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Commitments and contingencies - (Details) - HECO (USD $) | 3 Months Ended | 6 Months Ended |  | 1 Months Ended |  | 12 Months Ended |  | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended |
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Jun. 30, 2011 | Jun. 30, 2010 | Jun. 30, 2011 | Jun. 30, 2010 | Jun. 30, 2011 Hawaiian Electric Company, Inc. and Subsidiaries Campbell Industrial Park 110MW combustion turbine and transmission line mW | Jun. 30, 2011 East Oahu transmission project | Jun. 30, 2011 Hawaiian Electric Company, Inc. and Subsidiaries East Oahu Transmission Project Phase 1 | Jun. 30, 2011 East Oahu Transmission Project Phase 1 | Apr. 30, 2010 Hawaiian Electric Company, Inc. and Subsidiaries East Oahu Transmission Project Phase 2 | Jun. 30, 2011 Hawaiian Electric Company, Inc. and Subsidiaries East Oahu Transmission Project Phase 2 | Jun. 30, 2011 East Oahu Transmission Project Phase 2 | Dec. 31, 2005 Hawaiian Electric Company, Inc. and Subsidiaries Customer Information System Project | Jun. 30, 2011 Hawaiian Electric Company, Inc. and Subsidiaries Customer Information System Project | Jan. 31, 2011 Hawaiian Electric Company, Inc. and Subsidiaries | Aug. 31, 2010 Hawaiian Electric Company, Inc. and Subsidiaries | Sep. 30, 2009 Hawaiian Electric Company, Inc. and Subsidiaries | Jun. 30, 2011 Hawaiian Electric Company, Inc. and Subsidiaries | Jun. 30, 2010 Hawaiian Electric Company, Inc. and Subsidiaries | Jun. 30, 2011 Hawaiian Electric Company, Inc. and Subsidiaries mW kW | Jun. 30, 2010 Hawaiian Electric Company, Inc. and Subsidiaries | Dec. 31, 2013 Hawaiian Electric Company, Inc. and Subsidiaries | Dec. 31, 2012 Hawaiian Electric Company, Inc. and Subsidiaries | Dec. 31, 2011 Hawaiian Electric Company, Inc. and Subsidiaries | Jun. 30, 2011 Group of subsidiaries | Jun. 30, 2011 Electric utility
Regulatory projects and legal obligations |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deferred cost to be recovered subject to PUC approval |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | $ 3,900,000 |  |  |  |  |  |
Estimated cost of settement agreement not approved by PUC |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 3,200,000 |  | 3,200,000 |  |  |  |  |  |
Integration from renewable energy sources (in megawatts) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 200 |  |  |  |  |  |
Revenue recognized with respect to interim rate increase order |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 11,000,000 |  |  |  |  |  |
Estimated project cost above PUC approval |  |  |  |  | 32,000,000 |  | 43,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Capacity of projects (in megawatts) |  |  |  |  | 110 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Cost of project recoverable from increase in annual revenue |  |  |  |  | 163,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Estimated project cost |  |  |  |  |  | 56,000,000 |  | 42,000,000 |  |  | 14,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |
Project cost incurred |  |  |  |  | 195,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Allowance for funds used during construction | (553,000) | (790,000) | (1,073,000) | (1,569,000) | 9,000,000 |  |  |  |  |  |  |  |  |  |  |  | (553,000) | (790,000) | (1,073,000) | (1,569,000) |  |  |  |  |
Estimated project cost subject to decision and order issued |  |  |  |  |  |  | 16,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Amount authorized for the project |  |  |  |  |  |  |  |  |  |  |  | 20,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |
Net estimated cost of using smart grid technology |  |  |  |  |  |  |  |  | 10,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Estimated cost of smart grid technology |  |  |  |  |  |  |  |  | 15,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Estimated statutory funding for smart grid technology |  |  |  |  |  |  |  |  | 5,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Accumulated project cost |  |  |  |  |  |  | 59,000,000 |  |  | 5,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Accumulated project planning and permitting cost |  |  |  |  |  |  | 12,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Accumulated project planning and permitting cost after denial of permit |  |  |  |  |  |  | 24,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Accumulated cost for allowance for funds used during construction |  |  |  |  |  |  | 23,000,000 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deferred and capital cost |  |  |  |  |  |  |  |  |  |  |  |  | 57,000,000 |  |  |  |  |  |  |  |  |  |  |  |
Deferred and capital cost recorded |  |  |  |  |  |  |  |  |  |  |  |  | 30,000,000 |  |  |  |  |  |  |  |  |  |  |  |
Environmental regulation |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Number of periods allowed for compliance of EPA regulation (in years) |  |  | 8 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Number of EGUs impacted by proposed rules of MACT |  |  | 14 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Number of periods allowed for compliance of MACT rules (in years) |  |  | 3 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Number of extension periods allowed for installation of emission control technology (in years) |  |  | 1 |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Deferral period for GHG permitting requirements for carbon dioxide emissions (in years) |  |  |  |  |  |  |  |  |  |  |  |  |  | 3 |  |  |  |  |  |  |  |  |  |  |
Asset retirement obligations |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Asset retirement obligation related to removal of retired generating units |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 12,000,000 | 23,000,000 |  |  |  |  |  |  |  |  |
Changes in the asset retirement obligation liability |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Balance at the beginning of the period |  |  |  |  |  |  |  |  |  |  |  |  |  | 48,630,000 |  |  |  |  | 48,630,000 | 23,746,000 |  |  | 48,630,000 |  |
Accretion expense |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 1,134,000 | 1,143,000 |  |  |  |  |
Liabilities settled |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | (573,000) | (11,000) |  |  |  |  |
Revisions in estimated cash flows |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 11,141,000 |  |  |  |  |
Balance at the end of the period |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 49,191,000 | 36,019,000 | 49,191,000 | 36,019,000 |  |  |  |  |
Collective bargaining agreement |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Percentage of employees who are members of the International Brotherhood of Electrical Workers (as a percent) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 53.00%
Non-compounded wage increase (as a percent) |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | 3.00% | 2.50% | 1.75% |  |
Limited insurance |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |
Estimated replacement value of transmission and distribution system |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | $ 5,000,000,000 |

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