sale of Medium-Term Notes,
Series B.                                                                                                 
|            | 
|4.5(d)      |  | Pricing Supplement No. 15 to Registration Statement on Form S-3 of HEI (Registration No. 33-58820) filed on September 29, 1997 in connection with the sale of Medium-Term Notes, Series
B.                                                                                                              
|            | 
|4.5(e)      |  | Pricing Supplement No. 16 to Registration Statement on Form S-3 of HEI (Registration No. 33-58820) filed on September 30, 1997 in connection with the sale of Medium-Term Notes, Series
B.                                                                                                              
|            | 
|4.5(f)      |  | Pricing Supplement No. 17 to Registration Statement on Form S-3 of HEI (Registration No. 33-58820) filed on October 2, 1997 in connection with the sale of Medium-Term Notes, Series
B.                                                                                                                 
|            | 
|4.5(g)      |  | Pricing Supplement No. 24 to Registration Statement on Form S-3 of HEI (Registration No. 33-58820) filed on June 10, 1998 in connection with the sale of Medium-Term Notes, Series
B.                                                                                                                   
|            | 
|4.5(h)      |  | Pricing Supplement No. 1 to Registration Statement on Form S-3 of HEI (Registration No. 333-73225) filed on May 3, 1999 in connection with the sale of Medium-Term Notes, Series
C.                                                                                                                     
|            | 
|4.5(i)      |  | Pricing Supplement No. 3 to Registration Statement on Form S-3 of HEI (Registration No. 333-73225) filed on April 5, 2001 in connection with the sale of Medium-Term Notes, Series
C.                                                                                                                   
|            | 
|4.5(j)      |  | Pricing Supplement No. 1 to Registration Statement on Form S-3 of HEI (Registration No. 333-87782) filed on March 5, 2003 in connection with the sale of Medium-Term Notes, Series
D.                                                                                                                   
|            | 
|4.5(k)      |  | Pricing Supplement No. 2 to Registration Statement on Form S-3 of HEI (Registration No. 333-87782) filed on March 5, 2003 in connection with the sale of Medium-Term Notes, Series
D.                                                                                                                   
|            | 
|4.6         |  | Amended and Restated Agreement of Limited Partnership of HEI Preferred Funding, LP dated as of February 1, 1997 (Exhibit 4(e) to HEIs Current Report on Form 8-K dated February 4, 1997,
File No. 1-8503).                                                                                             
|            | 
|4.7         |  | Amended and Restated Trust Agreement of Hawaiian Electric Industries Capital Trust I (HEI Trust I) dated as of February 1, 1997 (Exhibit 4(f) to HEIs Current Report on Form 8-K dated
February 4, 1997, File No. 1-8503).                                                                             



88



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|            |  |                                                                                                                                                                                                                                                                                     
|----------- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                         
|            | 
|4.8         |  | Junior Indenture between HEI and The Bank of New York, as Trustee, dated as of February 1, 1997 (Exhibit 4(i) to HEIs Current Report on Form 8-K dated February 4, 1997, File No.
1-8503).                                                                                         
|            | 
|4.9         |  | Officers Certificate in connection with issuance of 8.36% Junior Subordinated Debenture, Series A, Due 2017 under Junior Indenture of HEI (Exhibit 4(l) to HEIs Current Report on
Form 8-K dated February 4, 1997, File No. 1-8503).                                              
|            | 
|4.10        |  | 8.36% Trust Originated Preferred Security (Liquidation Amount $25 Per Trust Preferred Security) of HEI Trust I (Exhibit 4(m) to HEIs Current Report on Form 8-K dated February 4, 1997,
File No. 1-8503).                                                                          
|            | 
|4.11        |  | 8.36% Junior Subordinated Debenture Series A, Due 2017, of HEI (Exhibit 4(n) to HEIs Current Report on Form 8-K dated February 4, 1997, File No. 1-8503).                                                                                                                          
|            | 
|4.12        |  | Trust Preferred Securities Guarantee Agreement with respect to HEI Trust I dated as of February 1, 1997 (Exhibit 4(o) to HEIs Current Report on Form 8-K dated February 4, 1997, File No.
1-8503).                                                                                 
|            | 
|4.13        |  | Partnership Guarantee Agreement with respect to the Partnership dated as of February 1, 1997 (Exhibit 4(p) to HEIs Current Report on Form 8-K dated February 4, 1997, File No.
1-8503).                                                                                            
|            | 
|4.14        |  | Affiliate Investment Instruments Guarantee Agreement with respect to 8.36% Junior Subordinated Debenture of HEIDI dated as of February 1, 1997 (Exhibit 4(q) to HEIs Current Report on
Form 8-K dated February 4, 1997, File No. 1-8503).                                          
|            | 
|4.15        |  | Certificate Evidencing Trust Common Securities of HEI Trust I dated February 4, 1997 (Exhibit 4.12 to the Quarterly Report on Form 10-Q of HEI Trust I and the Partnership, File No. 1-8503-02,
for the quarter ended March 31, 1997).                                              
|            | 
|4.16        |  | Certificate Evidencing Partnership Preferred Securities of the Partnership dated February 4, 1997 (Exhibit 4.13 to the Quarterly Report on Form 10-Q of HEI Trust I and the Partnership, File
No. 1-8503-02, for the quarter ended March 31, 1997).                                 
|            | 
|10.1        |  | PUC Order Nos. 7070, 7153, 7203 and 7256 in Docket No. 4337, including copy of Conditions for the Merger and Corporate Restructuring of Hawaiian Electric Company, Inc. dated
September 23, 1982 (Exhibit 10 to Amendment No. 1 to Form U-1).                                     
|            | 
|10.2        |  | Regulatory Capital Maintenance/Dividend Agreement dated May 26, 1988, between HEI, HEIDI and the Federal Savings and Loan Insurance Corporation (by the Federal Home Loan Bank of Seattle)
(Exhibit (28)-2 to HEIs Current Report on Form 8-K dated May 26, 1988, File No. 1-8503).
|            | 
|10.3        |  | OTS letter regarding release from Part II.B. of the Regulatory Capital Maintenance/Dividend Agreement dated May 26, 1988 (Exhibit 10.3(a) to HEIs Annual Report on Form 10-K for the
fiscal year ended December 31, 1992, File No. 1-8503).                                        
|            | 
|10.4        |  | Executive Incentive Compensation Plan (Exhibit 4.1 to HEIs Quarterly Report on Form 10-Q for the quarter ended March 31, 2003, File No. 1-8503)..                                                                                                                                  
|            | 
|10.5        |  | HEI Executives Deferred Compensation Plan (Exhibit 10.5 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1990, File No. 1-8503).                                                                                                                         



89



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|            |  |                                                                                                                                                                                                                                                                                                                                                                                     
|----------- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                                                                                                         
|            | 
|10.6        |  | 1987 Stock Option and Incentive Plan of HEI as amended and restated effective January 21, 2003 (Exhibit 10.2 to HEIs Quarterly Report on Form 10-Q for the quarter ended March 31, 2003,
File No. 1-8503).                                                                                                                                                                         
|            | 
|10.7        |  | HEI Long-Term Incentive Plan (Exhibit 10.7 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 2002, File No. 1-8503)..                                                                                                                                                                                                                                      
|            | 
|10.8(a)     |  | HEI Supplemental Executive Retirement Plan effective as of January 1, 1989 (Exhibit 10.8(a) to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 2002, File No.
1-8503).                                                                                                                                                                                      
|            | 
|10.8(b)     |  | HEI Excess Pay Supplemental Executive Retirement Plan (Exhibit 10.8(b) to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 2002, File No. 1-8503).                                                                                                                                                                                                           
|            | 
|10.9        |  | HEI Excess Benefit Plan effective as of January 1, 1994 (Exhibit 10.9 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 2002, File No. 1-8503).                                                                                                                                                                                                            
|            | 
|10.10       |  | Form of Change-in-Control Agreement (Exhibit 10.14 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1989, File No. 1-8503).                                                                                                                                                                                                                               
|            | 
|10.11       |  | Nonemployee Director Retirement Plan, effective as of October 1, 1989 (Exhibit 10.15 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1989, File No.
1-8503).                                                                                                                                                                                             
|            | 
|10.12       |  | HEI 1990 Nonemployee Director Stock Plan, As Amended and Restated (Exhibit 10.12 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 2002, File No.
1-8503).                                                                                                                                                                                                 
|            | 
|10.13       |  | HEI Nonemployee Directors Deferred Compensation Plan (Exhibit 10.14 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1990, File No.
1-8503).                                                                                                                                                                                                             
|            | 
|10.14       |  | Form of HEI and HECO Executives Deferred Compensation Agreement. The agreement pertains to and is substantially identical for all the HEI and HECO executive officers (Exhibit 10.15 to
HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1991, File No. 1-8503).                                                                                            
|            | 
|10.15       |  | Employment Separation Agreement by and between Robert F. Mougeot and HEI, and its subsidiary and affiliated entities and the shareholders, directors, officers, employees and agents of HEI and
its subsidiary and affiliated entities effective November 24, 2002 (Exhibit 10.15 to HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 2002, File No. 1-8503).
|            | 
|10.16       |  | HEI Executive Death Benefit Plan of HEI and Participating Subsidiaries effective September 1, 2001 (Exhibit 10.16 to HEIs Annual Report on Form 10-K for the fiscal year ended December
31, 2002, File No. 1-8503).                                                                                                                                                                
|            | 
|*11         |  | Computation of Earnings per Share of Common Stock. Filed herein as page 98.                                                                                                                                                                                                                                                                                                         
|            | 
|*12         |  | Computation of Ratio of Earnings to Fixed Charges. Filed herein as pages 99 and 100.                                                                                                                                                                                                                                                                                                



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|            |  |                                                                                                                                                                                                                                                   
|----------- |  | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                       
|            | 
|13          |  | HEIs 2003 Annual Report to Shareholders (HEI Exhibit 13 to HEIs Current Report on Form 8-K dated February 26, 2004, File No. 1-8503).                                                                                                           
|            | 
|18          |  | KPMG LLP letter re: change in accounting principle (Exhibit 18.1 to HEIs Quarterly Report on Form 10-Q for the quarter ended March 31, 2000, File No. 1-8503).                                                                                   
|            | 
|*21         |  | Subsidiaries of HEI. Filed herein as page 101.                                                                                                                                                                                                    
|            | 
|*23.1       |  | Accountants Consent. Filed herein as page 102.                                                                                                                                                                                                   
|            | 
|*31.1       |  | Certification Pursuant to 13a-14 of the Securities and Exchange Act of 1934, as Adopted by Section 302 of the Sarbanes-Oxley Act of 2002 of Robert F. Clarke (HEI Chief Executive Officer).
Filed herein as page 104.                             
|            | 
|*31.2       |  | Certification Pursuant to 13a-14 of the Securities and Exchange Act of 1934, as Adopted by Section 302 of the Sarbanes-Oxley Act of 2002 of Eric K. Yeaman (HEI Chief Financial Officer). Filed
herein as page 105.                               
|            | 
|*32.1       |  | Written Statement Furnished Pursuant to 18 U.S.C. Section 1350, as Adopted by Section 906 of the Sarbanes-Oxley Act of 2002 of Robert F. Clarke, HEI Chief Executive Officer. Filed herein as
page 106.                                           
|            | 
|*32.2       |  | Written Statement Furnished Pursuant to 18 U.S.C. Section 1350, as Adopted by Section 906 of the Sarbanes-Oxley Act of 2002 of Eric K. Yeaman, HEI Chief Financial Officer. Filed herein as
page 107.                                             
|            | 
|*99.1       |  | Amendment 2003-2 to the Hawaiian Electric Industries Retirement Savings Plan for incorporation by reference in the Registration Statement on Form S-8 (Regis. No. 333-02103).                                                                     
|            | 
|*99.2       |  | Ninth Amendment to Trust Agreement between HEI and Fidelity Management Trust Company made and entered into February 2, 2004.                                                                                                                      
|HECO:       |  |                                                                                                                                                                                                                                                   
|            | 
|3(i).1      |  | HECOs Certificate of Amendment of Articles of Incorporation (Exhibit 3.1 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1988, File No.
1-4955).                                                                     
|            | 
|3(i).2      |  | Articles of Amendment to HECOs Amended Articles of Incorporation (Exhibit 3.1(b) to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1989, File No
1-4955).                                                              
|            | 
|3(i).3      |  | Articles of Amendment to HECOs Amended Articles of Incorporation (Exhibit 3(i).4 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1998, File No
1-4955).                                                              
|            | 
|3(ii)       |  | HECOs By-Laws (Exhibit 3.2 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1988, File No. 1-4955).                                                                                                                   
|            | 
|4.1         |  | Agreement to provide the SEC with instruments which define the rights of holders of certain long-term debt of HECO, HELCO and MECO (Exhibit 4.1 to HEIs Annual Report on Form 10-K for
the fiscal year ended December 31, 2002, File No. 1-4955).
|            | 
|4.2         |  | Amended and Restated Trust Agreement of HECO Capital Trust I (HECO Trust I) dated as of March 1, 1997 (Exhibit 4(c) to HECOs Current Report on Form 8-K dated March 27, 1997, File No.
1-4955).                                                  



91



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|            |  |                                                                                                                                                                                                                                                                                                                                                
|----------- |  | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                                                                    
|            | 
|4.3         |  | HECO Junior Indenture with The Bank of New York, as Trustee, dated as of March 1, 1997 (Exhibit 4(d) to HECOs Current Report on Form 8-K dated March 27, 1997, File No.
1-4955).                                                                                                                                                              
|            | 
|4.4         |  | 8.05% Cumulative Quarterly Income Preferred Security (liquidation preference $25 per preferred security) of HECO Trust I (Exhibit 4(e) to HECOs Current Report on Form 8-K dated March
27, 1997, File No. 1-4955).                                                                                                                            
|            | 
|4.5         |  | 8.05% Junior Subordinated Deferrable Interest Debenture, Series 1997 of HECO (Exhibit 4(f) to HECOs Current Report on Form 8-K dated March 27, 1997, File No. 1-4955).                                                                                                                                                                        
|            | 
|4.6         |  | Trust Guarantee Agreement with respect to HECO Trust I dated as of March 1, 1997 (Exhibit 4(g) to HECOs Current Report on Form 8-K dated March 27, 1997, File No.
1-4955).                                                                                                                                                                    
|            | 
|4.7         |  | MECO Junior Indenture with The Bank of New York, as Trustee, including HECO Subsidiary Guarantee, dated as of March 1, 1997 (with the form of MECOs 8.05% Junior Subordinated Deferrable
Interest Debenture, Series 1997 included as Exhibit A) (Exhibit 4(h)-1 to HECOs Current Report on Form 8-K dated March 27, 1997, File No. 1-4955).  
|            | 
|4.8         |  | HELCO Junior Indenture with The Bank of New York, as Trustee, including HECO Subsidiary Guarantee, dated as of March 1, 1997 (with the form of HELCOs 8.05% Junior Subordinated
Deferrable Interest Debenture, Series 1997 included as Exhibit A) (Exhibit 4(h)-2 to HECOs Current Report on Form 8-K dated March 27, 1997, File No. 1-4955).
|            | 
|4.9         |  | Agreement as to Expenses and Liabilities among HECO Trust I, HECO, MECO and HELCO (Exhibit 4(i) to HECOs Current Report on Form 8-K dated March 27, 1997, File No.
1-4955).                                                                                                                                                                   
|            | 
|4.10        |  | Amended and Restated Trust Agreement of HECO Capital Trust II (HECO Trust II) dated as of December 1, 1998 (Exhibit 4(c) to HECOs Current Report on Form 8-K dated December 4, 1998, File
No. 1-4955).                                                                                                                                        
|            | 
|4.11        |  | HECO Junior Indenture with The Bank of New York, as Trustee, dated as of December 1, 1998 (with the form of HECOs 7.30% Junior Subordinated Deferrable Interest Debenture, Series 1998,
included as Exhibit A) (Exhibit 4(d) to HECOs Current Report on Form 8-K dated December 4, 1998, File No. 1-4955).                                   
|            | 
|4.12        |  | 7.30% Cumulative Quarterly Income Preferred Security (liquidation preference $25 per preferred security) of HECO Trust II (Exhibit 4(e) to HECOs Current Report on Form 8-K dated
December 4, 1998, File No. 1-4955).                                                                                                                         
|            | 
|4.13        |  | Trust Guarantee Agreement with respect to HECO Trust II dated as of December 1, 1998 (Exhibit 4(g) to HECOs Current Report on Form 8-K dated December 4, 1998, File No.
1-4955).                                                                                                                                                              



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|            |  |                                                                                                                                                                                                                                                                                                                                                 
|----------- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                                                                     
|            | 
|4.14        |  | MECO Junior Indenture with The Bank of New York, as Trustee, including HECO Subsidiary Guarantee, dated as of December 1, 1998 (with the form of MECOs 7.30% Junior Subordinated
Deferrable Interest Debenture, Series 1998 included as Exhibit A) (Exhibit 4(h) to HECOs Current Report on Form 8-K dated December 4, 1998, File No. 1-4955).
|            | 
|4.15        |  | HELCO Junior Indenture with The Bank of New York, as Trustee, including HECO Subsidiary Guarantee, dated as of December 1, 1998 (with the form of HELCOs 7.30% Junior Subordinated
Deferrable Interest Debenture, Series 1998) (Substantially the same as the MECO Junior Indenture included as Exhibit 4.14).                                 
|            | 
|4.16        |  | Agreement as to Expenses and Liabilities among HECO Trust II, HECO, MECO and HELCO (Exhibit 4(i) to HECOs Current Report on Form 8-K dated December 4, 1998, File No.
1-4955).                                                                                                                                                                 
|            | 
|10.1(a)     |  | Power Purchase Agreement between Kalaeloa Partners, L.P., and HECO dated October 14, 1988 (Exhibit 10(a) to HECOs Quarterly Report on Form 10-Q for the quarter ended September 30, 1988,
File No. 1-4955).                                                                                                                                    
|            | 
|10.1(b)     |  | Amendment No. 1 to Power Purchase Agreement between HECO and Kalaeloa Partners, L.P., dated June 15, 1989 (Exhibit 10(c) to HECOs Quarterly Report on Form 10-Q for the quarter ended
June 30, 1989, File No. 1-4955).                                                                                                                         
|            | 
|10.1(c)     |  | Lease Agreement between Kalaeloa Partners, L.P., as Lessor, and HECO, as Lessee, dated February 27, 1989 (Exhibit 10(d) to HECOs Quarterly Report on Form 10-Q for the quarter ended June
30, 1989, File No. 1-4955).                                                                                                                          
|            | 
|10.1(d)     |  | Restated and Amended Amendment No. 2 to Power Purchase Agreement between HECO and Kalaeloa Partners, L.P., dated February 9, 1990 (Exhibit 10.2(c) to HECOs Annual Report on Form 10-K
for the fiscal year ended December 31, 1989, File No. 1-4955).                                                                                          
|            | 
|10.1(e)     |  | Amendment No. 3 to Power Purchase Agreement between HECO and Kalaeloa Partners, L.P., dated December 10, 1991 (Exhibit 10.2(e) to HECOs Annual Report on Form 10-K for the fiscal year
ended December 31, 1991, File No. 1-4955).                                                                                                              
|            | 
|10.1(f)     |  | Amendment No. 4 to Power Purchase Agreement between HECO and Kalaeloa Partners, L.P., dated October 1, 1999 (Exhibit 10.1 to HECOs Quarterly Report on Form 10-Q for the quarter ended
September 30, 2000, File No. 1-4955).                                                                                                                   
|            | 
|10.2(a)     |  | Power Purchase Agreement between AES Barbers Point, Inc. and HECO, entered into on March 25, 1988 (Exhibit 10(a) to HECOs Quarterly Report on Form 10-Q for the quarter ended March 31,
1988, File No. 1-4955).                                                                                                                                
|            | 
|10.2(b)     |  | Agreement between HECO and AES Barbers Point, Inc., pursuant to letters dated May 10, 1988 and April 20, 1988 (Exhibit 10.4 to HECOs Annual Report on Form 10-K for fiscal year ended
December 31, 1988, File No. 1-4955).                                                                                                                     
|            | 
|10.2(c)     |  | Amendment No. 1, entered into as of August 28, 1988, to Power Purchase Agreement between AES Barbers Point, Inc. and HECO (Exhibit 10 to HECOs Quarterly Report on Form 10-Q for the
quarter ended September 30, 1989, File No. 1-4955).                                                                                                       



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|            |  |                                                                                                                                                                                                                                                                                                                                                                                                     
|----------- |  | ----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                                                                                                                         
|            | 
|10.2(d)     |  | HECOs Conditional Notice of Acceptance to AES Barbers Point, Inc. dated January 15, 1990 (Exhibit 10.3(c) to HECOs Annual Report on Form 10-K for the fiscal year ended December
31, 1989, File No. 1-4955).                                                                                                                                                                                      
|            | 
|*10.2(e)    |  | Amendment No. 2, entered into as of May 8, 2003, to Power Purchase Agreement between AES Hawaii, Inc. and HECO.                                                                                                                                                                                                                                                                                     
|            | 
|10.3(a)     |  | Amended and Restated Power Purchase Agreement between Hilo Coast Processing Company and HELCO dated March 24, 1995 (Exhibit 10 to HECOs Quarterly Report on Form 10-Q for the quarter
ended March 31, 1995, File No. 1-4955).                                                                                                                                                                      
|            | 
|10.3(b)     |  | Second Amended and Restated Power Purchase Agreement between Hilo Coast Power Company and HELCO dated October 4, 1999 (Exhibit 10 to HECOs Quarterly Report on Form 10-Q for the quarter
ended September 30, 1999, File No. 1-4955).                                                                                                                                                               
|            | 
|10.3(c)     |  | Amendment No. 1 to the Second Amended and Restated Power Purchase Agreement between Hilo Coast Power Company and HELCO dated November 5, 1999 (Exhibit 10.3(b) to HECOs Annual Report on
Form 10-K for fiscal year ended December 31, 2001, File No. 1-4955).                                                                                                                                      
|            | 
|10.4(a)     |  | Agreement between MECO and Hawaiian Commercial & Sugar Company pursuant to letters dated November 29, 1988 and November 1, 1988 (Exhibit 10.8 to HECOs Annual Report on Form 10-K for
the fiscal year ended December 31, 1988, File No. 1-4955).                                                                                                                                                   
|            | 
|10.4(b)     |  | Amended and Restated Power Purchase Agreement by and between A&B-Hawaii, Inc., through its division, Hawaiian Commercial & Sugar Company, and MECO, dated November 30, 1989 (Exhibit
10(e) to HECOs Quarterly Report on Form 10-Q for the quarter ended September 30, 1990, File No. 1-4955).                                                                                                      
|            | 
|10.4(c)     |  | First Amendment to Amended and Restated Power Purchase Agreement by and between A&B-Hawaii, Inc., through its division, Hawaiian Commercial & Sugar Company, and MECO, dated November
1, 1990, amending the Amended and Restated Power Purchase Agreement dated November 30, 1989 (Exhibit 10(f) to HECOs Quarterly Report on Form 10-Q for the quarter ended September 30, 1990, File No. 1-4955).
|            | 
|10.4(d)     |  | Letter agreement dated December 11, 1997 to Extend Term of Amended and Restated Power Purchase Agreement Between A&B-Hawaii, Inc., through its division, Hawaiian Commercial & Sugar
Company, and MECO dated November 30, 1989, as Amended on November 1, 1990 (Exhibit 10.4(c) to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).                 
|            | 
|10.4(e)     |  | Letter agreement dated October 22, 1998 to Extend Term of Amended and Restated Power Purchase Agreement Between A&B-Hawaii, Inc., through its division, Hawaiian Commercial & Sugar
Company, and MECO dated November 30, 1989, as Amended on November 1, 1990 (Exhibit 10.4(d) to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1998, File No. 1-4955).                  



94



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|            |  |                                                                                                                                                                                                                                                                                                                                                                         
|----------- |  | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                                                                                             
|            | 
|10.4(f)     |  | Termination Notice dated December 27, 1999 for Amended and Restated Power Purchase Agreement by and between A&B Hawaii, Inc., through its division, Hawaiian Commercial & Sugar
Company, and MECO, dated November 30, 1989, as amended (Exhibit 10.2 to HECOs Quarterly Report on Form 10-Q for the quarter ended September 30, 2000, File No. 1-4955).                
|            | 
|10.4(g)     |  | Rescission dated January 23, 2001 of Termination Notice for Amended and Restated Power Purchase Agreement by and between A&B Hawaii, Inc., through its division, Hawaiian Commercial &
Sugar Company, and MECO, dated November 30, 1989, as amended (Exhibit 10.4(f) to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 2000, File No. 1-4955).
|            | 
|10.5(a)     |  | Purchase Power Contract between HELCO and Thermal Power Company dated March 24, 1986 (Exhibit 10(a) to HECOs Quarterly Report on Form 10-Q for the quarter ended June 30, 1989, File No.
1-4955).                                                                                                                                                                      
|            | 
|10.5(b)     |  | Firm Capacity Amendment between HELCO and Puna Geothermal Venture (assignee of AMOR VIII, who is the assignee of Thermal Power Company) dated July 28, 1989 to Purchase Power Contract between
HELCO and Thermal Power Company dated March 24, 1986 (Exhibit 10(b) to HECOs Quarterly Report on Form 10-Q for the quarter ended June 30, 1989, File No. 1-4955).       
|            | 
|10.5(c)     |  | Amendment made in October 1993 to Purchase Power Contract between HELCO and Puna Geothermal Venture dated March 24, 1986, as amended (Exhibit 10.5(b) to HECOs Annual Report on Form 10-K
for the fiscal year ended December 31, 1997, File No. 1-4955).                                                                                                               
|            | 
|10.5(d)     |  | Third Amendment dated March 7, 1995 to the Purchase Power Contract between HELCO and Puna Geothermal Venture dated March 24, 1986, as amended (Exhibit 10.5(c) to HECOs Annual Report on
Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).                                                                                                      
|            | 
|10.5(e)     |  | Performance Agreement and Fourth Amendment dated February 12, 1996 to the Purchase Power Contract between HELCO and Puna Geothermal Venture dated March 24, 1986, as amended (Exhibit 10.5(b)
to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1995, File No. 1-4955).                                                                       
|            | 
|10.6(a)     |  | Purchase Power Contract between HECO and the City and County of Honolulu dated March 10, 1986 (Exhibit 10.9 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31,
1989, File No. 1-4955).                                                                                                                                                         
|            | 
|10.6(b)     |  | Amendment No. 1 to Purchase Power Contract between HECO and the City and County of Honolulu dated March 10, 1986 (Exhibit 10.6 (a) to HECOs Annual Report on Form 10-K for fiscal year
ended December 31, 2001, File No. 1-4955).                                                                                                                                      
|            | 
|10.6(c)     |  | Firm Capacity Amendment, dated April 8, 1991, to Purchase Power Contract, dated March 10, 1986, by and between HECO and the City & County of Honolulu (Exhibit 10 to HECOs Quarterly
Report on Form 10-Q for the quarter ended March 31, 1991, File No. 1-4955).                                                                                                       
|            | 
|10.6(d)     |  | Amendment No. 2 to Purchase Power Contract Between HECO and City and County of Honolulu dated March 10, 1986 (Exhibit 10.6(c) to HECOs Annual Report on Form 10-K for the fiscal year
ended December 31, 1997, File No. 1-4955).                                                                                                                                       



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|            |  |                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                    
|----------- |  | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                                        
|            | 
|10.7(a)     |  | Power Purchase Agreement between Encogen Hawaii, L.P. and HELCO dated October 22, 1997 (but with the following attachments omitted: Attachment C, Selected portions of the North American
Electric Reliability Council Generating Availability Data System Data Reporting Instructions dated October 1996 and Attachment E, Form of the Interconnection Agreement between Encogen Hawaii, L.P. and HELCO, which is provided in
final form as Exhibit 10.7(a)) (Exhibit 10.7 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).
|            | 
|10.7(b)     |  | Power Purchase Agreement between Encogen Hawaii, L.P. and HELCO dated October 22, 1997 (Exhibit 10.7(a) to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997,
File No. 1-4955).                                                                                                                                                                                                                                                                                                                                                                        
|            | 
|10.7(c)     |  | Amendment No. 1, executed on January 14, 1999, to Power Purchase Agreement between Encogen Hawaii, L.P. and HELCO dated October 22, 1997 (Exhibit 10.7(b) to HECOs Annual Report on Form
10-K for the fiscal year ended December 31, 1998, File No. 1-4955).                                                                                                                                                                                                                                                                                                                      
|            | 
|10.7(d)     |  | Power Purchase Agreement Novation dated November 8, 1999 by and among Encogen Hawaii, L.P., Hamakua Energy Partners and HELCO (Exhibit 10.7(c) to HECOs Annual Report on Form 10-K for
fiscal year ended December 31, 2001, File No. 1-4955).                                                                                                                                                                                                                                                                                                                                     
|            | 
|10.7(e)     |  | Guarantee Agreement dated November 8, 1999 between TECO Energy, Inc. and HELCO (Exhibit 10.7(d) to HECOs Annual Report on Form 10-K for fiscal year ended December 31, 2001, File No.
1-4955).                                                                                                                                                                                                                                                                                                                                                                                    
|            | 
|10.8        |  | Low Sulfur Fuel Oil Supply Contract by and between Chevron and HECO dated as of November 14, 1997 (confidential treatment has been requested for portions of this exhibit) (Exhibit 10.8 to
HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).                                                                                                                                                                                                                                                                                       
|            | 
|10.9        |  | Inter-Island Industrial Fuel Oil and Diesel Fuel Supply Contract by and between Chevron and HECO, MECO, HELCO, HTB and YB dated as of November 14, 1997 (confidential treatment has been
requested for portions of this exhibit) (Exhibit 10.9 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).                                                                                                                                                                                                                                 
|            | 
|10.10       |  | Facilities and Operating Contract by and between Chevron and HECO dated as of November 14, 1997 (confidential treatment has been requested for portions of this exhibit) (Exhibit 10.10 to
HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).                                                                                                                                                                                                                                                                                        
|            | 
|10.11       |  | Low Sulfur Fuel Oil Supply Contract by and between BHP Petroleum Americas Refining Inc. and HECO dated as of November 14, 1997 (confidential treatment has been requested for portions of this
exhibit) (Exhibit 10.11 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).                                                                                                                                                                                                                                                         
|            | 
|10.12       |  | Inter-Island Industrial Fuel Oil and Diesel Fuel Supply Contract by and between BHP Petroleum Americas Refining Inc. and HECO, MECO and HELCO dated November 14, 1997 (confidential treatment
has been requested for portions of this exhibit) (Exhibit 10.12 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1997, File No. 1-4955).                                                                                                                                                                                                                  



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|            |  |                                                                                                                                                                                                                                                                                 
|----------- |  | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------
|Exhibit no. |  | Description                                                                                                                                                                                                                                                                     
|            | 
|10.13       |  | Contract of private carriage by and between HITI and HELCO dated December 4, 2000 (Exhibit 10.13 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 2000, File
No. 1-4955).                                                                            
|            | 
|10.14       |  | Contract of private carriage by and between HITI and MECO dated December 4, 2000 (Exhibit 10.14 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 2000, File No.
1-4955).                                                                             
|            | 
|10.15       |  | HECO Nonemployee Directors Deferred Compensation Plan (Exhibit 10.16 to HECOs Annual Report on Form 10-K for the fiscal year ended December 31, 1990, File No.
1-4955).                                                                                                       
|            | 
|10.16       |  | HEI and HECO Executives Deferred Compensation Agreement. The agreement pertains to and is substantially identical for all the HEI and HECO executive officers (Exhibit 10.15 to
HEIs Annual Report on Form 10-K for the fiscal year ended December 31, 1991, File No. 1-8503).
|            | 
|11          |  | Computation of Earnings Per Share of Common Stock. See note on HECOs Selected Financial Data on page 49 herein.                                                                                                                                                                
|            | 
|*12         |  | Computation of Ratio of Earnings to Fixed Charges. Filed herein as page 108.                                                                                                                                                                                                    
|            | 
|18          |  | KPMG LLP letter re: change in accounting principle (Exhibit 18.2 to HECOs Quarterly Report on Form 10-Q for the quarter ended March 31, 2000, File No. 1-4955).                                                                                                                
|            | 
|*21         |  | Subsidiaries of HECO. Filed herein as page 109.                                                                                                                                                                                                                                 
|            | 
|*23.2       |  | Accountants Consent. Filed herein as page 103.                                                                                                                                                                                                                                 
|            | 
|*31.3       |  | Certification Pursuant to 13a-14 of the Securities and Exchange Act of 1934, as Adopted by Section 302 of the Sarbanes-Oxley Act of 2002 of T. Michael May (HECO Chief Executive Officer).
Filed herein as page 110.                                                            
|            | 
|*31.4       |  | Certification Pursuant to 13a-14 of the Securities and Exchange Act of 1934, as Adopted by Section 302 of the Sarbanes-Oxley Act of 2002 of Richard von Gnechten (HECO Chief Financial
Officer). Filed herein as page 111.                                                      
|            | 
|*32.3       |  | Written Statement Furnished Pursuant to 18 U.S.C. Section 1350, as Adopted by Section 906 of the Sarbanes-Oxley Act of 2002 of T. Michael May, HECO Chief Executive Officer. Filed herein as
page 112.                                                                          
|            | 
|*32.4       |  | Written Statement Furnished Pursuant to 18 U.S.C. Section 1350, as Adopted by Section 906 of the Sarbanes-Oxley Act of 2002 of Richard von Gnechten, HECO Chief Financial Officer. Filed herein
as page 113.                                                                    
|            | 
|*99.3       |  | Reconciliation of electric utility operating income per HEI and HECO Consolidated Statements of Income. Filed herein as page 114.                                                                                                                                               
|            | 
|99.4        |  | HECOs Consolidated Financial Statements (HECO Exhibit 99 to HECOs Current Report on Form 8-K dated February 26, 2004, File No. 1-4955)                                                                                                                                        



97



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HEI Exhibit 11



Hawaiian Electric Industries, Inc.

COMPUTATION OF EARNINGS PER SHARE

OF COMMON STOCK

Years ended December 31, 2003, 2002, 2001, 2000 and 1999



|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|------------------------------------------------------------- |  | ---- | ------- | - | ---- | - | ------- |  | - | ------- | - |  | ---- | ------- | - |  | - | ------
|(in thousands, except per share amounts)                      |  | 2003 |         |   | 2002 |   | 2001    |  |   | 2000    |   |  | 1999
|Net income (loss)                                             |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|Continuing operations                                         |  | $    | 118,048 |   |      | $ | 118,217 |  | $ | 107,746 |   |  | $    | 109,336 |   |  | $ | 96,426
|Discontinued operations                                       |  |      | (3,870  | ) |      |   |        |  |   | (24,041 | ) |  |      | (63,592 | ) |  |   | 421   
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|                                                              |  | $    | 114,178 |   |      | $ | 118,217 |  | $ | 83,705  |   |  | $    | 45,744  |   |  | $ | 96,847
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|Weighted-average number of common shares outstanding          |  |      | 37,348  |   |      |   | 36,278  |  |   | 33,754  |   |  |      | 32,545  |   |  |   | 32,188
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|Adjusted weighted-average number of common shares outstanding |  |      | 37,487  |   |      |   | 36,477  |  |   | 33,942  |   |  |      | 32,687  |   |  |   | 32,291
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|Basic earnings (loss) per common share                        |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|Continuing operations                                         |  | $    | 3.16    |   |      | $ | 3.26    |  | $ | 3.19    |   |  | $    | 3.36    |   |  | $ | 3.00  
|Discontinued operations                                       |  |      | (0.10   | ) |      |   |        |  |   | (0.71   | ) |  |      | (1.95   | ) |  |   | 0.01  
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|                                                              |  | $    | 3.06    |   |      | $ | 3.26    |  | $ | 2.48    |   |  | $    | 1.41    |   |  | $ | 3.01  
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|Diluted earnings (loss) per common share                      |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|Continuing operations                                         |  | $    | 3.15    |   |      | $ | 3.24    |  | $ | 3.18    |   |  | $    | 3.35    |   |  | $ | 2.99  
|Discontinued operations                                       |  |      | (0.10   | ) |      |   |        |  |   | (0.71   | ) |  |      | (1.95   | ) |  |   | 0.01  
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       
|                                                              |  | $    | 3.05    |   |      | $ | 3.24    |  | $ | 2.47    |   |  | $    | 1.40    |   |  | $ | 3.00  
|                                                              |  |      |         |   |      |   |         |  |   |         |   |  |      |         |   |  |   |       



98



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HEI Exhibit 12 (page 1 of 2)



Hawaiian Electric Industries, Inc.

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES



|                                                             |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  
|------------------------------------------------------------ |  | ---- | ------- | - | ---- | - | ------- | ---- |  | - | ------- | - |  | --- | ------- | - | --- | - | ------- | - |  | - | ------- | -
|                                                             |  | 2003 |         |   | 2002 |   |         | 2001 | 
|Years ended December 31                                      |  | (1)  |         |   | (2)  |   |         | (1)  |  |   | (2)     |   |  | (1) |         |   | (2) |  
|(dollars in thousands)                                       |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |  
|Fixed charges                                                |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  
|Total interest charges(3)                                    |  | $    | 138,808 |   |      | $ | 192,616 |      |  | $ | 151,543 |   |  | $   | 225,174 |   |     | $ | 175,780 |   |  | $ | 292,311 |  
|Interest component of rentals                                |  |      | 4,214   |   |      |   | 4,214   |      |  |   | 4,501   |   |  |     | 4,501   |   |     |   | 4,268   |   |  |   | 4,268   |  
|Pretax preferred stock dividend requirements of subsidiaries |  |      | 3,082   |   |      |   | 3,082   |      |  |   | 3,069   |   |  |     | 3,069   |   |     |   | 3,069   |   |  |   | 3,069   |  
|Preferred securities distributions of trust subsidiaries     |  |      | 16,035  |   |      |   | 16,035  |      |  |   | 16,035  |   |  |     | 16,035  |   |     |   | 16,035  |   |  |   | 16,035  |  
|                                                             |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  
|Total fixed charges                                          |  | $    | 162,139 |   |      | $ | 215,947 |      |  | $ | 175,148 |   |  | $   | 248,779 |   |     | $ | 199,152 |   |  | $ | 315,683 |  
|                                                             |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  
|Earnings                                                     |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  
|Pretax income from continuing operations                     |  | $    | 182,415 |   |      | $ | 182,415 |      |  | $ | 181,909 |   |  | $   | 181,909 |   |     | $ | 165,903 |   |  | $ | 165,903 |  
|Fixed charges, as shown                                      |  |      | 162,139 |   |      |   | 215,947 |      |  |   | 175,148 |   |  |     | 248,779 |   |     |   | 199,152 |   |  |   | 315,683 |  
|Interest capitalized                                         |  |      | (1,914  | ) |      |   | (1,914  | )    |  |   | (1,855  | ) |  |     | (1,855  | ) |     |   | (2,258  | ) |  |   | (2,258  | )
|                                                             |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  
|Earnings available for fixed charges                         |  | $    | 342,640 |   |      | $ | 396,448 |      |  | $ | 355,202 |   |  | $   | 428,833 |   |     | $ | 362,797 |   |  | $ | 479,328 |  
|                                                             |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  
|Ratio of earnings to fixed charges                           |  |      | 2.11    |   |      |   | 1.84    |      |  |   | 2.03    |   |  |     | 1.72    |   |     |   | 1.82    |   |  |   | 1.52    |  
|                                                             |  |      |         |   |      |   |         |      |  |   |         |   |  |     |         |   |     |   |         |   |  |   |         |  



|(1) | Excluding interest on ASB deposits.
|--- | -----------------------------------



|(2) | Including interest on ASB deposits.
|--- | -----------------------------------



|(3) | Interest on nonrecourse debt from leveraged leases is not included in total interest charges nor in interest expense in HEIs consolidated statements of income.
|--- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------



99



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HEI Exhibit 12 (page 2 of 2)



Hawaiian Electric Industries, Inc.

COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

Continued



|                                                             |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  
|------------------------------------------------------------ |  | ---- | ------- | - | ---- | - | ------- | --- |  | - | ------- | - |  | - | ------- | -
|                                                             |  | 2000 |         |   | 1999 |  
|Years ended December 31                                      |  | (1)  |         |   | (2)  |   |         | (1) |  |   | (2)     |  
|(dollars in thousands)                                       |  |      |         |   |      |   |         |     |  |   |         |  
|Fixed charges                                                |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  
|Total interest charges(3)                                    |  | $    | 196,980 |   |      | $ | 316,172 |     |  | $ | 158,947 |   |  | $ | 279,285 |  
|Interest component of rentals                                |  |      | 4,332   |   |      |   | 4,332   |     |  |   | 4,370   |   |  |   | 4,370   |  
|Pretax preferred stock dividend requirements of subsidiaries |  |      | 3,109   |   |      |   | 3,109   |     |  |   | 3,407   |   |  |   | 3,407   |  
|Preferred securities distributions of trust subsidiaries     |  |      | 16,035  |   |      |   | 16,035  |     |  |   | 16,025  |   |  |   | 16,025  |  
|                                                             |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  
|Total fixed charges                                          |  | $    | 220,456 |   |      | $ | 339,648 |     |  | $ | 182,749 |   |  | $ | 303,087 |  
|                                                             |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  
|Earnings                                                     |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  
|Pretax income from continuing operations                     |  | $    | 170,495 |   |      | $ | 170,495 |     |  | $ | 155,129 |   |  | $ | 155,129 |  
|Fixed charges, as shown                                      |  |      | 220,456 |   |      |   | 339,648 |     |  |   | 182,749 |   |  |   | 303,087 |  
|Interest capitalized                                         |  |      | (2,922  | ) |      |   | (2,922  | )   |  |   | (2,576  | ) |  |   | (2,576  | )
|                                                             |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  
|Earnings available for fixed charges                         |  | $    | 388,029 |   |      | $ | 507,221 |     |  | $ | 335,302 |   |  | $ | 455,640 |  
|                                                             |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  
|Ratio of earnings to fixed charges                           |  |      | 1.76    |   |      |   | 1.49    |     |  |   | 1.83    |   |  |   | 1.50    |  
|                                                             |  |      |         |   |      |   |         |     |  |   |         |   |  |   |         |  



|(1) | Excluding interest on ASB deposits.
|--- | -----------------------------------



|(2) | Including interest on ASB deposits.
|--- | -----------------------------------



|(3) | Interest on nonrecourse debt from leveraged leases is not included in total interest charges nor in interest expense in HEIs consolidated statements of income.
|--- | ----------------------------------------------------------------------------------------------------------------------------------------------------------------



100



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##### Table of Contents

HEI Exhibit 21



Hawaiian Electric Industries, Inc.

SUBSIDIARIES OF THE REGISTRANT



The following
is a list of all direct and indirect subsidiaries of the registrant as of March 1, 2004. The state/place of incorporation or organization is noted in parentheses and subsidiaries of intermediate parent companies are designated by indentations.



|Hawaiian | Electric Company, Inc. (Hawaii)
|-------- | -------------------------------

Maui Electric Company,
Limited (Hawaii)

Hawaii Electric Light Company, Inc. (Hawaii)

HECO Capital Trust I (Delaware)

HECO Capital Trust II (Delaware)

HECO Capital Trust III (Delaware)

Renewable
Hawaii, Inc. (Hawaii)

HEI Diversified, Inc. (Hawaii)

American Savings Bank, F.S.B. (federally chartered)

American Savings Investment Services Corp. (Hawaii)

Bishop Insurance Agency of Hawaii, Inc. (Hawaii)

AdCommunications, Inc. (Hawaii)

ASB Realty Corporation (Hawaii)

|Pacific | Energy Conservation Services, Inc. (Hawaii)
|------- | -------------------------------------------

HEI Properties, Inc. (Hawaii)

|Hycap | Management, Inc. (Delaware)
|----- | ---------------------------

HEI Preferred Funding, LP (a
limited partnership in which Hycap Management, Inc. is the sole general partner) (Delaware)

Hawaiian Electric Industries Capital Trust I (a statutory
trust) (Delaware)

Hawaiian Electric Industries Capital Trust II (a statutory trust) (Delaware) (potential financing entity)

Hawaiian Electric Industries Capital Trust III (a statutory trust) (Delaware) (potential financing entity)

The Old Oahu Tug Service, Inc. (Hawaii)



Discontinued operations:



HEI Power Corp. (Hawaii)

HEI Power Corp. International (Cayman Islands)

HEI Power Corp. Philippines (Cayman Islands)

HEI Power Corp. China (Republic of Mauritius)

HEI Power Corp. China II (Republic of Mauritius)

United Power Pacific Company Limited (Republic of Mauritius)

Baotou Tianjiao Power Co., Ltd. (Peoples
Republic of China)

(75% owned by United Power Pacific Company Limited)

HEI Investments, Inc. (Hawaii) (activity of leverage leases included in continuing operations)

Malama Pacific Corp. (Hawaii)



101



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##### Table of Contents

HEI Exhibit 23.1



[KPMG LLP letterhead]



Independent Auditors Consent



The Board of Directors

Hawaiian Electric Industries, Inc.:



We consent to incorporation by reference in Registration Statement Nos. 333-18809, 333-56312,
333-87782, 333-108110 and 333-113120 on Form S-3 and Registration Statement Nos. 33-65234, 333-05667, 333-02103 and 333-105404 on Form S-8 of Hawaiian Electric Industries, Inc., and Registration Statement Nos. 333-18809-01 and 333-18809-04 on Form
S-3 of Hawaiian Electric Industries Capital Trust I and HEI Preferred Funding, LP and Registration Statement Nos. 333-18809-02 and 333-113120-02 on Form S-3 of Hawaiian Electric Industries Capital Trust II and Registration Statement Nos.
333-18809-03 and 333-113120-01 on Form S-3 of Hawaiian Electric Industries Capital Trust III of our report dated February 11, 2004, relating to the consolidated balance sheets of Hawaiian Electric Industries, Inc. and subsidiaries as of December 31,
2003 and 2002, and the related consolidated statements of income, changes in stockholders equity, and cash flows for each of the years in the three-year period ended December 31, 2003, which report is incorporated by reference in the 2003
annual report on Form 10-K of Hawaiian Electric Industries, Inc. We also consent to incorporation by reference of our report dated February 11, 2004 relating to the financial statement schedules of Hawaiian Electric Industries, Inc. in the
aforementioned 2003 annual report on Form 10-K, which report is included in said Form 10-K.



Our reports refer to a change to the accounting method for goodwill and other intangible assets and for stock-based compensation.



/s/ KPMG LLP



Honolulu, Hawaii

March 9, 2004



102



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##### Table of Contents

HECO Exhibit 23.2



[KPMG LLP letterhead]



Independent Auditors Consent



The Board of Directors

Hawaiian Electric Company, Inc.:



We consent to incorporation by reference in Registration Statement Nos. 333-111073,
333-111073-01, 333-111073-02 and 333-111073-03 on Form S-3 of Hawaiian Electric Company, Inc., Hawaii Electric Light Company, Inc., Maui Electric Company, Limited, and HECO Capital Trust III of our report dated February 11, 2004, relating to the
consolidated balance sheets and consolidated statements of capitalization of Hawaiian Electric Company, Inc. and subsidiaries as of December 31, 2003 and 2002, and the related consolidated statements of income, retained earnings, and cash flows for
each of the years in the three-year period ended December 31, 2003, which report is incorporated by reference in the 2003 annual report on Form 10-K of Hawaiian Electric Industries, Inc. We also consent to incorporation by reference of our report
dated February 11, 2004 relating to the financial statement schedule of Hawaiian Electric Company, Inc. in the aforementioned 2003 annual report on Form 10-K, which report is included in said Form 10-K.



/s/ KPMG LLP



Honolulu, Hawaii

March 9, 2004



103



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##### Table of Contents

HEI Exhibit 31.1



Certification Pursuant to Section 13a-14 of the Securities Exchange Act of 1934 of Robert F. Clarke (HEI Chief Executive Officer)



I, Robert F. Clarke, certify that:



1. I have reviewed this report on Form 10-K for the year ended December 31, 2003 of Hawaiian
Electric Industries, Inc. (registrant);



2. Based on my knowledge,
this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the
period covered by this report;



3. Based on my knowledge, the financial
statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;



4. The registrants other certifying officer(s) and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:



| | (a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information
relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
| | --- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Evaluated the effectiveness of the registrants disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure
controls and procedures, as of the end of the period covered by this report based on such evaluation; and
| | --- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (c) | Disclosed in this report any change in the registrants internal control over financial reporting that occurred during the registrants most recent fiscal quarter (the
registrants fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrants internal control over financial reporting; and
| | --- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



5. The registrants other certifying officer(s) and I have disclosed, based on our most
recent evaluation of internal control over financial reporting, to the registrants auditors and the audit committee of the registrants board of directors (or persons performing the equivalent functions):



| | (a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the
registrants ability to record, process, summarize and report financial information; and
| | --- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrants internal control over financial reporting.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Date: March 9, 2004



/s/ Robert F. ClarkeRobert F. ClarkeChairman, President and Chief Executive Officer




104



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##### Table of Contents

HEI Exhibit 31.2



Certification Pursuant to Section 13a-14 of the Securities Exchange Act of 1934 of Eric K. Yeaman (HEI Chief Financial Officer)



I, Eric K. Yeaman, certify that:



1. I have reviewed this report on Form 10-K for the year ended December 31, 2003 of Hawaiian
Electric Industries, Inc. (registrant);



2. Based on my knowledge,
this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the
period covered by this report;



3. Based on my knowledge, the financial
statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;



4. The registrants other certifying officer(s) and I are responsible for
establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:



| | (a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information
relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
| | --- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Evaluated the effectiveness of the registrants disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure
controls and procedures, as of the end of the period covered by this report based on such evaluation; and
| | --- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (c) | Disclosed in this report any change in the registrants internal control over financial reporting that occurred during the registrants most recent fiscal quarter (the
registrants fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrants internal control over financial reporting; and
| | --- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



5. The registrants other certifying officer(s) and I have disclosed, based on our most
recent evaluation of internal control over financial reporting, to the registrants auditors and the audit committee of the registrants board of directors (or persons performing the equivalent functions):



| | (a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the
registrants ability to record, process, summarize and report financial information; and
| | --- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrants internal control over financial reporting.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Date: March 9, 2004



/s/ Eric K. YeamanEric K. YeamanFinancial Vice President, Treasurer and Chief Financial Officer




105



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##### Table of Contents

HEI Exhibit 32.1



Hawaiian Electric Industries, Inc.



Written Statement of Chief Executive Officer Furnished Pursuant to

18 U.S.C. Section 1350,

as Adopted by

Section 906 of the Sarbanes-Oxley Act of 2002



In connection with the Annual Report of Hawaiian Electric Industries, Inc. (HEI) on Form 10-K for the year ended December 31, 2003 as filed with the
Securities and Exchange Commission (the Report), I, Robert F. Clarke, Chief Executive Officer of HEI, certify, pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:



|(1) | The Report fully complies with the requirements of section 13(a) of the Securities Exchange Act of 1934; and
|--- | ------------------------------------------------------------------------------------------------------------



|(2) | The consolidated information contained in the Report fairly presents, in all material respects, the financial condition as of December 31, 2003 and results of operations for the
year ended December 31, 2003 of HEI and its subsidiaries.
|--- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|                                                                                           
|-------------------------------------------------------------------------------------------
|                                                                                           
|/s/ Robert F. Clarke                                                                       
|                                                                                           
|Robert F. Clarke Chairman, President and Chief Executive Officer of HEI Date: March 9, 2004



A signed original of this written
statement required by Section 906 has been provided to Hawaiian Electric Industries, Inc. and will be retained by Hawaiian Electric Industries, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.



106



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##### Table of Contents

HEI Exhibit 32.2



Hawaiian Electric Industries, Inc.



Written Statement of Chief Financial Officer Furnished Pursuant to

18 U.S.C. Section 1350,

as Adopted by

Section 906 of the Sarbanes-Oxley Act of 2002



In connection with the Annual Report of Hawaiian Electric Industries, Inc. (HEI) on Form 10-K for the year ended December 31, 2003 as filed with the
Securities and Exchange Commission (the Report), I, Eric K. Yeaman, Chief Financial Officer of HEI, certify, pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:



|(1) | The Report fully complies with the requirements of section 13(a) of the Securities Exchange Act of 1934; and
|--- | ------------------------------------------------------------------------------------------------------------



|(2) | The consolidated information contained in the Report fairly presents, in all material respects, the financial condition as of December 31, 2003 and results of operations for the
year ended December 31, 2003 of HEI and its subsidiaries.
|--- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|                                                                                                         
|---------------------------------------------------------------------------------------------------------
|                                                                                                         
|/s/ Eric K. Yeaman                                                                                       
|                                                                                                         
|Eric K. Yeaman Financial Vice President, Treasurer and Chief Financial Officer of HEI Date: March 9, 2004



A signed original of this written
statement required by Section 906 has been provided to Hawaiian Electric Industries, Inc. and will be retained by Hawaiian Electric Industries, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.



107



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##### Table of Contents

HECO Exhibit 12



Hawaiian Electric Company, Inc.

COMPUTATION
OF RATIO OF EARNINGS TO FIXED CHARGES



|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|----------------------------------------------------------------------------- |  | ---- | ------- | - | ---- | - | ------- | ---- |  | - | ------- | - |  | ---- | ------- | - |  | - | ------- | -
|Years ended December 31                                                       |  | 2003 |         |   | 2002 |   |         | 2001 |  |   | 2000    |   |  | 1999 |        
|(dollars in thousands)                                                        |  |      |         |   |      |   |         |      |  |   |         |   |  |      |        
|Fixed charges                                                                 |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Total interest charges                                                        |  | $    | 44,341  |   |      | $ | 44,232  |      |  | $ | 47,056  |   |  | $    | 49,062  |   |  | $ | 48,461  |  
|Interest component of rentals                                                 |  |      | 820     |   |      |   | 663     |      |  |   | 728     |   |  |      | 696     |   |  |   | 784     |  
|Pretax preferred stock dividend requirements of subsidiaries                  |  |      | 1,430   |   |      |   | 1,434   |      |  |   | 1,433   |   |  |      | 1,438   |   |  |   | 1,479   |  
|Preferred securities distributions of trust subsidiaries                      |  |      | 7,675   |   |      |   | 7,675   |      |  |   | 7,675   |   |  |      | 7,675   |   |  |   | 7,665   |  
|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Total fixed charges                                                           |  | $    | 54,266  |   |      | $ | 54,004  |      |  | $ | 56,892  |   |  | $    | 58,871  |   |  | $ | 58,389  |  
|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Earnings                                                                      |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Income before preferred stock dividends of HECO                               |  | $    | 79,991  |   |      | $ | 91,285  |      |  | $ | 89,380  |   |  | $    | 88,366  |   |  | $ | 76,400  |  
|Fixed charges, as shown                                                       |  |      | 54,266  |   |      |   | 54,004  |      |  |   | 56,892  |   |  |      | 58,871  |   |  |   | 58,389  |  
|Income taxes (see note below)                                                 |  |      | 49,824  |   |      |   | 56,658  |      |  |   | 55,416  |   |  |      | 55,375  |   |  |   | 48,047  |  
|Allowance for borrowed funds used during construction                         |  |      | (1,914  | ) |      |   | (1,855  | )    |  |   | (2,258  | ) |  |      | (2,922  | ) |  |   | (2,576  | )
|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Earnings available for fixed charges                                          |  | $    | 182,167 |   |      | $ | 200,092 |      |  | $ | 199,430 |   |  | $    | 199,690 |   |  | $ | 180,260 |  
|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Ratio of earnings to fixed charges                                            |  |      | 3.36    |   |      |   | 3.71    |      |  |   | 3.51    |   |  |      | 3.39    |   |  |   | 3.09    |  
|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Note:                                                                         |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Income taxes is comprised of the following:                                   |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|Income tax expense relating to operating income from regulated activities     |  | $    | 50,175  |   |      | $ | 56,729  |      |  | $ | 55,434  |   |  | $    | 55,213  |   |  | $ | 48,281  |  
|Income tax expense (benefit) relating to results from nonregulated activities |  |      | (351    | ) |      |   | (71     | )    |  |   | (18     | ) |  |      | 162     |   |  |   | (234    | )
|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  
|                                                                              |  | $    | 49,824  |   |      | $ | 56,658  |      |  | $ | 55,416  |   |  | $    | 55,375  |   |  | $ | 48,047  |  
|                                                                              |  |      |         |   |      |   |         |      |  |   |         |   |  |      |         |   |  |   |         |  



108



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##### Table of Contents

HECO Exhibit 21



Hawaiian Electric Company, Inc.

SUBSIDIARIES OF THE REGISTRANT



The following
is a list of all subsidiaries of the registrant as of March 1, 2004. The state/place of incorporation or organization is noted in parentheses.



Maui Electric Company, Limited (Hawaii)



Hawaii Electric Light Company, Inc. (Hawaii)



HECO Capital Trust I (a statutory trust) (Delaware)



HECO Capital Trust II (a statutory trust) (Delaware)



HECO Capital Trust III (a statutory trust) (Delaware)



Renewable Hawaii, Inc. (Hawaii)



109



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##### Table of Contents

HECO Exhibit 31.3



Certification Pursuant to Section 13a-14 of the Securities Exchange Act of 1934 of T. Michael May

(HECO Chief Executive Officer)



I, T.
Michael May, certify that:



1. I have reviewed this report on Form 10-K for the
quarter ended December 31, 2003 of Hawaiian Electric Company, Inc. (registrant);



2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such
statements were made, not misleading with respect to the period covered by this report;



3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and
for, the periods presented in this report;



4. The registrants other
certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:



| | (a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information
relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
| | --- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Evaluated the effectiveness of the registrants disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure
controls and procedures, as of the end of the period covered by this report based on such evaluation; and
| | --- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (c) | Disclosed in this report any change in the registrants internal control over financial reporting that occurred during the registrants most recent fiscal quarter (the
registrants fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrants internal control over financial reporting; and
| | --- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



5. The registrants other certifying officer(s) and I have disclosed, based on our most
recent evaluation of internal control over financial reporting, to the registrants auditors and the audit committee of the registrants board of directors (or persons performing the equivalent functions):



| | (a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the
registrants ability to record, process, summarize and report financial information; and
| | --- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrants internal control over financial reporting.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Date: March 9, 2004



/s/ T. Michael MayT. Michael MayPresident and Chief Executive Officer




110



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##### Table of Contents

HECO Exhibit 31.4



Certification Pursuant to Section 13a-14 of the Securities Exchange Act of 1934 of Richard A. von Gnechten

(HECO Chief Financial Officer)



I, Richard A. von Gnechten, certify that:



1. I have reviewed this report on Form 10-K for the year ended December 31, 2003 of Hawaiian Electric Company, Inc. (registrant);



2. Based on my knowledge, this report does not contain any untrue statement of a material
fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;



3. Based on my knowledge, the financial statements, and other financial information included
in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;



4. The registrants other certifying officer(s) and I are responsible for establishing
and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) for the registrant and have:



| | (a) | Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information
relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
| | --- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Evaluated the effectiveness of the registrants disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure
controls and procedures, as of the end of the period covered by this report based on such evaluation; and
| | --- | -----------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (c) | Disclosed in this report any change in the registrants internal control over financial reporting that occurred during the registrants most recent fiscal quarter (the
registrants fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrants internal control over financial reporting; and
| | --- | ---------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



5. The registrants other certifying officer(s) and I have disclosed, based on our most
recent evaluation of internal control over financial reporting, to the registrants auditors and the audit committee of the registrants board of directors (or persons performing the equivalent functions):



| | (a) | All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the
registrants ability to record, process, summarize and report financial information; and
| | --- | -------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



| | (b) | Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrants internal control over financial reporting.
| | --- | --------------------------------------------------------------------------------------------------------------------------------------------------------------------------



Date: March 9, 2004



/s/ Richard A. von GnechtenRichard A. von GnechtenFinancial Vice President




111



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##### Table of Contents

HECO Exhibit 32.3



Hawaiian Electric Company, Inc.



Written Statement of Chief Executive Officer Furnished Pursuant to

18 U.S.C. Section 1350,

as Adopted by

Section 906 of the Sarbanes-Oxley Act of 2002



In connection with the Annual Report of Hawaiian Electric Company, Inc. (HECO) on Form 10-K for the year ended December 31, 2003 as filed with the
Securities and Exchange Commission (the HECO Report), I, T. Michael May, Chief Executive Officer of HECO, certify, pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge, that:



|(1) | The HECO Report fully complies with the requirements of section 13(a) of the Securities Exchange Act of 1934; and
|--- | -----------------------------------------------------------------------------------------------------------------



|(2) | The HECO consolidated information contained in the HECO Report fairly presents, in all material respects, the financial condition as of December 31, 2003 and results of operations
for the year ended December 31, 2003 of HECO and its subsidiaries.
|--- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|                                             
|---------------------------------------------
|                                             
|/s/ T. Michael May                           
|                                             
|T. Michael May                               
|President and Chief Executive Officer of HECO
|Date: March 9, 2004                          



A signed original of this written
statement required by Section 906 has been provided to Hawaiian Electric Company, Inc. and will be retained by Hawaiian Electric Company, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.



112



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##### Table of Contents

HECO Exhibit 32.4



Hawaiian Electric Company, Inc.



Written Statement of Chief Financial Officer Furnished Pursuant to

18 U.S.C. Section 1350,

as Adopted by

Section 906 of the Sarbanes-Oxley Act of 2002



In connection with the Annual Report of Hawaiian Electric Company, Inc. (HECO) on Form 10-K for the year ended December 31, 2003 as filed with the
Securities and Exchange Commission (the HECO Report), I, Richard A. von Gnechten, Chief Financial Officer of HECO, certify, pursuant to 18 U.S.C. Section 1350, as adopted by Section 906 of the Sarbanes-Oxley Act of 2002, to the best of my knowledge,
that:



|(1) | The HECO Report fully complies with the requirements of section 13(a) of the Securities Exchange Act of 1934; and
|--- | -----------------------------------------------------------------------------------------------------------------



|(2) | The HECO consolidated information contained in the HECO Report fairly presents, in all material respects, the financial condition as of December 31, 2003 and results of operations
for the year ended December 31, 2003 of HECO and its subsidiaries.
|--- | ------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------------



|                                                                    
|--------------------------------------------------------------------
|                                                                    
|/s/ Richard A. von Gnechten                                         
|                                                                    
|Richard A. von Gnechten Financial Vice President Date: March 9, 2004



A signed original of this written
statement required by Section 906 has been provided to Hawaiian Electric Company, Inc. and will be retained by Hawaiian Electric Company, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.



113



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##### Table of Contents

HECO Exhibit 99.3



Hawaiian Electric Company, Inc.

RECONCILIATION OF ELECTRIC UTILITY OPERATING

INCOME PER HEI AND HECO CONSOLIDATED

STATEMENTS OF INCOME



|                                                                                                                            |  |      |         |   |      |   |         |      |  |   |         |  
|--------------------------------------------------------------------------------------------------------------------------- |  | ---- | ------- | - | ---- | - | ------- | ---- |  | - | ------- | -
|Years ended December 31                                                                                                     |  | 2003 |         |   | 2002 |   |         | 2001 | 
|(in thousands)                                                                                                              |  |      |         |   |      |   |         |      | 
|Operating income from regulated and nonregulated activities before income taxes (per HEI Consolidated Statements of Income) |  | $    | 176,565 |   |      | $ | 194,956 |      |  | $ | 193,945 |  
|                                                                                                                            |  |      |        
|Deduct:                                                                                                                     |  |      |         |   |      |   |         |      |  |   |         |  
|Income taxes on regulated activities                                                                                        |  |      | (50,175 | ) |      |   | (56,729 | )    |  |   | (55,434 | )
|Revenues from nonregulated activities                                                                                       |  |      | (3,647  | ) |      |   | (4,247  | )    |  |   | (4,992  | )
|                                                                                                                            |  |      |        
|Add:                                                                                                                        |  |      |         |   |      |   |         |      |  |   |         |  
|Expenses from nonregulated activities                                                                                       |  |      | 2,095   |   |      |   | 1,177   |      |  |   | 1,813   |  
|                                                                                                                            |  |      |         |   |      |   |         |      |  |   |         |  
|Operating income from regulated activities after income taxes (per HECO Consolidated Statements of Income)                  |  | $    | 124,838 |   |      | $ | 135,157 |      |  | $ | 135,332 |  
|                                                                                                                            |  |      |         |   |      |   |         |      |  |   |         |  



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SIGNATURES



Pursuant to the
requirements of Section 13 or 15(d) 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 execution of this report by registrant Hawaiian
Electric Company, Inc. shall be deemed to relate only to matters having reference to such registrant and its subsidiaries.



|                                   |  |                                                                                                                           |  |                                 |  |       |  |                                                                                                
|---------------------------------- |  | ------------------------------------------------------------------------------------------------------------------------- |  | ------------------------------- |  | ----- |  | -----------------------------------------------------------------------------------------------
|HAWAIIAN ELECTRIC INDUSTRIES, INC. |  |                                                                                                                           |  | HAWAIIAN ELECTRIC COMPANY, INC.
|(Registrant)                       |  |                                                                                                                           |  | (Registrant)                   
|                                   |  |                                                                                                                           |  |                                
|By                                 |  | /s/ Eric K. Yeaman                                                                                                        |  |                                 |  | By    |  | /s/ Richard A. von Gnechten                                                                    
|                                   |  |                                                                                                                           |  |                                 |  |       |  |                                                                                                
|                                   |  | Eric K. Yeaman Financial Vice President, Treasurer andChief Financial Officer of HEI (Principal Financial Officer of HEI) |  |                                 |  |       |  | Richard A. von Gnechten Financial Vice President of HECO  (Principal Financial Officer of HECO)
|                                   |  |                                                                                                                           |  |                                
|Date:                              |  | March 9, 2004                                                                                                             |  |                                 |  | Date: |  | March 9, 2004                                                                                  



Pursuant to the
requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrants and in the capacities indicated on March 9, 2004. The execution of this report by each of the undersigned
who signs this report solely in such persons capacity as a director or officer of Hawaiian Electric Company, Inc. shall be deemed to relate only to matters having reference to such registrant and its subsidiaries.



|                                     |  |                                                                                                                                             
|------------------------------------ |  | --------------------------------------------------------------------------------------------------------------------------------------------
|Signature                            |  | Title                                                                                                                                       
|                                     | 
|/s/ Robert F. ClarkeRobert F. Clarke |  | Chairman, President and Chairman of theBoard of Directors of HEI Chairman of the Board of Directors of HECO (Chief Executive Officer of HEI)
|                                    
|                                    
|                                    
|                                     | 
|/s/ T. Michael MayT. Michael May     |  | Director of HEI President and Director of HECO (Chief Executive Officer of HECO)                                                            
|                                     | 
|/s/ Eric K. YeamanEric K. Yeaman     |  | Financial Vice President, Treasurer andChief Financial Officer of HEI (Principal Financial Officer of HEI)                                  
|                                     | 
|/s/ Curtis Y. HaradaCurtis Y. Harada |  | Controller of HEI (Principal Accounting Officer of HEI)                                                                                     



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SIGNATURES (continued)



|                                                   |  |                                                               
|-------------------------------------------------- |  | --------------------------------------------------------------
|Signature                                          |  | Title                                                         
|                                                   | 
|/s/ Richard A. von GnechtenRichard A. von Gnechten |  | Financial Vice President (Principal Financial Officer of HECO)
|                                                  
|                                                   | 
|/s/ Ernest T. ShirakiErnest T. Shiraki             |  | Controller of HECO (Principal Accounting Officer of HECO)     
|                                                  
|                                                   | 
|/s/ Don E. CarrollDon E. Carroll                   |  | Director of HEI                                               
|                                                  
|                                                   | 
|/s/ Shirley J. DanielShirley J. Daniel             |  | Director of HEI and HECO                                      
|                                                  
|                                                   | 
|Constance H. Lau                                   |  | Director of HEI                                               
|                                                  
|                                                   | 
|/s/ Victor Hao LiVictor Hao Li                     |  | Director of HEI                                               
|                                                  
|                                                   | 
|/s/ Bill D. MillsBill D. Mills                     |  | Director of HEI                                               
|                                                  
|                                                   | 
|/s/ A. Maurice MyersA. Maurice Myers               |  | Director of HEI                                               
|                                                  



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SIGNATURES (continued)



|                                         |  |                         
|---------------------------------------- |  | ------------------------
|Signature                                |  | Title                   
|                                         | 
|/s/ Diane J. PlottsDiane J. Plotts       |  | Director of HEI and HECO
|                                         | 
|/s/ James K. ScottJames K. Scott         |  | Director of HEI and HECO
|                                         | 
|Oswald K. Stender                        |  | Director of HEI         
|                                         | 
|Anne M. Takabuki                         |  | Director of HECO        
|                                         | 
|/s/ Barry K. TaniguchiBarry K. Taniguchi |  | Director of HECO        
|                                         | 
|/s/ Kelvin H. TaketaKelvin H. Taketa     |  | Director of HEI         
|                                         | 
|Jeffrey N. Watanabe                      |  | Director of HEI and HECO



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