DEI_Document
DEI Document (USD $) | 12 Months Ended | ||
In Billions, except Share data, unless otherwise specified | Dec. 31, 2013 | Jan. 31, 2014 | Jun. 30, 2013 |
Entity Registrant Name | 'DTE ENERGY CO | ' | ' |
Entity Central Index Key | '0000936340 | ' | ' |
Current Fiscal Year End Date | '--12-31 | ' | ' |
Entity Filer Category | 'Accelerated Filer | ' | ' |
Document Type | '10-K | ' | ' |
Document Period End Date | 31-Dec-13 | ' | ' |
Document Fiscal Year Focus | '2013 | ' | ' |
Document Fiscal Period Focus | 'Q4 | ' | ' |
Amendment Flag | 'false | ' | ' |
Entity Common Stock, Shares Outstanding | ' | 177,086,236 | ' |
Entity Well-known Seasoned Issuer | 'No | ' | ' |
Entity Voluntary Filers | 'No | ' | ' |
Entity Current Reporting Status | 'Yes | ' | ' |
Entity Public Float | ' | ' | $11.70 |
Consolidated_Statements_of_Ope
Consolidated Statements of Operations (USD $) | 12 Months Ended | ||
In Millions, except Per Share data, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Income Statement [Abstract] | ' | ' | ' |
Operating Revenue | $9,661 | $8,791 | $8,858 |
Operating Expenses | ' | ' | ' |
Fuel, purchased power and gas | 4,055 | 3,296 | 3,537 |
Operation and maintenance | 2,978 | 2,892 | 2,612 |
Depreciation, depletion and amortization | 1,094 | 995 | 977 |
Taxes other than income | 340 | 332 | 310 |
Asset (gains) and losses, reserves and impairments, net | -9 | -3 | 1 |
Total operating expenses | 8,458 | 7,512 | 7,437 |
Operating Income | 1,203 | 1,279 | 1,421 |
Other (Income) and Deductions | ' | ' | ' |
Interest expense | 436 | 440 | 488 |
Interest income | -9 | -10 | -10 |
Other Income | -201 | -173 | -117 |
Other expenses | 55 | 62 | 69 |
Total Other (Income) and Deductions | 281 | 319 | 430 |
Income Before Income Taxes | 922 | 960 | 991 |
Income Tax Expense | 254 | 286 | 268 |
Income from Continuing Operations | 668 | 674 | 723 |
Discontinued Operations Income (Loss), net of tax | 0 | -56 | -3 |
Net Income | 668 | 618 | 720 |
Less: Net Income Attributable to Noncontrolling Interests | 7 | 8 | 9 |
Net Income Attributable to DTE Energy Company | $661 | $610 | $711 |
Basic Earnings per Common Share | ' | ' | ' |
Income from continuing operations | $3.76 | $3.89 | $4.21 |
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share | $0 | ($0.33) | ($0.02) |
Total Basic Earnings per Common Share | $3.76 | $3.56 | $4.19 |
Diluted Earnings per Common Share | ' | ' | ' |
Income from continuing operations | $3.76 | $3.88 | $4.20 |
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share | $0 | ($0.33) | ($0.02) |
Total Diluted Earnings per Common Share | $3.76 | $3.55 | $4.18 |
Weighted Average Common Shares Outstanding | ' | ' | ' |
Basic | 175 | 171 | 169 |
Weighted Average Number Diluted Shares Outstanding Adjustment | 175 | 172 | 170 |
Dividends Declared per Common Share | $2.59 | $2.42 | $2.32 |
Consolidated_Statements_of_Com
Consolidated Statements of Comprehensive Income (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Statement of Income and Comprehensive Income [Abstract] | ' | ' | ' |
Net Income | $668 | $618 | $720 |
Other comprehensive income (loss), net of tax: | ' | ' | ' |
Benefit obligations, net of taxes of $13, $(1) and $(5) | 22 | -2 | -9 |
Net unrealized gains on investments during the period, net of taxes of $1, $1 and $— | 2 | 1 | 0 |
Foreign currency translation, net of taxes of $(1), $— and $— | -2 | 1 | 0 |
Other Comprehensive Income (Loss), Net of Tax | 22 | 0 | -9 |
Comprehensive income | 690 | 618 | 711 |
Less: Comprehensive income attributable to noncontrolling interests | 7 | 8 | 9 |
Comprehensive income attributable to DTE Energy Company | $683 | $610 | $702 |
Consolidated_Statements_of_Com1
Consolidated Statements of Comprehensive Income (Parenthetical) (Parentheticals) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Tax | $13 | ($1) | ($5) |
Other Comprehensive Income (Loss), Unrealized Gain (Loss) on Derivatives Arising During Period, Tax | 0 | 0 | 0 |
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, Tax | 1 | 1 | 0 |
Other Comprehensive Income (Loss), Foreign Currency Translation Gain (Loss) Arising During Period, Tax | ($1) | $0 | $0 |
Consolidated_Statements_of_Fin
Consolidated Statements of Financial Position (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Current Assets | ' | ' |
Cash and cash equivalents | $52 | $65 |
Restricted cash, principally Securitization | 123 | 122 |
Accounts receivable (less allowance for doubtful accounts of $55 and $62, respectively) | ' | ' |
Customer | 1,542 | 1,336 |
Other | 127 | 126 |
Inventories | ' | ' |
Fuel and gas | 363 | 527 |
Materials and supplies | 265 | 234 |
Derivative assets | 99 | 108 |
Regulatory assets | 26 | 182 |
Other | 209 | 215 |
Total Current Assets | 2,806 | 2,915 |
Investments | ' | ' |
Nuclear decommissioning trust funds | 1,191 | 1,037 |
Other | 603 | 554 |
Total Investments | 1,794 | 1,591 |
Property | ' | ' |
Property, plant and equipment | 25,123 | 23,631 |
Less accumulated depreciation, depletion and amortization | -9,323 | -8,947 |
Property, plant and equipment, net | 15,800 | 14,684 |
Other Assets | ' | ' |
Goodwill | 2,018 | 2,018 |
Regulatory assets | 2,837 | 4,235 |
Securitized regulatory assets | 231 | 413 |
Intangible assets | 122 | 135 |
Notes receivable | 102 | 112 |
Derivative assets | 27 | 39 |
Other | 198 | 197 |
Total Noncurrent Assets | 5,535 | 7,149 |
Total Assets | 25,935 | 26,339 |
Current Liabilities | ' | ' |
Accounts payable | 962 | 848 |
Accrued interest | 90 | 93 |
Dividends payable | 116 | 107 |
Short-term borrowings | 131 | 240 |
Current portion long-term debt, including capital leases | 898 | 817 |
Derivative liabilities | 195 | 125 |
Regulatory liabilities | 302 | 89 |
Other | 495 | 449 |
Total Current Liabilities | 3,189 | 2,768 |
Long-Term Debt (net of current portion) | ' | ' |
Mortgage bonds, notes and other | 6,618 | 6,220 |
Securitization bonds | 105 | 302 |
Junior subordinated debentures | 480 | 480 |
Capital lease obligations | 11 | 12 |
Total Long-Term Debt (net of current portion) | 7,214 | 7,014 |
Other Liabilities | ' | ' |
Deferred income taxes | 3,321 | 3,191 |
Regulatory liabilities | 862 | 1,031 |
Asset retirement obligations | 1,827 | 1,719 |
Unamortized investment tax credit | 47 | 56 |
Derivative liabilities | 43 | 26 |
Accrued pension liability | 653 | 1,498 |
Accrued postretirement liability | 350 | 1,160 |
Nuclear decommissioning | 178 | 159 |
Other | 297 | 306 |
Total Noncurrent Liabilities | 7,578 | 9,146 |
Equity | ' | ' |
Common stock, without par value, 400,000,000 shares authorized, 177,087,230 and 172,351,680 shares issued and outstanding, respectively | 3,907 | 3,587 |
Retained earnings | 4,150 | 3,944 |
Accumulated other comprehensive loss | -136 | -158 |
Total DTE Energy Company Equity | 7,921 | 7,373 |
Noncontrolling interests | 33 | 38 |
Total Equity | 7,954 | 7,411 |
Total Liabilities and Equity | $25,935 | $26,339 |
Consolidated_Statements_of_Fin1
Consolidated Statements of Financial Position (Parenthetical) (Parentheticals) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, except Share data, unless otherwise specified | ||
Allowance for doubtful accounts | $55 | $62 |
Common stock, par value | $0 | $0 |
Common stock, shares authorized | 400,000,000 | 400,000,000 |
Common stock, shares issued | 177,087,230 | 172,351,680 |
Common stock, shares outstanding | 177,087,230 | 172,351,680 |
Consolidated_Statements_of_Cas
Consolidated Statements of Cash Flows (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Operating Activities | ' | ' | ' |
Net Income | $668 | $618 | $720 |
Adjustments to reconcile net income to net cash from operating activities: | ' | ' | ' |
Depreciation, depletion and amortization | 1,094 | 1,018 | 995 |
Nuclear fuel amortization | 38 | 29 | 46 |
Allowance for equity funds used during construction | -15 | -13 | -6 |
Deferred income taxes | 164 | 47 | 220 |
Loss on sale of non-utility business | 0 | 83 | 0 |
Asset (gains) and losses, reserves and impairments, net | -8 | 1 | -21 |
Changes in assets and liabilities: | ' | ' | ' |
Accounts receivable, net | -154 | 52 | 71 |
Inventories | 123 | 35 | -129 |
Accounts payable | 14 | 40 | -23 |
Derivative assets and liabilities | 107 | 53 | -94 |
Accrued pension obligation | -644 | 280 | 432 |
Accrued postretirement obligation | -526 | -323 | 209 |
Regulatory assets and liabilities | 1,269 | 278 | -662 |
Other assets | -24 | 55 | 44 |
Other liabilities | 48 | -44 | 206 |
Net cash from operating activities | 2,154 | 2,209 | 2,008 |
Investing Activities | ' | ' | ' |
Plant and equipment expenditures b utility | -1,534 | -1,451 | -1,382 |
Plant and equipment expenditures b non-utility | -342 | -369 | -102 |
Proceeds from sale of non-utility business | 0 | 255 | 0 |
Proceeds from sale of assets | 36 | 38 | 18 |
Restricted cash for debt redemption, principally Securitization | -1 | 2 | -5 |
Acquisition, Net of Cash Acquired | 0 | -198 | 0 |
Proceeds from sale of nuclear decommissioning trust fund assets | 1,118 | 759 | 833 |
Investment in nuclear decommissioning trust funds | -1,134 | -764 | -850 |
Other | -49 | -41 | -72 |
Net cash used for investing activities | -1,906 | -1,769 | -1,560 |
Financing Activities | ' | ' | ' |
Issuance of long-term debt, net of issuance costs | 1,234 | 759 | 1,179 |
Redemption of long-term debt | -961 | -639 | -1,455 |
Short-term borrowings, net | -109 | -179 | 269 |
Issuance of common stock | 39 | 39 | 0 |
Repurchase of common stock | 0 | 0 | -18 |
Dividends on common stock | -445 | -407 | -389 |
Other | -19 | -16 | -31 |
Net cash used for financing activities | -261 | -443 | -445 |
Net Increase (Decrease) in Cash and Cash Equivalents | -13 | -3 | 3 |
Cash and Cash Equivalents at Beginning of Period | 65 | 68 | 65 |
Cash and Cash Equivalents at End of Period | 52 | 65 | 68 |
Supplemental disclosure of cash information | ' | ' | ' |
Cash paid (received) for interest (net of interest capitalized) | 418 | 438 | 485 |
Cash paid (received) for Income Taxes | 121 | 173 | -205 |
Supplemental disclosure of non-cash information | ' | ' | ' |
Common stock issued for employee benefit and compensation plans | 293 | 155 | 15 |
Plant and equipment expenditures in accounts payable | $329 | $235 | $212 |
Consolidated_Statements_of_Cha
Consolidated Statements of Changes in Equity (USD $) | Total | Common Stock [Member] | Retained Earnings | Accumulated Translation Adjustment [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member] | Accumulated Net Unrealized Investment Gain (Loss) [Member] | Accumulated Other Comprehensive Loss | Non-controlling Interest |
In Millions, except Share data | ||||||||
Beginning Balance at Dec. 31, 2010 | $6,767 | $3,440 | $3,431 | ' | ' | ' | ($149) | $45 |
Beginning Balance, shares at Dec. 31, 2010 | ' | 169,428,000 | ' | ' | ' | ' | ' | ' |
Net Income | 720 | ' | 711 | ' | ' | ' | ' | 9 |
Dividends declared on common stock | -392 | ' | -392 | ' | ' | ' | ' | ' |
Repurchase of common stock, Shares | ' | -1,184,000 | ' | ' | ' | ' | ' | ' |
Repurchase of Common Stock, Value | -58 | -58 | ' | ' | ' | ' | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | -9 | ' | ' | ' | -9 | ' | ' | ' |
Stock-based compensation, distributions to noncontrolling interests and other, Shares | ' | 1,003,000 | ' | ' | ' | ' | ' | ' |
Stock-based compensation, distributions to noncontrolling interests and other | 25 | 35 | ' | ' | ' | ' | ' | -10 |
Ending Balance at Dec. 31, 2011 | 7,053 | 3,417 | 3,750 | ' | ' | ' | -158 | 44 |
Ending Balance, shares at Dec. 31, 2011 | ' | 169,247,000 | ' | ' | ' | ' | ' | ' |
Net Income | 618 | ' | 610 | ' | ' | ' | ' | 8 |
Dividends declared on common stock | -414 | ' | -414 | ' | ' | ' | ' | ' |
Issuance of common stock, Shares | ' | 684,000 | ' | ' | ' | ' | ' | ' |
Issuance of common stock, Value | 39 | 39 | ' | ' | ' | ' | ' | ' |
Contribution of Common Stock to Pension Plan Shares | ' | 1,335,000 | ' | ' | ' | ' | ' | ' |
Contribution of Common Stock to Pension Plan | 80 | 80 | ' | ' | ' | ' | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | 0 | ' | ' | 1 | -2 | 1 | ' | ' |
Stock-based compensation, distributions to noncontrolling interests and other, Shares | ' | 1,086,000 | ' | ' | ' | ' | ' | ' |
Stock-based compensation, distributions to noncontrolling interests and other | 35 | 51 | -2 | ' | ' | ' | ' | -14 |
Ending Balance at Dec. 31, 2012 | 7,411 | 3,587 | 3,944 | ' | ' | ' | -158 | 38 |
Ending Balance, shares at Dec. 31, 2012 | 172,351,680 | 172,352,000 | ' | ' | ' | ' | ' | ' |
Net Income | 668 | ' | 661 | ' | ' | ' | ' | 7 |
Dividends declared on common stock | -454 | ' | -454 | ' | ' | ' | ' | ' |
Issuance of common stock, Shares | ' | 589,000 | ' | ' | ' | ' | ' | ' |
Issuance of common stock, Value | 39 | 39 | ' | ' | ' | ' | ' | ' |
Contribution of Common Stock to Pension Plan Shares | ' | 3,026,000 | ' | ' | ' | ' | ' | ' |
Contribution of Common Stock to Pension Plan | 200 | 200 | ' | ' | ' | ' | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | 22 | ' | ' | -2 | 22 | 2 | ' | ' |
Stock-based compensation, distributions to noncontrolling interests and other, Shares | ' | 1,120,000 | ' | ' | ' | ' | ' | ' |
Stock-based compensation, distributions to noncontrolling interests and other | 68 | 81 | -1 | ' | ' | ' | ' | -12 |
Ending Balance at Dec. 31, 2013 | $7,954 | $3,907 | $4,150 | ' | ' | ' | ($136) | $33 |
Ending Balance, shares at Dec. 31, 2013 | 177,087,230 | 177,087,000 | ' | ' | ' | ' | ' | ' |
Organization_and_Basis_of_Pres
Organization and Basis of Presentation (Notes) | 12 Months Ended | |||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||
Organization, Consolidation and Presentation of Financial Statements [Abstract] | ' | |||||||||||||||||||||||
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block] | ' | |||||||||||||||||||||||
ORGANIZATION AND BASIS OF PRESENTATION | ||||||||||||||||||||||||
Corporate Structure | ||||||||||||||||||||||||
DTE Energy owns the following businesses: | ||||||||||||||||||||||||
• | DTE Electric, an electric utility engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million customers in southeastern Michigan; | |||||||||||||||||||||||
• | DTE Gas, a natural gas utility engaged in the purchase, storage, transportation, distribution and sale of natural gas to approximately 1.2 million customers throughout Michigan and the sale of storage and transportation capacity; and | |||||||||||||||||||||||
• | Other businesses involved in 1) natural gas pipelines, gathering and storage; 2) power and industrial projects; and 3) energy marketing and trading operations. | |||||||||||||||||||||||
DTE Electric and DTE Gas are regulated by the MPSC. Certain activities of DTE Electric and DTE Gas, as well as various other aspects of businesses under DTE Energy are regulated by the FERC. In addition, the Company is regulated by other federal and state regulatory agencies including the NRC, the EPA, the MDEQ and CFTC. | ||||||||||||||||||||||||
References in this Report to “Company” or “DTE” are to DTE Energy and its subsidiaries, collectively. | ||||||||||||||||||||||||
Basis of Presentation | ||||||||||||||||||||||||
The accompanying Consolidated Financial Statements are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Company’s estimates. | ||||||||||||||||||||||||
Certain prior year balances were reclassified to match the current year’s financial statement presentation. Such revisions included an increase in the Consolidated Statements of Cash Flows line items for (i) Proceeds from sale of nuclear decommissioning trust funds, and (ii) Investment in nuclear decommissioning trust funds by $662 million and $753 million for the years ended December 31, 2012 and 2011, respectively. These revisions were needed to properly state the gross purchases and sales activity in the nuclear decommissioning trust fund for the respective years. The totals of Net cash used in investing activities for both 2012 and 2011 were unchanged by these revisions. The revisions noted above are not deemed material, individually or in the aggregate, to the prior period consolidated financial statements. | ||||||||||||||||||||||||
Principles of Consolidation | ||||||||||||||||||||||||
The Company consolidates all majority-owned subsidiaries and investments in entities in which it has controlling influence. Non-majority owned investments are accounted for using the equity method when the Company is able to influence the operating policies of the investee. When the Company does not influence the operating policies of an investee, the cost method is used. These consolidated financial statements also reflect the Company's proportionate interests in certain jointly owned utility plant. The Company eliminates all intercompany balances and transactions. | ||||||||||||||||||||||||
The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, the Company considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed. | ||||||||||||||||||||||||
Legal entities within the Company's Power and Industrial Projects segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with the Company retaining operational and customer default risk. These entities generally are VIEs and are consolidated when the Company is the primary beneficiary. In addition, we have interests in certain VIEs that we share control of all significant activities for those entities with our partners, and therefore are accounted for under the equity method. | ||||||||||||||||||||||||
The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of December 31, 2013, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of its variable interests through these long-term purchase contracts. | ||||||||||||||||||||||||
In 2001, DTE Electric financed a regulatory asset related to Fermi 2 and certain other regulatory assets through the sale of rate reduction bonds by a wholly-owned special purpose entity, Securitization. DTE Electric performs servicing activities including billing and collecting surcharge revenue for Securitization. This entity is a VIE and is consolidated by the Company. | ||||||||||||||||||||||||
The maximum risk exposure for consolidated VIEs is reflected on the Company's Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment and amounts which it has guaranteed. | ||||||||||||||||||||||||
The following table summarizes the major balance sheet items for consolidated VIEs as of December 31, 2013 and 2012. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. VIEs, in which the Company holds a majority voting interest and is the primary beneficiary, that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIE's obligations have been excluded from the table below. | ||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||
Securitization | Other | Total | Securitization | Other | Total | |||||||||||||||||||
(In millions) | ||||||||||||||||||||||||
ASSETS | ||||||||||||||||||||||||
Cash and cash equivalents | $ | — | $ | 12 | $ | 12 | $ | — | $ | 10 | $ | 10 | ||||||||||||
Restricted cash | 100 | 8 | 108 | 102 | 7 | 109 | ||||||||||||||||||
Accounts receivable | 34 | 16 | 50 | 34 | 7 | 41 | ||||||||||||||||||
Inventories | — | 118 | 118 | — | 141 | 141 | ||||||||||||||||||
Other current assets | — | 1 | 1 | — | 1 | 1 | ||||||||||||||||||
Property, plant and equipment | — | 99 | 99 | — | 93 | 93 | ||||||||||||||||||
Securitized regulatory assets | 231 | — | 231 | 413 | — | 413 | ||||||||||||||||||
Other assets | 4 | 8 | 12 | 7 | 11 | 18 | ||||||||||||||||||
$ | 369 | $ | 262 | $ | 631 | $ | 556 | $ | 270 | $ | 826 | |||||||||||||
LIABILITIES | ||||||||||||||||||||||||
Accounts payable and accrued current liabilities | $ | 7 | $ | 23 | $ | 30 | $ | 11 | $ | 14 | $ | 25 | ||||||||||||
Current portion long-term debt, including capital leases | 196 | 9 | 205 | 177 | 8 | 185 | ||||||||||||||||||
Current regulatory liabilities | 43 | — | 43 | 50 | — | 50 | ||||||||||||||||||
Other current liabilities | — | 4 | 4 | — | 4 | 4 | ||||||||||||||||||
Mortgage bonds, notes and other | — | 21 | 21 | — | 25 | 25 | ||||||||||||||||||
Securitization bonds | 105 | — | 105 | 302 | — | 302 | ||||||||||||||||||
Capital lease obligations | — | 7 | 7 | — | 11 | 11 | ||||||||||||||||||
Other long-term liabilities | 8 | 2 | 10 | 7 | 2 | 9 | ||||||||||||||||||
$ | 359 | $ | 66 | $ | 425 | $ | 547 | $ | 64 | $ | 611 | |||||||||||||
Amounts for non-consolidated VIEs as of December 31, 2013 and 2012 are as follows: | ||||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||
Other investments | $ | 141 | $ | 130 | ||||||||||||||||||||
Notes receivable | $ | 8 | $ | 6 | ||||||||||||||||||||
Significant_Accounting_Policie
Significant Accounting Policies (Notes) | 12 Months Ended | |||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||
Accounting Policies [Abstract] | ' | |||||||||||||||||||
Significant Accounting Policies | ' | |||||||||||||||||||
SIGNIFICANT ACCOUNTING POLICIES | ||||||||||||||||||||
Revenues | ||||||||||||||||||||
Revenues from the sale and delivery of electricity, and the sale, delivery and storage of natural gas are recognized as services are provided. DTE Electric and DTE Gas record revenues for electricity and gas provided but unbilled at the end of each month. Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are recorded on the Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors. | ||||||||||||||||||||
See Note 11 for further discussion of recovery mechanisms authorized by the MPSC. | ||||||||||||||||||||
Non-utility businesses recognize revenues as services are provided and products are delivered. See Note 4 for discussion of derivative contracts. | ||||||||||||||||||||
Other Income | ||||||||||||||||||||
Other income is recognized for non-operating income such as equity earnings, interest and dividends, allowance for funds using during construction and contract services. Power & Industrial Projects also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income is considered earned when refined coal is produced and tax credits are generated. Power & Industrial Projects recognized approximately $81 million, $63 million, and $15 million of Other income for the years ended December 31, 2013, 2012, and 2011, respectively. | ||||||||||||||||||||
Accounting for ISO Transactions | ||||||||||||||||||||
DTE Electric participates in the energy market through MISO. MISO requires that we submit hourly day-ahead, real- time and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time and FTR markets and net transactions across all MISO energy market locations. In any single hour DTE Electric records net purchases in Fuel, purchased power and gas and net sales in Operating revenues on the Consolidated Statements of Operations. | ||||||||||||||||||||
Energy Trading participates in the energy markets through various independent system operators and regional transmission organizations (ISOs and RTOs). These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the regional transmission organizations. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time and FTR markets. These transactions are related to trading contracts which are presented on a net basis in Operating Revenues in the Consolidated Statements of Operations. | ||||||||||||||||||||
DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience, and reconcile accruals to actual costs when invoices are received from MISO, and other ISOs and RTOs. | ||||||||||||||||||||
Comprehensive Income (Loss) | ||||||||||||||||||||
Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the year ended December 31, 2013 include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities, the Company’s interest in other comprehensive income of equity investees, which comprise the net unrealized gains and losses on investments, changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans, and foreign currency translation adjustments. | ||||||||||||||||||||
Changes in Accumulated Other Comprehensive Loss by Component (a) | ||||||||||||||||||||
For The Year Ended December 31, 2013 | ||||||||||||||||||||
Net | Net | Benefit | Foreign | Total | ||||||||||||||||
Unrealized | Unrealized | Obligations | Currency | |||||||||||||||||
Gain/(Loss) | Gain/(Loss) | (b) | Translation | |||||||||||||||||
on Derivatives | on Investments | |||||||||||||||||||
(In millions) | ||||||||||||||||||||
Beginning balances December 31, 2012 | $ | (4 | ) | $ | (8 | ) | $ | (148 | ) | $ | 2 | $ | (158 | ) | ||||||
Other comprehensive income (loss) before reclassifications | — | 2 | 13 | (2 | ) | 13 | ||||||||||||||
Amounts reclassified from accumulated other comprehensive income (loss) | — | — | 9 | — | 9 | |||||||||||||||
Net current-period other comprehensive income (loss) | — | 2 | 22 | (2 | ) | 22 | ||||||||||||||
Ending balances December 31, 2013 | $ | (4 | ) | $ | (6 | ) | $ | (126 | ) | $ | — | $ | (136 | ) | ||||||
______________________________________ | ||||||||||||||||||||
(a) | All amounts are net of tax. | |||||||||||||||||||
(b) | The amounts reclassified from accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 20). | |||||||||||||||||||
Cash Equivalents and Restricted Cash | ||||||||||||||||||||
Cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt, primarily Securitization bonds, and partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a current asset. | ||||||||||||||||||||
Receivables | ||||||||||||||||||||
Accounts receivable are primarily composed of trade receivables and unbilled revenue. Our accounts receivable are stated at net realizable value. | ||||||||||||||||||||
The allowance for doubtful accounts for DTE Electric and DTE Gas is generally calculated using the aging approach that utilizes rates developed in reserve studies. We establish an allowance for uncollectible accounts based on historical losses and management’s assessment of existing economic conditions, customer trends, and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. We assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated. | ||||||||||||||||||||
The customer allowance for doubtful accounts for our other businesses is calculated based on specific review of probable future collections based on receivable balances in excess of 30 days. | ||||||||||||||||||||
Unbilled revenues of $815 million and $686 million are included in customer accounts receivable at December 31, 2013 and 2012, respectively. | ||||||||||||||||||||
Notes Receivable | ||||||||||||||||||||
Notes receivable, or financing receivables, are primarily comprised of capital lease receivables and loans and are included in Notes receivable and Other current assets on the Company’s Consolidated Statements of Financial Position. | ||||||||||||||||||||
Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Company ceases accruing interest (nonaccrual status), considers a note receivable impaired, and establishes an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected in accordance with the contractual terms of the note receivable. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current. | ||||||||||||||||||||
In determining the allowance for credit losses for notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty’s ability to pay. In addition, the Company monitors the credit ratings of the counterparties from which we have notes receivable. | ||||||||||||||||||||
Inventories | ||||||||||||||||||||
The Company generally values inventory at average cost. | ||||||||||||||||||||
Natural gas inventory of $4 million and $37 million as of December 31, 2013 and 2012, respectively, at DTE Gas is determined using the last-in, first-out (LIFO) method. At December 31, 2013, the replacement cost of gas remaining in storage exceeded the LIFO cost by $170 million. At December 31, 2012, the replacement cost of gas remaining in storage exceeded the LIFO cost by $113 million. | ||||||||||||||||||||
Property, Retirement and Maintenance, and Depreciation, Depletion and Amortization | ||||||||||||||||||||
Property is stated at cost and includes construction-related labor, materials, overheads and, for utility property, an allowance for funds used during construction (AFUDC). The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred, except for Fermi 2. | ||||||||||||||||||||
Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC. | ||||||||||||||||||||
Non-utility property is depreciated over its estimated useful life using the straight-line and units of production methods. | ||||||||||||||||||||
Depreciation, depletion and amortization expense also includes the amortization of certain regulatory assets. | ||||||||||||||||||||
Approximately $26 million and $12 million of expenses related to Fermi 2 refueling outages were accrued at December 31, 2013 and 2012, respectively. Amounts are accrued on a pro-rata basis, generally over an 18-month period, that coincides with scheduled refueling outages at Fermi 2. This accrual of outage costs matches the regulatory recovery of these costs in rates set by the MPSC. See Note 11. | ||||||||||||||||||||
The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas in the Consolidated Statements of Operations and is recorded using the units-of-production method. | ||||||||||||||||||||
Long-Lived Assets | ||||||||||||||||||||
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected discounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell. | ||||||||||||||||||||
Intangible Assets | ||||||||||||||||||||
The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below: | ||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||
2013 | 2012 | |||||||||||||||||||
(In millions) | ||||||||||||||||||||
Emission allowances | $ | 2 | $ | 6 | ||||||||||||||||
Renewable energy credits | 51 | 44 | ||||||||||||||||||
Contract intangible assets | 126 | 139 | ||||||||||||||||||
179 | 189 | |||||||||||||||||||
Less accumulated amortization | 45 | 34 | ||||||||||||||||||
Intangible assets, net | 134 | 155 | ||||||||||||||||||
Less current intangible assets | 12 | 20 | ||||||||||||||||||
$ | 122 | $ | 135 | |||||||||||||||||
Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business. The Company amortizes contract intangible assets on a straight-line basis over the expected period of benefit, ranging from 1 to 28 years. Intangible assets amortization expense was $14 million in 2013, $6 million in 2012 and $5 million in 2011. | ||||||||||||||||||||
The following table summarizes the estimated amortization expense expected to be recognized during each year through 2018: | ||||||||||||||||||||
Estimated amortization expense | (In millions) | |||||||||||||||||||
2014 | $ | 13 | ||||||||||||||||||
2015 | $ | 12 | ||||||||||||||||||
2016 | $ | 11 | ||||||||||||||||||
2017 | $ | 8 | ||||||||||||||||||
2018 | $ | 8 | ||||||||||||||||||
Excise and Sales Taxes | ||||||||||||||||||||
The Company records the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Consolidated Statements of Operations. | ||||||||||||||||||||
Deferred Debt Costs | ||||||||||||||||||||
The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. In accordance with MPSC regulations applicable to the Company’s electric and gas utilities, the unamortized discount, premium and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium and expense on early redemptions of debt associated with non-utility operations are charged to earnings. | ||||||||||||||||||||
Investments in Debt and Equity Securities | ||||||||||||||||||||
The Company generally classifies investments in debt and equity securities as either trading or available-for-sale and has recorded such investments at market value with unrealized gains or losses included in earnings or in other comprehensive income or loss, respectively. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to regulatory assets or liabilities, due to a recovery mechanism from customers. The Company’s equity investments are reviewed for impairment each reporting period. If the assessment indicates that the impairment is other than temporary, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 3. | ||||||||||||||||||||
Government Grants | ||||||||||||||||||||
Grants are recognized when there is reasonable assurance that the grant will be received and that any conditions associated with the grant will be met. When grants are received related to Property, Plant and Equipment, the Company reduces the cost of the assets on the Consolidated Statements of Financial Position, resulting in lower depreciation expense over the life of the associated asset. Grants received related to expenses are reflected as a reduction of the associated expense in the period in which the expense is incurred. | ||||||||||||||||||||
DTE Energy Foundation | ||||||||||||||||||||
Charitable contributions to the DTE Energy Foundation were $18 million, $21 million, and $21 million for the years ended December 31, 2013, 2012 and 2011, respectively. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations and does not serve a direct business or political purpose of DTE. | ||||||||||||||||||||
Other Accounting Policies | ||||||||||||||||||||
See the following notes for other accounting policies impacting the Company’s consolidated financial statements: | ||||||||||||||||||||
Note | Title | |||||||||||||||||||
3 | Fair Value | |||||||||||||||||||
4 | Financial and Other Derivative Instruments | |||||||||||||||||||
10 | Asset Retirement Obligations | |||||||||||||||||||
11 | Regulatory Matters | |||||||||||||||||||
12 | Income Taxes | |||||||||||||||||||
21 | Stock-based Compensation |
Fair_Value_Notes
Fair Value (Notes) | 12 Months Ended | |||||||||||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | ' | |||||||||||||||||||||||||||||||||||||||
Fair Value | ' | |||||||||||||||||||||||||||||||||||||||
FAIR VALUE | ||||||||||||||||||||||||||||||||||||||||
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated or generally unobservable inputs. The Company makes certain assumptions it believes that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Company and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 2013 and 2012. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs. | ||||||||||||||||||||||||||||||||||||||||
A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Company classifies fair value balances based on the fair value hierarchy defined as follows: | ||||||||||||||||||||||||||||||||||||||||
• | Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date. | |||||||||||||||||||||||||||||||||||||||
• | Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data. | |||||||||||||||||||||||||||||||||||||||
• | Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints. | |||||||||||||||||||||||||||||||||||||||
The following table presents assets and liabilities measured and recorded at fair value on a recurring basis as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Netting (a) | Net Balance | Level 1 | Level 2 | Level 3 | Netting (a) | Net Balance | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Assets: | ||||||||||||||||||||||||||||||||||||||||
Cash equivalents (b) | $ | 10 | $ | 115 | $ | — | $ | — | $ | 125 | $ | — | $ | 123 | $ | — | $ | — | $ | 123 | ||||||||||||||||||||
Nuclear decommissioning trusts | 779 | 412 | — | — | 1,191 | 694 | 343 | — | — | 1,037 | ||||||||||||||||||||||||||||||
Other investments (c) (d) | 92 | 44 | — | — | 136 | 66 | 44 | — | — | 110 | ||||||||||||||||||||||||||||||
Derivative assets: | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | 273 | 89 | 34 | (382 | ) | 14 | 555 | 66 | 24 | (605 | ) | 40 | ||||||||||||||||||||||||||||
Electricity | — | 261 | 139 | (291 | ) | 109 | — | 226 | 134 | (258 | ) | 102 | ||||||||||||||||||||||||||||
Other | 33 | 1 | 3 | (34 | ) | 3 | 6 | 3 | 2 | (6 | ) | 5 | ||||||||||||||||||||||||||||
Total derivative assets | 306 | 351 | 176 | (707 | ) | 126 | 561 | 295 | 160 | (869 | ) | 147 | ||||||||||||||||||||||||||||
Total | $ | 1,187 | $ | 922 | $ | 176 | $ | (707 | ) | $ | 1,578 | $ | 1,321 | $ | 805 | $ | 160 | $ | (869 | ) | $ | 1,417 | ||||||||||||||||||
Liabilities: | ||||||||||||||||||||||||||||||||||||||||
Derivative liabilities: | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | $ | (277 | ) | $ | (140 | ) | $ | (86 | ) | $ | 395 | $ | (108 | ) | $ | (526 | ) | $ | (73 | ) | $ | (62 | ) | $ | 605 | $ | (56 | ) | ||||||||||||
Electricity | — | (272 | ) | (126 | ) | 269 | (129 | ) | — | (240 | ) | (111 | ) | 258 | (93 | ) | ||||||||||||||||||||||||
Other | (32 | ) | (2 | ) | — | 34 | — | (6 | ) | (1 | ) | — | 6 | (1 | ) | |||||||||||||||||||||||||
Other derivative contracts (f) | — | (1 | ) | — | — | (1 | ) | — | (1 | ) | — | — | (1 | ) | ||||||||||||||||||||||||||
Total derivative liabilities | (309 | ) | (415 | ) | (212 | ) | 698 | (238 | ) | (532 | ) | (315 | ) | (173 | ) | 869 | (151 | ) | ||||||||||||||||||||||
Total | $ | (309 | ) | $ | (415 | ) | $ | (212 | ) | $ | 698 | $ | (238 | ) | $ | (532 | ) | $ | (315 | ) | $ | (173 | ) | $ | 869 | $ | (151 | ) | ||||||||||||
Net Assets (liabilities) at the end of the period | $ | 878 | $ | 507 | $ | (36 | ) | $ | (9 | ) | $ | 1,340 | $ | 789 | $ | 490 | $ | (13 | ) | $ | — | $ | 1,266 | |||||||||||||||||
Assets: | ||||||||||||||||||||||||||||||||||||||||
Current | $ | 277 | $ | 400 | $ | 139 | $ | (592 | ) | $ | 224 | $ | 493 | $ | 372 | $ | 120 | $ | (754 | ) | $ | 231 | ||||||||||||||||||
Noncurrent (e) | 910 | 522 | 37 | (115 | ) | 1,354 | 828 | 433 | 40 | (115 | ) | 1,186 | ||||||||||||||||||||||||||||
Total Assets | $ | 1,187 | $ | 922 | $ | 176 | $ | (707 | ) | $ | 1,578 | $ | 1,321 | $ | 805 | $ | 160 | $ | (869 | ) | $ | 1,417 | ||||||||||||||||||
Liabilities: | ||||||||||||||||||||||||||||||||||||||||
Current | $ | (268 | ) | $ | (328 | ) | $ | (177 | ) | $ | 578 | $ | (195 | ) | $ | (466 | ) | $ | (269 | ) | $ | (144 | ) | $ | 754 | $ | (125 | ) | ||||||||||||
Noncurrent | (41 | ) | (87 | ) | (35 | ) | 120 | (43 | ) | (66 | ) | (46 | ) | (29 | ) | 115 | (26 | ) | ||||||||||||||||||||||
Total Liabilities | $ | (309 | ) | $ | (415 | ) | $ | (212 | ) | $ | 698 | $ | (238 | ) | $ | (532 | ) | $ | (315 | ) | $ | (173 | ) | $ | 869 | $ | (151 | ) | ||||||||||||
Net Assets (liabilities) at the end of the period | $ | 878 | $ | 507 | $ | (36 | ) | $ | (9 | ) | $ | 1,340 | $ | 789 | $ | 490 | $ | (13 | ) | $ | — | $ | 1,266 | |||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||||||||||||||
(a) | Amounts represent the impact of master netting agreements that allow the Company to net gain and loss positions and cash collateral held or placed with the same counterparties. | |||||||||||||||||||||||||||||||||||||||
(b) | At December 31, 2013, available-for-sale securities of $125 million included $109 million and $16 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. At December 31, 2012, available-for-sale securities of $123 million, included $109 million and $14 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. | |||||||||||||||||||||||||||||||||||||||
(c) | Excludes cash surrender value of life insurance investments. | |||||||||||||||||||||||||||||||||||||||
(d) | Available-for-sale equity securities of $7 million at December 31, 2013 and $5 million at December 31, 2012 are included in Other investments on the Consolidated Statements of Financial Position. | |||||||||||||||||||||||||||||||||||||||
(e) | Includes $136 million and $110 million of Other investments that are included in the Consolidated Statements of Financial Position in Other investments at December 31, 2013 and 2012, respectively. | |||||||||||||||||||||||||||||||||||||||
(f) | Includes Interest rate contracts and Foreign currency exchange contracts. | |||||||||||||||||||||||||||||||||||||||
Cash Equivalents | ||||||||||||||||||||||||||||||||||||||||
Cash equivalents include investments with maturities of three months or less when purchased. The cash equivalents shown in the fair value table are comprised of short-term investments and money market funds. The fair values of the shares in these investments are based upon observable market prices for similar securities and, therefore, have been categorized as Level 2 in the fair value hierarchy. | ||||||||||||||||||||||||||||||||||||||||
Nuclear Decommissioning Trusts and Other Investments | ||||||||||||||||||||||||||||||||||||||||
The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds which hold exchange-traded equity or debt securities are valued based on the underlying securities, using quoted prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by the Company's Trust Investments Department which reports to the Company's Vice President and Treasurer. | ||||||||||||||||||||||||||||||||||||||||
Derivative Assets and Liabilities | ||||||||||||||||||||||||||||||||||||||||
Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. DTE Energy considers the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality and basis differential factors. DTE Energy monitors the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. DTE Energy has obtained an understanding of how these prices are derived. Additionally, DTE Energy selectively corroborates the fair value of its transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Company has established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of our forward price curves has been assigned to our Risk Management Department, which is separate and distinct from the trading functions within the Company. | ||||||||||||||||||||||||||||||||||||||||
The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||||||||||
Natural Gas | Electricity | Other | Total | Natural Gas | Electricity | Other | Total | |||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Net Assets (Liabilities) as of December 31 | $ | (38 | ) | $ | 23 | $ | 2 | $ | (13 | ) | $ | 6 | $ | 32 | $ | 6 | $ | 44 | ||||||||||||||||||||||
Transfers into Level 3 | 1 | — | — | 1 | 1 | — | — | 1 | ||||||||||||||||||||||||||||||||
Total gains (losses): | ||||||||||||||||||||||||||||||||||||||||
Included in earnings | (32 | ) | 75 | — | 43 | (41 | ) | 101 | — | 60 | ||||||||||||||||||||||||||||||
Recorded in regulatory assets/liabilities | — | — | 5 | 5 | — | — | 15 | 15 | ||||||||||||||||||||||||||||||||
Purchases, issuances and settlements: | ||||||||||||||||||||||||||||||||||||||||
Purchases | (8 | ) | 1 | — | (7 | ) | — | 2 | — | 2 | ||||||||||||||||||||||||||||||
Issuances | — | (1 | ) | — | (1 | ) | — | — | — | — | ||||||||||||||||||||||||||||||
Settlements | 25 | (85 | ) | (4 | ) | (64 | ) | (4 | ) | (112 | ) | (19 | ) | (135 | ) | |||||||||||||||||||||||||
Net Assets (Liabilities) as of December 31 | $ | (52 | ) | $ | 13 | $ | 3 | $ | (36 | ) | $ | (38 | ) | $ | 23 | $ | 2 | $ | (13 | ) | ||||||||||||||||||||
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations | $ | (49 | ) | $ | 48 | $ | — | $ | (1 | ) | $ | (33 | ) | $ | 91 | $ | — | $ | 58 | |||||||||||||||||||||
Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period. The following table shows transfers between the levels of the fair value hierarchy for the years ended December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Level 1 | Level 2 | Level 3 | |||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Transfers into Level 1 from | $ N/A | $ | — | $ | — | $ N/A | $ | — | $ | — | ||||||||||||||||||||||||||||||
Transfers into Level 2 from | — | N/A | — | — | N/A | — | ||||||||||||||||||||||||||||||||||
Transfers into Level 3 from | — | 1 | N/A | — | 1 | N/A | ||||||||||||||||||||||||||||||||||
The following table presents the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts | Derivative Assets | Derivative Liabilities | Valuation Techniques | Unobservable Input | Range | Weighted Average | ||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | $ | 34 | $ | (86 | ) | Discounted Cash Flow | Forward basis price (per MMBtu) | $ | (0.88 | ) | — | $ | 5.07 | /MMBtu | $ | (0.16 | )/MMBtu | |||||||||||||||||||||||
Electricity | $ | 139 | $ | (126 | ) | Discounted Cash Flow | Forward basis price (per MWh) | $ | (7 | ) | — | $ | 15 | /MWh | $ | 3 | /MWh | |||||||||||||||||||||||
31-Dec-12 | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts | Derivative Assets | Derivative Liabilities | Valuation Techniques | Unobservable Input | Range | Weighted Average | ||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | $ | 24 | $ | (62 | ) | Discounted Cash Flow | Forward basis price (per MMBtu) | $ | (0.63 | ) | — | $ | 1.95 | /MMBtu | $ | 0.03 | /MMBtu | |||||||||||||||||||||||
Electricity | $ | 134 | $ | (111 | ) | Discounted Cash Flow | Forward basis price (per MWh) | $ | (2 | ) | — | $ | 16 | /MWh | $ | 3 | /MWh | |||||||||||||||||||||||
The unobservable inputs used in the fair value measurement of the electricity and natural gas commodity types consists of inputs that are less observable due in part to lack of available broker quotes, supported by little, if any, market activity at the measurement date or are based on internally developed models. Certain basis prices (i.e., the difference in pricing between two locations) included in the valuation of natural gas and electricity contracts were deemed unobservable. | ||||||||||||||||||||||||||||||||||||||||
The inputs listed above would have a direct impact on the fair values of the above security types if they were adjusted. A significant increase (decrease) in the basis price would result in a higher (lower) fair value for long positions, with offsetting impacts to short positions. | ||||||||||||||||||||||||||||||||||||||||
Fair Value of Financial Instruments | ||||||||||||||||||||||||||||||||||||||||
The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. DTE Energy has obtained an understanding of how the fair values are derived. DTE Energy also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are estimated using discounted cash flow techniques that incorporate market interest rates as well assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures are determined by DTE Energy's Treasury Department which reports to the Company's Vice President and Treasurer. | ||||||||||||||||||||||||||||||||||||||||
The following table presents the carrying amount and fair value of financial instruments as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||||||||||
Carrying | Fair Value | Carrying | Fair Value | |||||||||||||||||||||||||||||||||||||
Amount | Level 1 | Level 2 | Level 3 | Amount | Level 1 | Level 2 | Level 3 | |||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Notes receivable, excluding capital leases | $ | 41 | $ | — | $ | — | $ | 41 | $ | 39 | $ | — | $ | — | $ | 39 | ||||||||||||||||||||||||
Dividends payable | $ | 116 | $ | 116 | $ | — | $ | — | $ | 107 | $ | 107 | $ | — | $ | — | ||||||||||||||||||||||||
Short-term borrowings | $ | 131 | $ | — | $ | 131 | $ | — | $ | 240 | $ | — | $ | 240 | $ | — | ||||||||||||||||||||||||
Long-term debt | $ | 8,094 | $ | 425 | $ | 7,551 | $ | 499 | $ | 7,813 | $ | 507 | $ | 7,453 | $ | 933 | ||||||||||||||||||||||||
See Note 4 for further fair value information on financial and derivative instruments. | ||||||||||||||||||||||||||||||||||||||||
Nuclear Decommissioning Trust Funds | ||||||||||||||||||||||||||||||||||||||||
DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. This obligation is reflected as an asset retirement obligation on the Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates. See Note 10. | ||||||||||||||||||||||||||||||||||||||||
The following table summarizes the fair value of the nuclear decommissioning trust fund assets: | ||||||||||||||||||||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Fermi 2 | $ | 1,172 | $ | 1,021 | ||||||||||||||||||||||||||||||||||||
Fermi 1 | 3 | 3 | ||||||||||||||||||||||||||||||||||||||
Low level radioactive waste | 16 | 13 | ||||||||||||||||||||||||||||||||||||||
Total | $ | 1,191 | $ | 1,037 | ||||||||||||||||||||||||||||||||||||
The costs of securities sold are determined on the basis of specific identification. The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds: | ||||||||||||||||||||||||||||||||||||||||
Year Ended December 31 | ||||||||||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Realized gains | $ | 83 | $ | 37 | $ | 46 | ||||||||||||||||||||||||||||||||||
Realized losses | $ | (41 | ) | $ | (31 | ) | $ | (38 | ) | |||||||||||||||||||||||||||||||
Proceeds from sales of securities | $ | 1,118 | $ | 759 | $ | 833 | ||||||||||||||||||||||||||||||||||
Realized gains and losses from the sale of securities for the Fermi 2 and the low level radioactive waste funds are recorded to the Regulatory asset and Nuclear decommissioning liability. The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||||||||||
Fair | Unrealized | Fair | Unrealized | |||||||||||||||||||||||||||||||||||||
Value | Gains | Value | Gains | |||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Equity securities | $ | 730 | $ | 201 | $ | 631 | $ | 122 | ||||||||||||||||||||||||||||||||
Debt securities | 442 | 12 | 399 | 27 | ||||||||||||||||||||||||||||||||||||
Cash and cash equivalents | 19 | — | 7 | — | ||||||||||||||||||||||||||||||||||||
$ | 1,191 | $ | 213 | $ | 1,037 | $ | 149 | |||||||||||||||||||||||||||||||||
At December 31, 2013, investments in the nuclear decommissioning trust funds consisted of approximately 61% in publicly traded equity securities, 37% in fixed debt instruments and 2% in cash equivalents. At December 31, 2012, investments in the nuclear decommissioning trust funds consisted of approximately 61% in publicly traded equity securities, 38% in fixed debt instruments and 1% in cash equivalents. | ||||||||||||||||||||||||||||||||||||||||
The debt securities at December 31, 2013 and 2012 had an average maturity of approximately 7 and 6 years, respectively. Securities held in the nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other than temporary impairments. | ||||||||||||||||||||||||||||||||||||||||
Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset. DTE Electric recognized $31 million and $44 million of unrealized losses as Regulatory assets at December 31, 2013 and 2012, respectively. Since the decommissioning of Fermi 1 is funded by DTE Electric rather than through a regulatory recovery mechanism, there is no corresponding regulatory asset treatment. Therefore, unrealized losses incurred by the Fermi 1 trust are recognized in earnings immediately. There were no unrealized losses recognized in 2013, 2012 and 2011 for Fermi 1. | ||||||||||||||||||||||||||||||||||||||||
Other Securities | ||||||||||||||||||||||||||||||||||||||||
At December 31, 2013 and 2012, the securities were comprised primarily of money-market and equity securities. During the years ended December 31, 2013 and 2012, no amounts of unrealized losses on available-for-sale securities were reclassified out of other comprehensive income and realized into net income for the periods. Gains related to trading securities held at December 31, 2013, 2012, and 2011 were $22 million, $11 million and $4 million, respectively. |
Financial_and_Other_Derivative
Financial and Other Derivative Instruments (Notes) | 12 Months Ended | |||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||
Derivative Instruments and Hedges, Assets [Abstract] | ' | |||||||||||||||||||||||||||||||
Financial and Other Derivative Instruments | ' | |||||||||||||||||||||||||||||||
FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS | ||||||||||||||||||||||||||||||||
The Company recognizes all derivatives at their fair value as Derivative assets or liabilities on the Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge), or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in the fair value are recognized in earnings each period. | ||||||||||||||||||||||||||||||||
The Company’s primary market risk exposure is associated with commodity prices, credit and interest rates. The Company has risk management policies to monitor and manage market risks. The Company uses derivative instruments to manage some of the exposure. The Company uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include power, natural gas, oil and certain coal forwards, futures, options and swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits and natural gas storage assets. | ||||||||||||||||||||||||||||||||
Electric — DTE Electric generates, purchases, distributes and sells electricity. DTE Electric uses forward energy contracts to manage changes in the price of electricity and fuel. Substantially all of these contracts meet the normal purchases and sales exemption and are therefore accounted for under the accrual method. Other derivative contracts are recoverable through the PSCR mechanism when settled. This results in the deferral of unrealized gains and losses as Regulatory assets or liabilities until realized. | ||||||||||||||||||||||||||||||||
Gas — DTE Gas purchases, stores, transports, distributes and sells natural gas and sells storage and transportation capacity. DTE Gas has fixed-priced contracts for portions of its expected gas supply requirements through 2016. Substantially all of these contracts meet the normal purchases and sales exemption and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method. | ||||||||||||||||||||||||||||||||
Gas Storage and Pipelines — This segment is primarily engaged in services related to the transportation and storage of natural gas. Primarily fixed-priced contracts are used in the marketing and management of transportation and storage services. Generally these contracts are not derivatives and are therefore accounted for under the accrual method. | ||||||||||||||||||||||||||||||||
Power and Industrial Projects — This segment manages and operates energy and pulverized coal projects, coke batteries, reduced emissions fuel projects, landfill gas recovery and power generation assets. Primarily fixed-price contracts are used in the marketing and management of the segment assets. These contracts are generally not derivatives and are therefore accounted for under the accrual method. | ||||||||||||||||||||||||||||||||
Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, coal, natural gas physical products and energy financial instruments, and provides energy and asset management services utilizing energy commodity derivative instruments. Forwards, futures, options and swap agreements are used to manage exposure to the risk of market price and volume fluctuations in its operations. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met. | ||||||||||||||||||||||||||||||||
Energy Trading — Foreign Currency Exchange Risk — Energy Trading has foreign currency exchange forward contracts to economically hedge fixed Canadian dollar commitments existing under natural gas and power purchase and sale contracts and natural gas transportation contracts. The Company enters into these contracts to mitigate price volatility with respect to fluctuations of the Canadian dollar relative to the U.S. dollar. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met. | ||||||||||||||||||||||||||||||||
Corporate and Other — Interest Rate Risk — The Company uses interest rate swaps, treasury locks and other derivatives to hedge the risk associated with interest rate market volatility. In 2004 and 2000, the Company entered into a series of interest rate derivatives to limit its sensitivity to market interest rate risk associated with the issuance of long-term debt. Such instruments were designated as cash flow hedges. The Company subsequently issued long-term debt and terminated these hedges at a cost that is included in Other comprehensive loss. Amounts recorded in Other comprehensive loss will be reclassified to interest expense through 2033. In 2014, the Company estimates reclassifying less than $1 million of losses to earnings. | ||||||||||||||||||||||||||||||||
Credit Risk — The utility and non-utility businesses are exposed to credit risk if customers or counterparties do not comply with their contractual obligations. The Company maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, credit rating, collateral requirements or other credit enhancements such as letters of credit or guarantees. The Company generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. The Company maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on the Company’s credit policies and its December 31, 2013 and 2012 provision for credit losses, the Company’s exposure to counterparty nonperformance is not expected to have a material adverse effect on the Company’s financial statements. | ||||||||||||||||||||||||||||||||
Derivative Activities | ||||||||||||||||||||||||||||||||
The Company manages its mark-to-market (MTM) risk on a portfolio basis based upon the delivery period of its contracts and the individual components of the risks within each contract. Accordingly, it records and manages the energy purchase and sale obligations under its contracts in separate components based on the commodity (e.g. electricity or natural gas), the product (e.g. electricity for delivery during peak or off-peak hours), the delivery location (e.g. by region), the risk profile (e.g. forward or option), and the delivery period (e.g. by month and year). The following describes the categories of activities represented by their operating characteristics and key risks: | ||||||||||||||||||||||||||||||||
• | Asset Optimization — Represents derivative activity associated with assets owned and contracted by DTE Energy, including forward natural gas purchases and sales, natural gas transportation and storage capacity. Changes in the value of derivatives in this category typically economically offset changes in the value of underlying non-derivative positions, which do not qualify for fair value accounting. The difference in accounting treatment of derivatives in this category and the underlying non-derivative positions can result in significant earnings volatility. | |||||||||||||||||||||||||||||||
• | Marketing and Origination — Represents derivative activity transacted by originating substantially hedged positions with wholesale energy marketers, producers, end users, utilities, retail aggregators and alternative energy suppliers. | |||||||||||||||||||||||||||||||
• | Fundamentals Based Trading — Represents derivative activity transacted with the intent of taking a view, capturing market price changes, or putting capital at risk. This activity is speculative in nature as opposed to hedging an existing exposure. | |||||||||||||||||||||||||||||||
• | Other — Includes derivative activity at DTE Electric related to FTRs. Changes in the value of derivative contracts at DTE Electric are recorded as Derivative Assets or Liabilities, with an offset to Regulatory Assets or Liabilities as the settlement value of these contracts will be included in the PSCR mechanism when realized. | |||||||||||||||||||||||||||||||
The following tables present the fair value of derivative instruments as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Derivative Assets | Derivative Liabilities | Derivative Assets | Derivative Liabilities | |||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Derivatives designated as hedging instruments: | ||||||||||||||||||||||||||||||||
Interest rate contracts | $ | — | $ | — | $ | — | $ | (1 | ) | |||||||||||||||||||||||
Derivatives not designated as hedging instruments: | ||||||||||||||||||||||||||||||||
Foreign currency exchange contracts | $ | — | $ | (1 | ) | $ | — | $ | — | |||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | 396 | (503 | ) | 645 | (661 | ) | ||||||||||||||||||||||||||
Electricity | 400 | (398 | ) | 360 | (351 | ) | ||||||||||||||||||||||||||
Other | 37 | (34 | ) | 11 | (7 | ) | ||||||||||||||||||||||||||
Total derivatives not designated as hedging instruments: | $ | 833 | $ | (936 | ) | $ | 1,016 | $ | (1,019 | ) | ||||||||||||||||||||||
Total derivatives: | ||||||||||||||||||||||||||||||||
Current | $ | 691 | $ | (773 | ) | $ | 862 | $ | (879 | ) | ||||||||||||||||||||||
Noncurrent | 142 | (163 | ) | 154 | (141 | ) | ||||||||||||||||||||||||||
Total derivatives | $ | 833 | $ | (936 | ) | $ | 1,016 | $ | (1,020 | ) | ||||||||||||||||||||||
Certain of the Company's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, the Company offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces the Company's total assets and liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in accounts receivable and accounts payable as collateral paid or received, respectively. | ||||||||||||||||||||||||||||||||
The Company also provides and receives collateral in the form of letters of credit which can be offset against net derivative assets and liabilities as well as accounts receivable and payable. The Company had issued letters of credit of approximately $19 million and $63 million at December 31, 2013 and 2012, respectively, which could be used to offset our net derivative liabilities. Letters of credit received from third parties which could be used to offset our net derivative assets were not material for the periods presented. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in the Consolidated Statements of Financial Position. | ||||||||||||||||||||||||||||||||
For contracts with certain clearing agents the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a derivative asset or liability or 2) an account receivable or payable. Other than certain clearing agents, accounts receivable and accounts payable that are subject to netting arrangements have not been offset against the fair value of derivative assets and liabilities. Certain contracts that have netting arrangements have not been offset in the Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below. | ||||||||||||||||||||||||||||||||
As of December 31, 2013, the total cash collateral posted, net of cash collateral received, was $12 million. As of December 31, 2012, the total cash collateral received, net of cash collateral posted, was $20 million. As of December 31, 2013, derivative assets and derivative liabilities are shown net of cash collateral of $26 million and $17 million, respectively. There was no cash collateral related to unrealized positions to net against derivative assets and liabilities as of December 31, 2012. The Company recorded cash collateral paid of $34 million and cash collateral received of $13 million not related to unrealized derivative positions as of December 31, 2013. The Company recorded cash collateral paid of $4 million and cash collateral received of $24 million not related to unrealized derivative positions as of December 31, 2012. These amounts are included in accounts receivable and accounts payable and are recorded net by counterparty. | ||||||||||||||||||||||||||||||||
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Gross Amounts of Recognized Assets (Liabilities) | Gross Amounts Offset in the Consolidated Statements of Financial Position | Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position | Gross Amounts of Recognized Assets (Liabilities) | Gross Amounts Offset in the Consolidated Statements of Financial Position | Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position | |||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Derivative assets: | ||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | $ | 396 | $ | (382 | ) | $ | 14 | $ | 645 | $ | (605 | ) | $ | 40 | ||||||||||||||||||
Electricity | 400 | (291 | ) | 109 | 360 | (258 | ) | 102 | ||||||||||||||||||||||||
Other | 37 | (34 | ) | 3 | 11 | (6 | ) | 5 | ||||||||||||||||||||||||
Total derivative assets | $ | 833 | $ | (707 | ) | $ | 126 | $ | 1,016 | $ | (869 | ) | $ | 147 | ||||||||||||||||||
Derivative liabilities: | ||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | $ | (503 | ) | $ | 395 | $ | (108 | ) | $ | (661 | ) | $ | 605 | $ | (56 | ) | ||||||||||||||||
Electricity | (398 | ) | 269 | (129 | ) | (351 | ) | 258 | (93 | ) | ||||||||||||||||||||||
Other | (34 | ) | 34 | — | (7 | ) | 6 | (1 | ) | |||||||||||||||||||||||
Other derivative liabilities | (1 | ) | — | (1 | ) | (1 | ) | — | (1 | ) | ||||||||||||||||||||||
Total derivative liabilities | $ | (936 | ) | $ | 698 | $ | (238 | ) | $ | (1,020 | ) | $ | 869 | $ | (151 | ) | ||||||||||||||||
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Derivative Assets | Derivative Liabilities | Derivative Assets | Derivative Liabilities | |||||||||||||||||||||||||||||
Current | Noncurrent | Current | Noncurrent | Current | Noncurrent | Current | Noncurrent | |||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Reconciliation of derivative instruments to Consolidated Statements of Financial Position: | ||||||||||||||||||||||||||||||||
Total fair value of derivatives | $ | 691 | $ | 142 | $ | (773 | ) | $ | (163 | ) | $ | 862 | $ | 154 | $ | (879 | ) | $ | (141 | ) | ||||||||||||
Counterparty netting | (566 | ) | (115 | ) | 566 | 115 | (754 | ) | (115 | ) | 754 | 115 | ||||||||||||||||||||
Collateral adjustment | (26 | ) | — | 12 | 5 | — | — | — | — | |||||||||||||||||||||||
Total derivatives as reported | $ | 99 | $ | 27 | $ | (195 | ) | $ | (43 | ) | $ | 108 | $ | 39 | $ | (125 | ) | $ | (26 | ) | ||||||||||||
The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for years ended December 31, 2013 and 2012 is as follows: | ||||||||||||||||||||||||||||||||
Location of Gain | Gain (Loss) | |||||||||||||||||||||||||||||||
(Loss) Recognized | Recognized in | |||||||||||||||||||||||||||||||
in Income on Derivatives | Income on | |||||||||||||||||||||||||||||||
Derivatives for | ||||||||||||||||||||||||||||||||
Years Ended | ||||||||||||||||||||||||||||||||
December 31 | ||||||||||||||||||||||||||||||||
Derivatives not Designated as Hedging Instruments | 2013 | 2012 | ||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Foreign currency exchange contracts | Operating Revenue | $ | (1 | ) | $ | — | ||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | Operating Revenue | (48 | ) | (29 | ) | |||||||||||||||||||||||||||
Natural Gas | Fuel, purchased power and gas | (44 | ) | 25 | ||||||||||||||||||||||||||||
Electricity | Operating Revenue | 82 | 64 | |||||||||||||||||||||||||||||
Other | Operating Revenue | — | 5 | |||||||||||||||||||||||||||||
Total | $ | (11 | ) | $ | 65 | |||||||||||||||||||||||||||
Revenues and energy costs related to trading contracts are presented on a net basis in the Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the mark-to-market method with unrealized and realized gains and losses recorded in Operating revenues. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the mark-to-market method with unrealized and realized gains and losses for sales recorded in Operating revenue and purchases recorded in Fuel, purchased power and gas. | ||||||||||||||||||||||||||||||||
The effects of derivative instruments recoverable through the PSCR mechanism when realized on the Consolidated Statements of Financial Position were $5 million in unrealized gains related to FTRs recognized in Regulatory liabilities for the year ended December 31, 2013, and $15 million in unrealized gains related to FTRs recognized in Regulatory liabilities, for the year ended December 31, 2012. | ||||||||||||||||||||||||||||||||
The following represents the cumulative gross volume of derivative contracts outstanding as of December 31, 2013: | ||||||||||||||||||||||||||||||||
Commodity | Number of Units | |||||||||||||||||||||||||||||||
Natural Gas (MMBtu) | 795,553,773 | |||||||||||||||||||||||||||||||
Electricity (MWh) | 55,658,483 | |||||||||||||||||||||||||||||||
Foreign Currency Exchange ($ CAD) | 65,074,206 | |||||||||||||||||||||||||||||||
FTR (MWh) | 10,485,618 | |||||||||||||||||||||||||||||||
Various subsidiaries of the Company have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to request that the Company post cash or letters of credit as collateral in the event that DTE Energy’s credit rating is downgraded below investment grade. Certain of these provisions (known as “hard triggers”) state specific circumstances under which the Company can be asked to post collateral upon the occurrence of a credit downgrade, while other provisions (known as “soft triggers”) are not as specific. For contracts with soft triggers, it is difficult to estimate the amount of collateral which may be requested by counterparties and/or which the Company may ultimately be required to post. The amount of such collateral which could be requested fluctuates based on commodity prices (primarily natural gas, power and coal) and the provisions and maturities of the underlying transactions. As of December 31, 2013, DTE Energy's contractual obligation in the form of cash or letter of credit in the event of a downgrade to below investment grade, under both hard trigger and soft trigger provisions, was approximately $406 million. | ||||||||||||||||||||||||||||||||
As of December 31, 2013, the Company had approximately $1,176 million of derivatives in net liability positions, for which hard triggers exist. Collateral of approximately $25 million has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were approximately $902 million. The net remaining amount of approximately $249 million is derived from the $406 million noted above. |
Goodwill_Notes
Goodwill (Notes) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Goodwill and Intangible Assets Disclosure [Abstract] | ' | |||||||
Goodwill Disclosure | ' | |||||||
GOODWILL | ||||||||
The Company has goodwill resulting from purchase business combinations. | ||||||||
The change in the carrying amount of goodwill for the fiscal years ended December 31, 2013 and 2012 is as follows: | ||||||||
2013 | 2012 | |||||||
(In millions) | ||||||||
Balance as of January 1 | $ | 2,018 | $ | 2,020 | ||||
Goodwill attributable to sale of Unconventional Gas Production business | — | (2 | ) | |||||
Balance at December 31 | $ | 2,018 | $ | 2,018 | ||||
Acquisition_Notes
Acquisition (Notes) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Business Combinations [Abstract] | ' | |||
Business Combination Disclosure [Text Block] | ' | |||
ACQUISITION | ||||
In the fourth quarter of 2012, the Company closed on the purchase of a portfolio of fourteen on-site energy projects from subsidiaries of Duke Energy Corporation and GDF Suez Energy North America, Inc. This acquisition provided a growth opportunity for the Company's Power and Industrial Projects segment that leverages its extensive energy-related operating experience and project management capabilities. | ||||
The purchase of equity interests ranged from 46 percent to 100 percent of the project companies for a total purchase price of approximately $294 million, which consisted of $220 million paid in cash and assumption of approximately $74 million of debt. The debt assumed related to two project companies which have been deemed variable interest entities. DTE, however, was determined not to be the primary beneficiary and thus the VIEs' assets and liabilities are not included in the Company's Consolidated Statements of Financial Position. Therefore, the assumed debt was not included in the purchase price allocation table below. There was no exposure to loss related to the debt assumed as the customer of the project companies is obligated to pay the loans in the event of default or termination. The following table summarizes the fair value of the assets acquired and liabilities assumed as of the closing date: | ||||
(In millions) | ||||
Cash | $ | 22 | ||
Accounts receivable | 14 | |||
Other current assets | 8 | |||
Property, plant and equipment | 100 | |||
Intangible assets | 75 | |||
Other noncurrent assets | 9 | |||
Current liabilities | (7 | ) | ||
Non-controlling interest | (1 | ) | ||
Total purchase price | $ | 220 | ||
The intangible assets recorded as a result of the acquisition pertained to existing contracts and agreements, which were valued at approximately $75 million as of the closing date. The intangible assets are amortized on a straight line basis over a weighted-average amortization period of approximately eight years. The Company did not record any goodwill due to the acquisition. | ||||
The Company's 2012 results of operations included revenue of $30 million and net income of $2 million associated with the acquired project companies for the approximate three-month period following the closing date. The pro forma results of operations have not been presented for DTE Energy because the effects of the acquisition were not material to our consolidated results of operations. |
Discontinued_Operations_Notes
Discontinued Operations (Notes) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Discontinued Operations and Disposal Groups [Abstract] | ' | |||||||
Disposal Groups, Including Discontinued Operations, Disclosure [Text Block] | ' | |||||||
DISCONTINUED OPERATIONS | ||||||||
Sale of Unconventional Gas Production Business | ||||||||
In December 2012, the Company sold its 100% equity interest in its Unconventional Gas Production business which consisted of gas and oil production assets in the western Barnett and Marble Falls shale areas of Texas. The sale resulted in gross proceeds of approximately $255 million, which resulted in a pre-tax loss of approximately $83 million ($55 million after tax). The activity of the discontinued business is shown below. The amounts exclude general corporate overhead costs, and related tax effects, and no portion of corporate interest costs were allocated to discontinued operations. | ||||||||
2012 | 2011 | |||||||
(In millions) | ||||||||
Operating Revenues | $ | 55 | $ | 39 | ||||
Operation and Maintenance | 24 | 16 | ||||||
Depreciation, Depletion and Amortization | 23 | 18 | ||||||
Taxes Other Than Income | 4 | 3 | ||||||
Asset (Gains) and Losses, Net | 83 | — | ||||||
134 | 37 | |||||||
Operating Income (Loss) | (79 | ) | 2 | |||||
Other (Income) and Deductions | 6 | 6 | ||||||
Loss Before Income Taxes | (85 | ) | (4 | ) | ||||
Income Tax Expense (Benefit) | (29 | ) | (1 | ) | ||||
Net Loss Attributable to DTE Energy Company | $ | (56 | ) | $ | (3 | ) |
Property_Plant_and_Equipment_N
Property, Plant and Equipment (Notes) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Property, Plant and Equipment [Abstract] | ' | |||||||
Property, Plant and Equipment Disclosure | ' | |||||||
PROPERTY, PLANT AND EQUIPMENT | ||||||||
Summary of property by classification as of December 31: | ||||||||
2013 | 2012 | |||||||
Property, Plant and Equipment | (In millions) | |||||||
DTE Electric | ||||||||
Generation | $ | 11,127 | $ | 10,383 | ||||
Distribution | 7,603 | 7,306 | ||||||
Total DTE Electric | 18,730 | 17,689 | ||||||
DTE Gas | ||||||||
Distribution | 2,834 | 2,704 | ||||||
Storage | 431 | 426 | ||||||
Other | 836 | 852 | ||||||
Total DTE Gas | 4,101 | 3,982 | ||||||
Non-utility and other | 2,292 | 1,960 | ||||||
Total | 25,123 | 23,631 | ||||||
Less Accumulated Depreciation, Depletion and Amortization | ||||||||
DTE Electric | ||||||||
Generation | (4,004 | ) | (3,880 | ) | ||||
Distribution | (2,947 | ) | (2,837 | ) | ||||
Total DTE Electric | (6,951 | ) | (6,717 | ) | ||||
DTE Gas | ||||||||
Distribution | (1,129 | ) | (1,057 | ) | ||||
Storage | (138 | ) | (132 | ) | ||||
Other | (338 | ) | (365 | ) | ||||
Total DTE Gas | (1,605 | ) | (1,554 | ) | ||||
Non-utility and other | (767 | ) | (676 | ) | ||||
Total | (9,323 | ) | (8,947 | ) | ||||
Net Property, Plant and Equipment | $ | 15,800 | $ | 14,684 | ||||
The Allowance for Funds used During Construction (AFUDC) capitalized was approximately $23 million and $20 million during 2013 and 2012, respectively. | ||||||||
The composite depreciation rate for DTE Electric was approximately 3.4% in 2013 and 3.3% in 2012 and 2011. The composite depreciation rate for DTE Gas was 2.4% in 2013 and 2012, and 2.3% in 2011. | ||||||||
The average estimated useful life for each major class of utility property, plant and equipment as of December 31, 2013 follows: | ||||||||
Estimated Useful Lives in Years | ||||||||
Utility | Generation | Distribution | Storage | |||||
Electric | 40 | 41 | N/A | |||||
Gas | N/A | 50 | 53 | |||||
The estimated useful lives for major classes of non-utility assets and facilities ranges from 3 to 55 years. | ||||||||
Capitalized software costs are classified as Property, plant and equipment and the related amortization is included in Accumulated depreciation, depletion and amortization on the Consolidated Statements of Financial Position. The Company capitalizes the costs associated with computer software it develops or obtains for use in its business. The Company amortizes capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years. | ||||||||
Capitalized software costs amortization expense was $71 million in 2013, $68 million in 2012 and $65 million in 2011. The gross carrying amount and accumulated amortization of capitalized software costs at December 31, 2013 were $668 million and $384 million, respectively. The gross carrying amount and accumulated amortization of capitalized software costs at December 31, 2012 were $608 million and $313 million, respectively. | ||||||||
Gross property under capital leases was $35 million and $32 million at December 31, 2013 and 2012, respectively. Accumulated amortization of property under capital leases was $21 million and $20 million at December 31, 2013 and 2012, respectively. |
Jointly_Owned_Utility_Plant_No
Jointly Owned Utility Plant (Notes) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Jointly Owned Utility Plant, Net Ownership Amount [Abstract] | ' | |||||||
Jointly Owned Utility Plant [Text Block] | ' | |||||||
JOINTLY OWNED UTILITY PLANT | ||||||||
DTE Electric has joint ownership interest in two power plants, Belle River and Ludington Hydroelectric Pumped Storage. DTE Electric’s share of direct expenses of the jointly owned plants are included in Fuel, purchased power and gas and Operation and maintenance expenses in the Consolidated Statements of Operations. Ownership information of the two utility plants as of December 31, 2013 was as follows: | ||||||||
Belle River | Ludington | |||||||
Hydroelectric | ||||||||
Pumped Storage | ||||||||
In-service date | 1984-1985 | 1973 | ||||||
Total plant capacity | 1,270 | MW | 1,872 | MW | ||||
Ownership interest | (a) | 49 | % | |||||
Investment in property, plant and equipment (in millions) | $ | 1,702 | $ | 354 | ||||
Accumulated depreciation (in millions) | $ | 969 | $ | 170 | ||||
_______________________________________ | ||||||||
(a) | DTE Electric's ownership interest is 63% in Unit No. 1, 81% of the facilities applicable to Belle River used jointly by the Belle River and St. Clair Power Plants and 75% in common facilities used at Unit No. 2. | |||||||
Belle River | ||||||||
The Michigan Public Power Agency (MPPA) has an ownership interest in Belle River Unit No. 1 and other related facilities. The MPPA is entitled to 19% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance and capital improvement costs. | ||||||||
Ludington Hydroelectric Pumped Storage | ||||||||
Consumers Energy Company has an ownership interest in the Ludington Hydroelectric Pumped Storage Plant. Consumers Energy is entitled to 51% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance and capital improvement costs. |
Asset_Retirement_Obligations_N
Asset Retirement Obligations (Notes) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Asset Retirement Obligation [Abstract] | ' | |||
Asset Retirement Obligations | ' | |||
ASSET RETIREMENT OBLIGATIONS | ||||
The Company has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property and various other operations. The Company has conditional retirement obligations for gas pipelines, asbestos and PCB removal at certain of its power plants and various distribution equipment. The Company recognizes such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at our credit-adjusted risk-free rate. In its regulated operations, the Company recognizes regulatory assets or liabilities for timing differences in expense recognition for legal asset retirement costs that are currently recovered in rates. | ||||
If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets. | ||||
A reconciliation of the asset retirement obligations for 2013 follows: | ||||
(In millions) | ||||
Asset retirement obligations at December 31, 2012 | $ | 1,719 | ||
Accretion | 106 | |||
Liabilities incurred | 5 | |||
Liabilities settled | (13 | ) | ||
Revision in estimated cash flows | 10 | |||
Asset retirement obligations at December 31, 2013 | $ | 1,827 | ||
In 2001, DTE Electric began the final decommissioning of Fermi 1, with the goal of removing the remaining radioactive material and terminating the Fermi 1 license. In 2011, based on management decisions revising the timing and estimate of cash flows, DTE Electric accrued an additional $19 million with respect to the decommissioning of Fermi 1. Management has suspended decommissioning activities and placed the facility in safe storage status. The expense amount has been recorded in Asset (gains) and losses, reserves and impairments, net on the Consolidated Statements of Operations. In addition, in 2011, based on updated studies revising the timing and estimate of cash flows, a reduction of approximately $20 million was made to the DTE Electric asset retirement obligation for asbestos removal with approximately $6 million of the decrease associated with Fermi 1 recorded in Asset (gains) and losses, reserves and impairments, net on the Consolidated Statements of Operations. | ||||
In October 2011, the MPSC approved DTE Electric's request for a reduction to the nuclear decommissioning surcharge under the assumption that it would request an extension of the Fermi 2 license for an additional 20 years beyond the term of the existing license which expires in 2025. DTE Electric expects to request the license extension in 2014. This proposed extension of the license, including the associated impact on spent nuclear fuel, resulted in a revision in estimated cash flows for the Fermi 2 asset retirement obligation of approximately $22 million in 2011. It is estimated that the cost of decommissioning Fermi 2 is $1.6 billion in 2013 dollars and $10 billion in 2045 dollars, using a 6% inflation rate. Approximately $1.6 billion of the asset retirement obligations represent nuclear decommissioning liabilities that are funded through a surcharge to electric customers over the life of the Fermi 2 nuclear plant. | ||||
The NRC has jurisdiction over the decommissioning of nuclear power plants and requires minimum decommissioning funding based upon a formula. The MPSC and FERC regulate the recovery of costs of decommissioning nuclear power plants and both require the use of external trust funds to finance the decommissioning of Fermi 2. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates. The Company believes the MPSC and FERC collections will be adequate to fund the estimated cost of decommissioning. The decommissioning assets, anticipated earnings thereon and future revenues from decommissioning collections will be used to decommission Fermi 2. The Company expects the liabilities to be reduced to zero at the conclusion of the decommissioning activities. If amounts remain in the trust funds for Fermi 2 following the completion of the decommissioning activities, those amounts will be disbursed based on rulings by the MPSC and FERC. | ||||
A portion of the funds recovered through the Fermi 2 decommissioning surcharge and deposited in external trust accounts is designated for the removal of non-radioactive assets and returning the site to greenfield. This removal and greenfielding is not considered a legal liability. Therefore, it is not included in the asset retirement obligation, but is reflected as the nuclear decommissioning liability. The decommissioning of Fermi 1 is funded by DTE Electric. Contributions to the Fermi 1 trust are discretionary. See Note 3 for additional discussion of Nuclear decommissioning trust fund assets. |
Regulatory_Matters_Notes
Regulatory Matters (Notes) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Regulatory Assets and Liabilities Disclosure [Abstract] | ' | |||||||
Regulatory Matters | ' | |||||||
REGULATORY MATTERS | ||||||||
Regulation | ||||||||
DTE Electric and DTE Gas are subject to the regulatory jurisdiction of the MPSC, which issues orders pertaining to rates, recovery of certain costs, including the costs of generating facilities and regulatory assets, conditions of service, accounting and operating-related matters. DTE Electric is also regulated by the FERC with respect to financing authorization and wholesale electric activities. Regulation results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses. | ||||||||
The Company is unable to predict the outcome of the unresolved regulatory matters discussed herein. Resolution of these matters is dependent upon future MPSC orders and appeals, which may materially impact the financial position, results of operations and cash flows of the Company. | ||||||||
Regulatory Assets and Liabilities | ||||||||
DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of our businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment. | ||||||||
The following are balances and a brief description of the regulatory assets and liabilities at December 31: | ||||||||
2013 | 2012 | |||||||
(In millions) | ||||||||
Assets | ||||||||
Recoverable pension and other postretirement costs: | ||||||||
Pension | $ | 1,660 | $ | 2,420 | ||||
Other postretirement costs | — | 426 | ||||||
Asset retirement obligation | 394 | 424 | ||||||
Recoverable Michigan income taxes | 286 | 304 | ||||||
Recoverable income taxes related to securitized regulatory assets | 126 | 226 | ||||||
Cost to achieve Performance Excellence Process | 75 | 96 | ||||||
Other recoverable income taxes | 71 | 76 | ||||||
Unamortized loss on reacquired debt | 63 | 63 | ||||||
Deferred environmental costs | 59 | 58 | ||||||
Enterprise Business Systems costs | 13 | 16 | ||||||
Recoverable revenue decoupling | 9 | 28 | ||||||
Choice incentive mechanism | 3 | 66 | ||||||
Accrued PSCR/GCR revenue | — | 87 | ||||||
Recoverable restoration expense | — | 49 | ||||||
Other | 104 | 78 | ||||||
2,863 | 4,417 | |||||||
Less amount included in current assets | (26 | ) | (182 | ) | ||||
$ | 2,837 | $ | 4,235 | |||||
Securitized regulatory assets | $ | 231 | $ | 413 | ||||
2013 | 2012 | |||||||
(In millions) | ||||||||
Liabilities | ||||||||
Asset removal costs | $ | 351 | $ | 439 | ||||
Renewable energy | 277 | 230 | ||||||
Refundable revenue decoupling/deferred gain | 127 | 127 | ||||||
Negative pension offset | 84 | 105 | ||||||
Over recovery of Securitization | 72 | 54 | ||||||
Refundable other postretirement costs | 72 | — | ||||||
Accrued PSCR/GCR | 65 | 16 | ||||||
Refundable income taxes | 45 | 56 | ||||||
Energy optimization | 31 | 34 | ||||||
Fermi 2 refueling outage | 26 | 12 | ||||||
Refundable uncollectible expense | 12 | 37 | ||||||
Other | 2 | 10 | ||||||
$ | 1,164 | $ | 1,120 | |||||
Less amount included current liabilities | (302 | ) | (89 | ) | ||||
$ | 862 | $ | 1,031 | |||||
As noted below, certain regulatory assets for which costs have been incurred have been included (or are expected to be included, for costs incurred subsequent to the most recently approved rate case) in DTE Electric or DTE Gas’s rate base, thereby providing a return on invested costs (except as noted). Certain other regulatory assets are not included in rate base but accrue recoverable carrying charges until surcharges to collect the assets are billed. Certain regulatory assets do not result from cash expenditures and therefore do not represent investments included in rate base or have offsetting liabilities that reduce rate base. | ||||||||
ASSETS | ||||||||
• | Recoverable pension and other postretirement costs — Accounting rules for pension and other postretirement benefit costs require, among other things, the recognition in other comprehensive income of the actuarial gains or losses and the prior service costs that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the impact of actuarial gains or losses and prior services costs as a regulatory asset since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs. (a) | |||||||
• | Asset retirement obligation — This obligation is primarily for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant. (a) | |||||||
• | Recoverable Michigan income taxes — In July 2007, the Michigan Business Tax (MBT) was enacted by the State of Michigan. State deferred tax liabilities were established for the Company’s utilities, and offsetting regulatory assets were recorded as the impacts of the deferred tax liabilities will be reflected in rates as the related taxable temporary differences reverse and flow through current income tax expense. In May 2011, the MBT was repealed and the Michigan Corporate Income Tax (MCIT) was enacted. The regulatory asset was remeasured to reflect the impact of the MCIT tax rate. (a) | |||||||
• | Recoverable income taxes related to securitized regulatory assets — Receivable for the recovery of income taxes to be paid on the non-bypassable securitization bond surcharge. A non-bypassable securitization tax surcharge recovers the income tax over a fourteen-year period ending 2015. (a) | |||||||
• | Cost to achieve Performance Excellence Process (PEP) — The MPSC authorized the deferral of costs to implement the PEP. These costs consist of employee severance, project management and consultant support. These costs are amortized over a ten-year period beginning with the year subsequent to the year the costs were deferred. | |||||||
• | Other recoverable income taxes — Income taxes receivable from DTE Electric’s customers representing the difference in property-related deferred income taxes and amounts previously reflected in DTE Electric’s rates. This asset will reverse over the remaining life of the related plant. (a) | |||||||
• | Unamortized loss on reacquired debt — The unamortized discount, premium and expense related to debt redeemed with a refinancing are deferred, amortized and recovered over the life of the replacement issue. | |||||||
• | Deferred environmental costs — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas's former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings. (a) | |||||||
• | Enterprise Business Systems (EBS) costs — The MPSC approved the deferral and amortization over ten years beginning in January 2009 of EBS costs that would otherwise be expensed. | |||||||
• | Recoverable revenue decoupling — Amounts recoverable from DTE Gas customers for the change in revenue resulting from the difference in weather-adjusted average sales per customer compared to the base level of average sales per customer established by the MPSC. The December 2012 order in DTE Gas's rate case required the RDM be discontinued effective November 1, 2012. The order provided for a new RDM, which began in November 2013. | |||||||
• | Choice incentive mechanism (CIM) — DTE Electric receivable for non-fuel revenues lost as a result of fluctuations in electric Customer Choice sales. The CIM was terminated in the October 20, 2011 MPSC order issued to DTE Electric. | |||||||
• | Accrued PSCR/GCR revenue — Receivable for the temporary under-recovery of and carrying costs on fuel and purchased power costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary under-recovery of and carrying costs on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism. | |||||||
• | Recoverable restoration expense — Receivable for the MPSC approved restoration expense tracking mechanism that tracked the difference between actual restoration expense and the amount provided for in base rates, recognized pursuant to the MPSC authorization. The restoration expense tracking mechanism was terminated in the October 20, 2011 MPSC order issued to DTE Electric. | |||||||
• | Securitized regulatory assets — The net book balance of the Fermi 2 nuclear plant was written off in 1998 and an equivalent regulatory asset was established. In 2001, the Fermi 2 regulatory asset and certain other regulatory assets were securitized pursuant to PA 142 and an MPSC order. A non-bypassable securitization bond surcharge recovers the securitized regulatory asset over a fourteen-year period ending in 2015. | |||||||
_________________________________ | ||||||||
(a) | Regulatory assets not earning a return or accruing carrying charges. | |||||||
LIABILITIES | ||||||||
• | Asset removal costs — The amount collected from customers for the funding of future asset removal activities. | |||||||
• | Renewable energy — Amounts collected in rates in excess of renewable energy expenditures. | |||||||
• | Refundable revenue decoupling / deferred gain — Amounts were originally accrued as refundable to DTE Electric customers for the change in revenue resulting from the difference between actual average sales per customer compared to the base level of average sales per customer established by the MPSC. In 2012, the Michigan Court of Appeals issued a decision reversing the MPSC's decision to authorize a RDM for DTE Electric. The revenue decoupling liability was reversed and, after receiving an order from the MPSC to defer the resulting gain for future amortization, DTE Electric created a regulatory liability representing its obligation to refund the gain. The deferred gain will be amortized into earnings in 2014. | |||||||
• | Negative pension offset — DTE Gas's negative pension costs are not included as a reduction to its authorized rates; therefore, the Company is accruing a regulatory liability to eliminate the impact on earnings of the negative pension expense accrued. This regulatory liability will reverse to the extent DTE Gas’s pension expense is positive in future years. | |||||||
• | Over recovery of Securitization — Over recovery of securitization bond expenses. | |||||||
• | Refundable other postretirement costs — Accounting rules for other postretirement benefit costs require, among other things, the recognition in other comprehensive income of the actuarial gains or losses and the prior service costs or credits that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the favorable impact of actuarial gains or losses and prior service credits as a regulatory liability since the impact will reduce expense in a future rate setting process as the deferred items are recognized as a component of net periodic benefit costs. | |||||||
• | Accrued PSCR/GCR refund — Liability for the temporary over-recovery of and a return on power supply costs and transmission costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary over-recovery of and a return on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism. | |||||||
• | Refundable income taxes — Income taxes refundable to DTE Gas’s customers representing the difference in property-related deferred income taxes payable and amounts recognized pursuant to MPSC authorization. | |||||||
• | Energy optimization (EO) — Amounts collected in rates in excess of energy optimization expenditures. | |||||||
• | Fermi 2 refueling outage — Accrued liability for refueling outage at Fermi 2 pursuant to MPSC authorization. | |||||||
• | Refundable uncollectible expense (UETM) — DTE Electric and DTE Gas liability for the MPSC approved uncollectible expense tracking mechanism that tracks the difference in the fluctuation in uncollectible accounts and amounts recognized pursuant to the MPSC authorization. The UETM was terminated for DTE Electric in the October 20, 2011 MPSC rate case order and terminated for DTE Gas in the December 20, 2012 MPSC approval of the partial settlement agreement. | |||||||
2009 Electric Rate Case Filing - Court of Appeals Decision | ||||||||
In April 2012, the Michigan Court of Appeals (COA) issued a decision relating to an appeal of the January 2010 MPSC rate order in DTE Electric's January 2009 rate case filing. The COA found that the record of evidence in the January 2010 rate order was insufficient to support the MPSC's authorization to recover costs for the advanced metering infrastructure (AMI) program and remanded this matter to the MPSC. On October 17, 2013, the MPSC issued an order affirming the approximately $8 million rate increase authorized in the MPSC's January 2010 rate order for the AMI program and further concluded that the evidence presented after remand supports the authorized cost recovery. | ||||||||
2010 Electric Rate Case Filing - Court of Appeals Decision | ||||||||
In July 2013, the COA issued a decision relating to an appeal of the October 2011 MPSC order in DTE Electric's October 2010 rate case filing. The COA found that the record of evidence in the 2010 rate case order was insufficient to support the MPSC's authorization to recover costs for the AMI program and remanded this matter to the MPSC. The MPSC had approved an approximately $11 million rate increase related to the AMI program in the October 2011 order. DTE Electric is currently operating its AMI program pursuant to the MPSC's approval set forth in the October 2011 order. On August 29, 2013, the MPSC reopened the 2010 electric rate case for the limited purpose of addressing the COA's opinion on AMI. The Company is unable to predict the outcome of this matter or the timing of its resolution. | ||||||||
Transition of the City of Detroit's Public Lighting Department's (PLD) Customers to DTE Electric's Distribution System | ||||||||
Accounting Authority | ||||||||
On June 28, 2013, DTE Electric filed an application for accounting authority to defer certain costs associated with the transition of the City of Detroit's PLD customers to the DTE Electric distribution system over a five to seven year system conversion period. The Company requested authority to defer as a regulatory asset, all net incremental revenue requirement associated with the transition. The net incremental revenue requirement includes costs to install meters and attach customers; system and customer facility upgrades and repairs; and the difference between DTE Electric's tariff rates and any transitional rates approved in the future. On July 11, 2013, the MPSC approved DTE Electric's request to defer, for accounting purposes, the net incremental revenue requirement. | ||||||||
The approval excludes the request to defer the difference between DTE Electric's tariff rates and any transitional rates that might be approved by the MPSC in the future. The MPSC will address proposed rates and recovery matters in a future contested proceeding. As the accounting order did not provide a regulatory recovery mechanism, a regulatory asset will not be recognized until a regulatory recovery mechanism is put into place and the recovery of the regulatory asset becomes probable. | ||||||||
Transitional Reconciliation Mechanism (TRM) | ||||||||
On July 19, 2013, DTE Electric filed its TRM application proposing a transitional tariff option for certain former PLD customers and a modified line extension provision. The application also proposed a recovery mechanism for the deferred net incremental revenue requirement described above. The application further discussed that DTE Electric will be requesting recovery, in subsequent PSCR cases, of PLD transmission delivery service costs incurred while DTE Electric is temporarily relying upon PLD to operate and maintain PLD's system during the system conversion period. If the MPSC determines that the transmission costs are not recoverable in the PSCR, the Company requested recovery as part of the TRM. | ||||||||
Energy Optimization (EO) Plans | ||||||||
The EO plan is designed to help customers reduce their electric usage by: 1) building customer awareness of energy efficiency options and 2) offering a diverse set of programs and participation options that result in energy savings for each customer class. | ||||||||
In May 2013, DTE Electric and DTE Gas filed separate applications for approval of their respective reconciliations of their 2012 EO plan expenses. DTE Electric’s EO reconciliation included a cumulative $26 million net over-recovery and DTE Gas’s EO reconciliation included a cumulative $7 million net over-recovery for their 2012 EO plans. DTE Electric and DTE Gas proposed that the calculated over-recoveries for 2012 be carried forward into 2013 and used as beginning balances for the 2013 reconciliations. On December 6, 2013, the MPSC approved settlement agreements of the DTE Electric and DTE Gas 2012 EO reconciliations that carried forward to 2013 the 2012 over-recoveries. In addition, the MPSC authorized performance incentive surcharges, over a 12-month period effective January 1, 2014, of approximately $10 million and $4 million for DTE Electric and DTE Gas, respectively. | ||||||||
In July 2013, DTE Electric and DTE Gas filed separate applications with the MPSC for the biennial review of their EO plans. On December 19, 2013, the MPSC approved settlement agreements for the EO plans of DTE Electric and DTE Gas. | ||||||||
DTE Electric Restoration Expense Tracker Mechanism (RETM) and Line Clearance Tracker (LCT) Reconciliation | ||||||||
In January 2012, DTE Electric filed an application with the MPSC for approval of the reconciliation of its 2011 RETM and LCT. The Company's 2011 restoration expenses were higher than the amount provided in rates. Accordingly, DTE Electric requested net recovery of approximately $44 million. On February 28, 2013, the MPSC approved a settlement agreement and authorized a $44 million net surcharge to recover the costs over a three-month period beginning April 1, 2013. | ||||||||
DTE Electric Uncollectible Expense True-Up Mechanism (UETM) | ||||||||
In February 2012, DTE Electric filed an application with the MPSC for approval of its UETM for 2011 requesting authority to refund approximately $9 million consisting of costs related to 2011 uncollectible expense. On February 28, 2013, the MPSC approved a settlement agreement and authorized a $9 million credit to refund the over-recovery over a one month period beginning April 1, 2013. | ||||||||
Low Income Energy Assistance Fund (LIEAF) | ||||||||
On July 1, 2013, Michigan Public Act 95 was signed into law and created the LIEAF. The legislation allows the use of a LIEAF funding factor to be determined by the MPSC and assessed on all customer classes of Michigan electric utilities to fund the LIEAF. On July 29, 2013, the MPSC adopted a funding factor of $0.99 per meter per month for all Michigan electric utilities that are participating in the program, including DTE Electric, effective with the September 2013 billing month. The surcharge billed by DTE Electric is remitted to the State of Michigan for subsequent distribution through a grant process to social service agencies and utilities to assist low income customers. | ||||||||
Renewable Energy Plan (REP) | ||||||||
In June 2013, DTE Electric filed an application for the biennial review and approval of its amended REP with the MPSC requesting authority to reduce its annual surcharge revenue recovery from approximately $100 million to $15 million. The proposed level is appropriate to continue to properly implement DTE Electric’s 20-year REP, designed to deliver cleaner, renewable electric generation to its customers, to further diversify DTE Electric’s and the State of Michigan’s sources of electric supply, and to address the state and national goals of increasing energy independence. On December 19, 2013, the MPSC approved DTE Electric’s amended REP. | ||||||||
Power Supply Cost Recovery Proceedings | ||||||||
The PSCR process is designed to allow DTE Electric to recover all of its power supply costs if incurred under reasonable and prudent policies and practices. DTE Electric's power supply costs include fuel and related transportation costs, purchased and net interchange power costs, nitrogen oxide and sulfur dioxide emission allowances costs, urea costs, transmission costs and MISO costs. The MPSC reviews these costs, policies and practices for prudence in annual plan and reconciliation filings. | ||||||||
2010 PSCR Year - On April 25, 2013, the MPSC approved the 2010 PSCR net under-recovery of $52.6 million and the recovery of this amount as part of the 2011 PSCR reconciliation. The order also approved DTE Electric's Pension Equalization Mechanism reconciliation and authorized a one month surcharge in June 2013 and approved the recovery of the over-refund of the self-implemented rate increase related to the 2009 electric rate case filing as part of the 2011 PSCR reconciliation. | ||||||||
2012 PSCR Year - In March 2013, DTE Electric filed the 2012 PSCR reconciliation calculating a net under-recovery of approximately $87 million that includes an under-recovery of approximately $148 million for the 2011 PSCR year. The reconciliation includes purchased power costs related to the manual shutdown of our Fermi 2 nuclear power plant in June 2012 caused by the failure of one of the plant's two non-safety related feed-water pumps. The plant was restarted on July 30, 2012, which restored production to nominal 68% of full capacity. In September 2013, the repair to the plant was completed and production was returned to full capacity. DTE Electric was able to purchase sufficient power from MISO to continue to provide uninterrupted service to our customers. Certain intervenors in the reconciliation case have challenged the recovery of up to $32 million of the Fermi-related purchased power costs. Resolution of this matter is expected in 2014. | ||||||||
2012 Gas Rate Case Filing | ||||||||
DTE Gas filed a rate case on April 20, 2012 based on a projected test year for the twelve-month period ending October 31, 2013. On December 20, 2012, the MPSC approved a partial settlement agreement and authorized the Company to increase its annual gas revenues by $19.9 million for service rendered on and after January 1, 2013. The partial settlement agreement did not resolve the proposal for an infrastructure recovery mechanism (IRM) designed to recover DTE Gas' projected costs over a five-year period related to its gas main renewal, pipeline integrity and meter move out programs. On April 16, 2013, the MPSC issued an order approving the IRM and authorized the recovery of the cost of service related to $77 million of annual investment in the programs beginning in May 2013. The IRM will adjust annually in July for the incremental investment each year, after a limited hearing on the reconciliation of the prior year capital expenditures. When DTE Gas files a rate case, all capital invested as part of the IRM will be rolled into rate base and recovery would continue through base rates as part of a base rate case filing. As part of any future rate case, DTE Gas may propose to implement an updated IRM to address the recovery of future infrastructure investments. | ||||||||
DTE Gas UETM | ||||||||
In March 2013, DTE Gas filed an application with the MPSC for approval of its UETM reconciliation for 2012 requesting authority to refund approximately $20 million. On September 10, 2013, the MPSC approved a settlement agreement approving the requested 2012 UETM refund over a twelve-month period beginning in October 2013. | ||||||||
DTE Gas Revenue Decoupling Mechanism (RDM) | ||||||||
In October 2012, DTE Gas filed an application with the MPSC for approval of its RDM reconciliation for the period July 1, 2011 through June 30, 2012. The application requests authority to adjust existing retail gas rates so as to collect a net amount of approximately $9 million, plus interest. On March 15, 2013, the MPSC approved a settlement agreement and authorized the implementation of surcharges during the billing months of April 2013 through March 2014. | ||||||||
In May 2013, DTE Gas filed an application with the MPSC for approval of its RDM reconciliation for the period July 1, 2012 through October 31, 2012. DTE Gas's RDM application proposed the recovery of a net under-recovery of approximately $5.2 million. On November 14, 2013, the MPSC approved a settlement agreement and authorized the implementation of surcharges during the billing months of December 2013 through March 2014. | ||||||||
The December 2012 order in DTE Gas's rate case required the RDM be discontinued effective November 1, 2012. The order also provided for a new RDM for the period November 1, 2013 through October 31, 2014. The new RDM decouples weather normalized distribution revenue inside caps. The caps are tied to expected conservation targets: 1.125% in the first reconciliation period and 2.25% for the second and future periods. | ||||||||
DTE Gas Depreciation Filing | ||||||||
In compliance with an MPSC order, DTE Gas filed a depreciation case in June 2012. On May 15, 2013, the MPSC approved a settlement agreement increasing DTE Gas’s composite depreciation rates from 2.29% to 2.51%, effective on the same date as the MPSC-approved rates are effective in DTE Gas’s next general rate case. The Company cannot predict when DTE Gas will file its next rate case. |
Income_Taxes_Notes
Income Taxes (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Income Tax Disclosure [Abstract] | ' | |||||||||||
Income Taxes | ' | |||||||||||
INCOME TAXES | ||||||||||||
Income Tax Summary | ||||||||||||
The Company files a consolidated federal income tax return. Total income tax expense varied from the statutory federal income tax rate for the following reasons: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Income before income taxes | $ | 922 | $ | 960 | $ | 991 | ||||||
Income tax expense at 35% statutory rate | $ | 323 | $ | 336 | $ | 347 | ||||||
Production tax credits | (68 | ) | (49 | ) | (6 | ) | ||||||
Investment tax credits | (6 | ) | (6 | ) | (6 | ) | ||||||
Depreciation | (4 | ) | (4 | ) | (4 | ) | ||||||
AFUDC - Equity | (5 | ) | (4 | ) | (1 | ) | ||||||
Employee Stock Ownership Plan dividends | (4 | ) | (4 | ) | (4 | ) | ||||||
Domestic production activities deduction | (14 | ) | (14 | ) | (7 | ) | ||||||
State and local income taxes, net of federal benefit | 37 | 37 | 37 | |||||||||
Enactment of Michigan Corporate Income Tax, net of federal expense | — | — | (87 | ) | ||||||||
Other, net | (5 | ) | (6 | ) | (1 | ) | ||||||
Income tax expense | $ | 254 | $ | 286 | $ | 268 | ||||||
Effective income tax rate | 27.5 | % | 29.8 | % | 27 | % | ||||||
Components of income tax expense were as follows: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Current income tax expense (benefit) | ||||||||||||
Federal | $ | 74 | $ | 190 | $ | 27 | ||||||
State and other income tax | 16 | 49 | 21 | |||||||||
Total current income taxes | 90 | 239 | 48 | |||||||||
Deferred income tax expense (benefit) | ||||||||||||
Federal | 122 | 39 | 318 | |||||||||
State and other income tax | 42 | 8 | (98 | ) | ||||||||
Total deferred income taxes | 164 | 47 | 220 | |||||||||
Total income taxes from continuing operations | 254 | 286 | 268 | |||||||||
Discontinued operations | — | (29 | ) | (1 | ) | |||||||
Total | $ | 254 | $ | 257 | $ | 267 | ||||||
Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the financial statements. Deferred tax assets and liabilities are classified as current or noncurrent according to the classification of the related assets or liabilities. Deferred tax assets and liabilities not related to assets or liabilities are classified according to the expected reversal date of the temporary differences. Consistent with rate making treatment, deferred taxes are offset in the table below for temporary differences which have related regulatory assets and liabilities. | ||||||||||||
Deferred tax assets (liabilities) were comprised of the following at December 31: | ||||||||||||
2013 | 2012 | |||||||||||
(In millions) | ||||||||||||
Property, plant and equipment | $ | (3,372 | ) | $ | (3,389 | ) | ||||||
Securitized regulatory assets | (127 | ) | (256 | ) | ||||||||
Alternative minimum tax credit carry-forwards | 266 | 254 | ||||||||||
Merger basis differences | 18 | 42 | ||||||||||
Pension and benefits | (30 | ) | (33 | ) | ||||||||
Other comprehensive loss | — | 101 | ||||||||||
Derivative assets and liabilities | — | 66 | ||||||||||
State net operating loss and credit carry-forwards | 43 | 37 | ||||||||||
Other | (110 | ) | 41 | |||||||||
(3,312 | ) | (3,137 | ) | |||||||||
Less valuation allowance | (37 | ) | (33 | ) | ||||||||
$ | (3,349 | ) | $ | (3,170 | ) | |||||||
Current deferred income tax assets (liabilities) | $ | (28 | ) | $ | 21 | |||||||
Long-term deferred income tax liabilities | (3,321 | ) | (3,191 | ) | ||||||||
$ | (3,349 | ) | $ | (3,170 | ) | |||||||
Deferred income tax assets | $ | 1,808 | $ | 1,038 | ||||||||
Deferred income tax liabilities | (5,157 | ) | (4,208 | ) | ||||||||
$ | (3,349 | ) | $ | (3,170 | ) | |||||||
Production tax credits earned in prior years but not utilized totaled $266 million and are carried forward indefinitely as alternative minimum tax credits. The majority of the production tax credits earned in prior years but not utilized, including all of those from our synfuel projects, were generated from projects that had received a private letter ruling (PLR) from the Internal Revenue Service (IRS). These PLRs provide assurance as to the appropriateness of using these credits to offset taxable income, however, these tax credits are subject to IRS audit and adjustment. | ||||||||||||
The above table excludes deferred tax liabilities associated with unamortized investment tax credits that are shown separately on the Consolidated Statements of Financial Position. Investment tax credits are deferred and amortized to income over the average life of the related property. | ||||||||||||
The Company has state deferred tax assets related to net operating loss and credit carry-forwards of $43 million and $37 million at December 31, 2013 and 2012, respectively. The state net operating loss and credit carry-forwards expire from 2014 through 2033. The Company has recorded valuation allowances at December 31, 2013 and 2012 of approximately $37 million and $33 million, respectively, with respect to these deferred tax assets. In assessing the realizability of deferred tax assets, the Company considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. 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. | ||||||||||||
Uncertain Tax Positions | ||||||||||||
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Balance at January 1 | $ | 11 | $ | 48 | $ | 28 | ||||||
Additions for tax positions of prior years | — | — | 27 | |||||||||
Reductions for tax positions of prior years | — | (2 | ) | (4 | ) | |||||||
Additions for tax positions of current year | — | 1 | 1 | |||||||||
Settlements | — | (30 | ) | (3 | ) | |||||||
Lapse of statute of limitations | (1 | ) | (6 | ) | (1 | ) | ||||||
Balance at December 31 | $ | 10 | $ | 11 | $ | 48 | ||||||
The Company had $2 million and $3 million of unrecognized tax benefits at December 31, 2013 and at 2012, respectively, that, if recognized, would favorably impact its effective tax rate. During the next twelve months, it is reasonably possible that the statute of limitation will expire on various state tax returns. As a result, the Company believes that it is possible that there will be a decrease in unrecognized tax benefits of up to $1 million within the next twelve months. | ||||||||||||
The Company recognizes interest and penalties pertaining to income taxes in Interest expense and Other expenses, respectively, on its Consolidated Statements of Operations. Accrued interest pertaining to income taxes totaled $1 million and $1 million at December 31, 2013 and 2012, respectively. The Company had no accrued penalties pertaining to income taxes. The Company recognized interest expense (income) related to income taxes of a nominal amount, $(1) million and $(2) million in 2013, 2012 and 2011, respectively. | ||||||||||||
In 2013, the Company settled a federal tax audit for the 2011 tax year, which resulted in the recognition of a nominal amount of unrecognized tax benefits. The Company's federal income tax returns for 2012 and subsequent years remain subject to examination by the IRS. The Company's Michigan Business Tax and Michigan Corporate Income Tax returns for the year 2008 and subsequent years remain subject to examination by the State of Michigan. The Company also files tax returns in numerous state and local jurisdictions with varying statutes of limitation. | ||||||||||||
Michigan Corporate Income Tax (MCIT) | ||||||||||||
In May 2011, the Michigan Business Tax (MBT) was repealed and the MCIT was enacted and became effective January 1, 2012. The MCIT subjects corporations with business activity in Michigan to a 6% tax rate on an apportioned income tax base and eliminates the modified gross receipts tax and nearly all credits available under the MBT. The MCIT also eliminated the future deductions allowed under MBT that enabled companies to establish a one-time deferred tax asset upon enactment of the MBT to offset deferred tax liabilities that resulted from enactment of the MBT. | ||||||||||||
As a result of the enactment of the MCIT, the net state deferred tax liability was remeasured to reflect the impact of the MCIT tax rate on cumulative temporary differences expected to reverse after the effective date. The net impact of this remeasurement was a reduction of the net deferred tax assets attributable to our regulated utilities, partially offset by a decrease in deferred tax liabilities attributable to our non-utilities of $87 million primarily due to a lower apportionment factor from inclusion of non-utility entities in DTE Energy's unitary Michigan tax return and was recognized as a reduction to income tax expense in 2011. | ||||||||||||
No recognition of these non-cash transactions have been reflected in the Consolidated Statements of Cash Flows. |
Common_Stock_Notes
Common Stock (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Stockholders' Equity Note [Abstract] | ' | |||||||||||
Schedule of Stock by Class [Table Text Block] | ' | |||||||||||
COMMON STOCK | ||||||||||||
Common Stock | ||||||||||||
During 2013 and 2012, the Company contributed the following amounts of DTE Energy Common stock to the DTE Energy Company Affiliates Employee Benefit Plans Master Trust: | ||||||||||||
Date | Number of Shares | Price Per Share | Amount | |||||||||
(In millions) | ||||||||||||
12-Mar-13 | 750,075 | $ | 66.66 | $ | 50 | |||||||
12-Jun-13 | 753,579 | $ | 66.35 | 50 | ||||||||
12-Sep-13 | 1,522,301 | $ | 65.69 | 100 | ||||||||
$ | 200 | |||||||||||
18-Jun-12 | 1,334,668 | $ | 59.94 | $ | 80 | |||||||
The shares for all the contributions were valued at the closing market price of DTE Energy common stock on the contribution dates in accordance with fair value measurement and accounting requirements. | ||||||||||||
Under the DTE Energy Company Long-Term Incentive Plan, the Company grants non-vested stock awards to key employees, primarily management. As a result of a stock award, a settlement of an award of performance shares, or by exercise of a participant’s stock option, the Company may deliver common stock from the Company’s authorized but unissued common stock and/or from outstanding common stock acquired by or on behalf of the Company in the name of the participant. | ||||||||||||
Dividends | ||||||||||||
Certain of the Company’s credit facilities contain a provision requiring the Company to maintain a total funded debt to capitalization ratio, as defined in the agreements, of no more than 0.65 to 1, which has the effect of limiting the amount of dividends the Company can pay in order to maintain compliance with this provision. See Note 17 for a definition of this ratio. The effect of this provision was to restrict the payment of approximately $166 million at December 31, 2013 of total retained earnings of approximately $4 billion. There are no other effective limitations with respect to the Company’s ability to pay dividends. |
Earnings_Per_Share_Notes
Earnings Per Share (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Earnings Per Share [Abstract] | ' | |||||||||||
Earnings Per Share | ' | |||||||||||
EARNINGS PER SHARE | ||||||||||||
The Company reports both basic and diluted earnings per share. The calculation of diluted earnings per share assumes the issuance of potentially dilutive common shares outstanding during the period from the exercise of stock options. A reconciliation of both calculations is presented in the following table as of December 31: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions, expect per share amounts) | ||||||||||||
Basic Earnings per Share | ||||||||||||
Net income attributable to DTE Energy Company | $ | 661 | $ | 610 | $ | 711 | ||||||
Average number of common shares outstanding | 175 | 171 | 169 | |||||||||
Weighted average net restricted shares outstanding | 1 | 1 | 1 | |||||||||
Dividends declared — common shares | $ | 453 | $ | 413 | $ | 392 | ||||||
Dividends declared — net restricted shares | 1 | 1 | 1 | |||||||||
Total distributed earnings | $ | 454 | $ | 414 | $ | 393 | ||||||
Net income less distributed earnings | $ | 207 | $ | 196 | $ | 318 | ||||||
Distributed (dividends per common share) | $ | 2.59 | $ | 2.42 | $ | 2.32 | ||||||
Undistributed | 1.17 | 1.14 | 1.87 | |||||||||
Total Basic Earnings per Common Share | $ | 3.76 | $ | 3.56 | $ | 4.19 | ||||||
Diluted Earnings per Share | ||||||||||||
Net income attributable to DTE Energy Company | $ | 661 | $ | 610 | $ | 711 | ||||||
Average number of common shares outstanding | 175 | 171 | 169 | |||||||||
Average incremental shares from assumed exercise of options | — | 1 | 1 | |||||||||
Common shares for dilutive calculation | 175 | 172 | 170 | |||||||||
Weighted average net restricted shares outstanding | 1 | 1 | 1 | |||||||||
Dividends declared — common shares | $ | 453 | $ | 413 | $ | 392 | ||||||
Dividends declared — net restricted shares | 1 | 1 | 1 | |||||||||
Total distributed earnings | $ | 454 | $ | 414 | $ | 393 | ||||||
Net income less distributed earnings | $ | 207 | $ | 196 | $ | 318 | ||||||
Distributed (dividends per common share) | $ | 2.59 | $ | 2.42 | $ | 2.32 | ||||||
Undistributed | 1.17 | 1.13 | 1.86 | |||||||||
Total Diluted Earnings per Common Share | $ | 3.76 | $ | 3.55 | $ | 4.18 | ||||||
LongTerm_Debt_Notes
Long-Term Debt (Notes) | 12 Months Ended | |||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||
Long-term Debt, Unclassified [Abstract] | ' | |||||||||||||||||||||||||||
Long-Term Debt | ' | |||||||||||||||||||||||||||
LONG-TERM DEBT | ||||||||||||||||||||||||||||
Long-Term Debt | ||||||||||||||||||||||||||||
The Company’s long-term debt outstanding and weighted average interest rates (a) of debt outstanding at December 31 were: | ||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
Mortgage bonds, notes, and other | ||||||||||||||||||||||||||||
DTE Energy Debt, Unsecured | ||||||||||||||||||||||||||||
6.1% due 2014 to 2033 | $ | 1,297 | $ | 1,298 | ||||||||||||||||||||||||
DTE Electric Taxable Debt, Principally Secured | ||||||||||||||||||||||||||||
4.7% due 2014 to 2043 | 4,286 | 3,777 | ||||||||||||||||||||||||||
DTE Electric Tax-Exempt Revenue Bonds (b) | ||||||||||||||||||||||||||||
5.1% due 2014 to 2036 | 558 | 707 | ||||||||||||||||||||||||||
DTE Gas Taxable Debt, Principally Secured | ||||||||||||||||||||||||||||
5.6% due 2014 to 2042 | 1,029 | 919 | ||||||||||||||||||||||||||
Other Long-Term Debt, Including Non-Recourse Debt | 142 | 153 | ||||||||||||||||||||||||||
7,312 | 6,854 | |||||||||||||||||||||||||||
Less amount due within one year | (694 | ) | (634 | ) | ||||||||||||||||||||||||
$ | 6,618 | $ | 6,220 | |||||||||||||||||||||||||
Securitization bonds | ||||||||||||||||||||||||||||
6.6% due 2015 | $ | 302 | $ | 479 | ||||||||||||||||||||||||
Less amount due within one year | (197 | ) | (177 | ) | ||||||||||||||||||||||||
$ | 105 | $ | 302 | |||||||||||||||||||||||||
Junior Subordinated Debentures | ||||||||||||||||||||||||||||
6.5% due 2061 | $ | 280 | $ | 280 | ||||||||||||||||||||||||
5.25% due 2062 | 200 | 200 | ||||||||||||||||||||||||||
$ | 480 | $ | 480 | |||||||||||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||
(a) | Weighted average interest rates as of December 31, 2013 are shown below the description of each category of debt. | |||||||||||||||||||||||||||
(b) | DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds. | |||||||||||||||||||||||||||
Debt Issuances | ||||||||||||||||||||||||||||
In 2013, the following debt was issued: | ||||||||||||||||||||||||||||
Company | Month Issued | Type | Interest Rate | Maturity | Amount | |||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
DTE Electric | March | Mortgage Bonds (a) | 4 | % | 2043 | $ | 375 | |||||||||||||||||||||
DTE Electric | August | Mortgage Bonds (a) | 3.65 | % | 2024 | 400 | ||||||||||||||||||||||
DTE Energy | November | Senior Notes (a) | 3.85 | % | 2023 | 300 | ||||||||||||||||||||||
DTE Gas | December | Mortgage Bonds (a) | 3.64 | % | 2023 | 50 | ||||||||||||||||||||||
DTE Gas | December | Mortgage Bonds (a) | 3.74 | % | 2025 | 70 | ||||||||||||||||||||||
DTE Gas | December | Mortgage Bonds (a) | 3.94 | % | 2028 | 50 | ||||||||||||||||||||||
$ | 1,245 | |||||||||||||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||
(a) | Proceeds were used for the redemption of long-term debt, repayment of short-term borrowings and general corporate purposes. | |||||||||||||||||||||||||||
Debt Redemptions | ||||||||||||||||||||||||||||
In 2013, the following debt was redeemed: | ||||||||||||||||||||||||||||
Company | Month | Type | Interest Rate | Maturity | Amount | |||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
DTE Electric | March | Securitization Bonds | 6.42 | % | 2013 | $ | 88 | |||||||||||||||||||||
DTE Electric | March | Tax Exempt Revenue Bonds (a) | 5.3 | % | 2030 | 51 | ||||||||||||||||||||||
DTE Electric | April | Other Long-Term Debt | Various | 2013 | 13 | |||||||||||||||||||||||
DTE Gas | April | Senior Notes | 5.26 | % | 2013 | 60 | ||||||||||||||||||||||
DTE Energy | June | Senior Notes | Variable | 2013 | 300 | |||||||||||||||||||||||
DTE Electric | September | Securitization Bonds | 6.62 | % | 2013 | 89 | ||||||||||||||||||||||
DTE Electric | September | Senior Notes | 6.4 | % | 2013 | 250 | ||||||||||||||||||||||
DTE Electric | December | Tax Exempt Revenue Bonds (a) | 5.5 | % | 2030 | 49 | ||||||||||||||||||||||
DTE Electric | December | Tax Exempt Revenue Bonds (a) | 6.75 | % | 2038 | 50 | ||||||||||||||||||||||
DTE Energy | Various | Other Long-Term Debt | Various | 2013 | 11 | |||||||||||||||||||||||
$ | 961 | |||||||||||||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||
(a) | DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds. | |||||||||||||||||||||||||||
The following table shows the scheduled debt maturities: | ||||||||||||||||||||||||||||
2014 | 2015 | 2016 | 2017 | 2018 | 2019 and | Total | ||||||||||||||||||||||
Thereafter | ||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
Amount to mature | $ | 891 | $ | 476 | $ | 465 | $ | 9 | $ | 407 | $ | 5,846 | $ | 8,094 | ||||||||||||||
Junior Subordinated Debentures | ||||||||||||||||||||||||||||
At December 31, 2013, the Company had $280 million of 6.5% Junior Subordinated Debentures due 2061 and $200 million of 5.25% Junior Subordinated Debentures due 2062. The Company has the right to defer interest payments on the debt securities. Should the Company exercise this right, it cannot declare or pay dividends on, or redeem, purchase or acquire, any of its capital stock during the deferral period. Any deferred interest payments will bear additional interest at the rate associated with the related debt issue. | ||||||||||||||||||||||||||||
Cross Default Provisions | ||||||||||||||||||||||||||||
Substantially all of the net utility properties of DTE Electric and DTE Gas are subject to the lien of mortgages. Should DTE Electric or DTE Gas fail to timely pay their indebtedness under these mortgages, such failure may create cross defaults in the indebtedness of DTE Energy. |
Preferred_and_Preferenced_Secu
Preferred and Preferenced Securities (Notes) | 12 Months Ended | |||||||||
Dec. 31, 2013 | ||||||||||
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract] | ' | |||||||||
Preferred and Preference Securities | ' | |||||||||
PREFERRED AND PREFERENCE SECURITIES | ||||||||||
As of December 31, 2013, the amount of authorized and unissued stock is as follows: | ||||||||||
Company | Type of Stock | Par Value | Shares Authorized | |||||||
DTE Energy | Preferred | $ | — | 5,000,000 | ||||||
DTE Electric | Preferred | $ | 100 | 6,747,484 | ||||||
DTE Electric | Preference | $ | 1 | 30,000,000 | ||||||
DTE Gas | Preferred | $ | 1 | 7,000,000 | ||||||
DTE Gas | Preference | $ | 1 | 4,000,000 | ||||||
ShortTerm_Credit_Arrangements_
Short-Term Credit Arrangements and Borrowings (Notes) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Short-term Debt [Abstract] | ' | |||||||||||||||
Short-Term Credit Arrangements and Borrowings | ' | |||||||||||||||
SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS | ||||||||||||||||
DTE Energy and its wholly owned subsidiaries, DTE Electric and DTE Gas, have unsecured revolving credit agreements with a syndicate of 19 banks that can be used for general corporate borrowings, but are intended to provide liquidity support for each of the companies’ commercial paper programs. No one bank provides more than 8.7% of the commitment in any facility. Borrowings under the facilities are available at prevailing short-term interest rates. Additionally, DTE Energy has other facilities to support letter of credit issuance. | ||||||||||||||||
The agreements require the Company to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. In the agreements, “total funded debt” means all indebtedness of the Company and its consolidated subsidiaries, including capital lease obligations, hedge agreements and guarantees of third parties’ debt, but excluding contingent obligations, nonrecourse and junior subordinated debt and certain equity-linked securities and, except for calculations at the end of the second quarter, certain DTE Gas short-term debt. “Capitalization” means the sum of (a) total funded debt plus (b) “consolidated net worth,” which is equal to consolidated total stockholders’ equity of the Company and its consolidated subsidiaries (excluding pension effects under certain FASB statements), as determined in accordance with accounting principles generally accepted in the United States of America. At December 31, 2013, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric and DTE Gas are 0.48 to 1, 0.50 to 1 and 0.48 to 1, respectively, and are in compliance with this financial covenant. The availability under the facilities in place at December 31, 2013 is shown in the following table: | ||||||||||||||||
DTE Energy | DTE Electric | DTE Gas | Total | |||||||||||||
(In millions) | ||||||||||||||||
Unsecured letter of credit facility, expiring in May 2014 | $ | 50 | $ | — | $ | — | $ | 50 | ||||||||
Unsecured letter of credit facility, expiring in August 2015 | 125 | — | — | 125 | ||||||||||||
Unsecured revolving credit facility, expiring April 2018 | 1,200 | 300 | 300 | 1,800 | ||||||||||||
1,375 | 300 | 300 | 1,975 | |||||||||||||
Amounts outstanding at December 31, 2013: | ||||||||||||||||
Commercial paper issuances | 35 | — | 96 | 131 | ||||||||||||
Letters of credit | 244 | — | — | 244 | ||||||||||||
279 | — | 96 | 375 | |||||||||||||
Net availability at December 31, 2013 | $ | 1,096 | $ | 300 | $ | 204 | $ | 1,600 | ||||||||
The Company has other outstanding letters of credit which are not included in the above described facilities totaling approximately $53 million which are used for various corporate purposes. | ||||||||||||||||
The weighted average interest rate for short-term borrowings was 0.2% and 0.4% at December 31, 2013 and 2012, respectively. | ||||||||||||||||
In conjunction with maintaining certain exchange traded risk management positions, the Company may be required to post cash collateral with its clearing agent. The Company has a demand financing agreement for up to $100 million with its clearing agent. The agreement, as amended, also allows for up to $50 million of additional margin financing provided that the Company posts a letter of credit for the incremental amount. At December 31, 2013, a $50 million letter of credit was in place, raising the capacity under this facility to $150 million. The $50 million letter of credit is included in the table above. The amount outstanding under this agreement was $138 million and $65 million at December 31, 2013 and 2012, respectively. |
Capital_and_Operating_Leases_N
Capital and Operating Leases (Notes) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Capital and Operating Leases [Abstract] | ' | |||||||
Capital and Operating Leases | ' | |||||||
CAPITAL AND OPERATING LEASES | ||||||||
Lessee — The Company leases various assets under capital and operating leases, including coal railcars, office buildings, a warehouse, computers, vehicles and other equipment. The lease arrangements expire at various dates through 2046. | ||||||||
Future minimum lease payments under non-cancelable leases at December 31, 2013 were: | ||||||||
Capital | Operating | |||||||
Leases | Leases | |||||||
(In millions) | ||||||||
2014 | $ | 8 | $ | 35 | ||||
2015 | 8 | 31 | ||||||
2016 | 3 | 27 | ||||||
2017 | — | 25 | ||||||
2018 | — | 20 | ||||||
Thereafter | — | 92 | ||||||
Total minimum lease payments | $ | 19 | $ | 230 | ||||
Less imputed interest | 1 | |||||||
Present value of net minimum lease payments | 18 | |||||||
Less current portion | 7 | |||||||
Non-current portion | $ | 11 | ||||||
Rental expense for operating leases was $34 million in 2013, $36 million in 2012, and $40 million in 2011. | ||||||||
Lessor - Capital Lease — The Company leases a portion of its pipeline system to the Vector Pipeline through a capital lease contract that expires in 2020, with renewal options extending for five years. The Company owns a 40% interest in the Vector Pipeline. In addition, the Company has an energy services agreement, a portion of which is accounted for as a capital lease. The agreement expires in 2019, with a three or five year renewal option. The components of the net investment in the capital leases at December 31, 2013, were as follows: | ||||||||
(In millions) | ||||||||
2014 | $ | 12 | ||||||
2015 | 12 | |||||||
2016 | 12 | |||||||
2017 | 12 | |||||||
2018 | 12 | |||||||
Thereafter | 19 | |||||||
Total minimum future lease receipts | 79 | |||||||
Residual value of leased pipeline | 40 | |||||||
Less unearned income | (40 | ) | ||||||
Net investment in capital lease | 79 | |||||||
Less current portion | (5 | ) | ||||||
$ | 74 | |||||||
Commitments_and_Contingencies_
Commitments and Contingencies (Notes) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Commitments and Contingencies Disclosure [Abstract] | ' | |||
Commitments and Contingencies | ' | |||
COMMITMENTS AND CONTINGENCIES | ||||
Environmental | ||||
Electric | ||||
Air - DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. Since 2005, the EPA and the State of Michigan have issued additional emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to additional controls on fossil-fueled power plants to reduce nitrogen oxide, sulfur dioxide, mercury and other emissions. To comply with these requirements, DTE Electric has spent approximately $2 billion through 2013. The Company estimates DTE Electric will make capital expenditures of approximately $280 million in 2014 and up to approximately $1.2 billion of additional capital expenditures through 2021 based on current regulations. Further, additional rulemakings are expected over the next few years which could require additional controls for sulfur dioxide, nitrogen oxides and other hazardous air pollutants. The Cross State Air Pollution Rule (CSAPR), finalized in July 2011, requires further reductions of sulfur dioxide and nitrogen oxides emissions beginning in 2012. On December 30, 2011, the U.S. Court of Appeals for the District of Columbia (D.C.) Circuit granted the motions to stay the rule, leaving DTE Electric temporarily subject to the previously existing Clean Air Interstate Rule (CAIR). On August 21, 2012, the Court issued its decision, vacating CSAPR and leaving CAIR in place. The EPA's petition seeking a rehearing of the U.S. Court of Appeals' decision regarding the CSAPR was denied on January 24, 2013. On June 24, 2013, the U.S. Supreme Court granted the EPA's petition asking the Court to review the D.C. Circuit Court's decision on CSAPR. A ruling by the Supreme Court is expected in 2014. Notwithstanding the appeal filed with the Supreme Court, the EPA and a number of states have started working on the framework of revised CSAPR regulations which we anticipate to be proposed in the next few years. | ||||
The Mercury and Air Toxics Standard (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule, was finalized on December 16, 2011. The MATS rule requires reductions of mercury and other hazardous air pollutants beginning in April 2015, with a potential extension to April 2016. DTE Electric has requested and been granted compliance date extensions for some units to April 2016. DTE Electric has tested technologies to determine technological and economic feasibility as MATS compliance alternatives to Flue Gas Desulfurization (FGD) systems. Implementation of Dry Sorbent Injection (DSI) and Activated Carbon Injection (ACI) technologies will allow several units that would not have been economical for FGD installations to continue operation in compliance with MATS. | ||||
In July 2009, DTE Energy received a Notice of Violation/Finding of Violation (NOV/FOV) from the EPA alleging, among other things, that five DTE Electric power plants violated New Source Performance standards, Prevention of Significant Deterioration requirements, and operating permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations related to a project and outage at Unit 2 of the Monroe Power Plant. In March 2013, DTE Energy received a supplemental NOV from the EPA relating to the July 2009 NOV/FOV. The supplemental NOV alleged additional violations relating to the New Source Review provisions under the Clean Air Act, among other things. | ||||
In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant, but not relating to the July 2009 NOV/FOV. Among other relief, the EPA requested the court to require DTE Electric to install and operate the best available control technology at Unit 2 of the Monroe Power Plant. Further, the EPA requested the court to issue a preliminary injunction to require DTE Electric to (i) begin the process of obtaining the necessary permits for the Monroe Unit 2 modification and (ii) offset the pollution from Monroe Unit 2 through emissions reductions from DTE Electric's fleet of coal-fired power plants until the new control equipment is operating. On August 23, 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. The EPA and Sierra Club motions are currently pending with the U.S. District Court Judge. | ||||
DTE Energy and DTE Electric believe that the plants identified by the EPA, including Unit 2 of the Monroe Power Plant, have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution. | ||||
On March 13, 2013, the Sierra Club filed suit against DTE Energy and DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,499 6-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin DTE Energy and DTE Electric from operating the power plants except in complete compliance with applicable laws and permit requirements, pay civil penalties, conduct beneficial environmental mitigation projects, pay attorney fees and require the installation of any necessary pollution controls or to convert and/or operate the plants' boilers on natural gas to avoid additional violations and to off-set historic unlawful emissions. In December 2013, a U.S. District Court judge issued an order dismissing, without prejudice, the plaintiff's complaint allowing them to file an amended complaint by January 17, 2014. The order dismissing the complaint resulted from a considerable number of plaintiff's claims being time barred based on the statute of limitations. On January 17, 2014, the plaintiffs filed an amended complaint for the period January 13, 2008 - June 30, 2012, reducing the total number of 6-minute periods from 1,499 to 1,139. DTE Energy and DTE Electric plan to file an answer to the amended complaint in the first quarter of 2014. The resolution of this matter is not expected to have a material effect on the Company's operations or financial statements. | ||||
Water - In response to an EPA regulation, DTE Electric would be required to examine alternatives for reducing the environmental impacts of the cooling water intake structures at several of its facilities. Based on the results of completed studies and expected future studies, DTE Electric may be required to install technologies to reduce the impacts of the water intake structures. The initial rule published in 2004 was subsequently remanded and a proposed rule published in 2011. The proposed rule specified an eight year compliance timeline. Final action on this rule has been delayed and is expected in 2014. Depending on final regulations, its requirements may require modifications to some existing intake structures and could impact the rates we charge our customers. It is not possible to quantify the impact of those expected rulemakings at this time. | ||||
On April 19, 2013, the EPA proposed revised steam electric effluent guidelines regulating wastewater streams from coal-fired power plants including multiple possible options for compliance. The rules are expected to be finalized by May 2014. DTE Electric has provided comments to the EPA. However, it is not possible at this time to quantify the impacts of these developing requirements. | ||||
Contaminated and Other Sites — Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke or oil. The facilities, which produced gas, have been designated as manufactured gas plant (MGP) sites. DTE Electric conducted remedial investigations at contaminated sites, including three former MGP sites. The investigations have revealed contamination related to the by-products of gas manufacturing at each site. In addition to the MGP sites, the Company is also in the process of cleaning up other contaminated sites, including the area surrounding an ash landfill, electrical distribution substations, electric generating power plants, and underground and aboveground storage tank locations. The findings of these investigations indicated that the estimated cost to remediate these sites is expected to be incurred over the next several years. At December 31, 2013 and 2012, the Company had $8 million and $9 million, respectively, accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company believes that the likelihood of a materially greater liability than the accrued amount is remote based on current knowledge of the conditions at each site. | ||||
DTE Electric owns and operates three permitted engineered ash storage facilities to dispose of fly ash from coal fired power plants. The EPA has published proposed rules to regulate coal ash under the authority of the Resources Conservation and Recovery Act (RCRA). The proposed rule published in June 2010 contains two primary regulatory options to regulate coal ash residue. The EPA is currently considering either designating coal ash as a “Hazardous Waste” as defined by RCRA or regulating coal ash as non-hazardous waste under RCRA. Agencies and legislatures have urged the EPA to regulate coal ash as a non-hazardous waste. If the EPA designates coal ash as a hazardous waste, the agency could apply some, or all, of the disposal and reuse standards that have been applied to other existing hazardous wastes to disposal and reuse of coal ash. Some of the regulatory actions currently being contemplated could have a significant impact on our operations and financial position and the rates we charge our customers. It is not possible to quantify the impact of those expected rulemakings at this time. | ||||
Gas | ||||
Contaminated Sites — Gas segment, owned or previously owned, 15 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. In addition to the MGP sites, the Company is also in the process of cleaning up other contaminated sites. Cleanup activities associated with these sites will be conducted over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. As of December 31, 2013 and 2012, the Company had $28 million and $29 million, accrued for remediation, respectively. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company anticipates the cost amortization methodology approved by the MPSC for DTE Gas, which allows DTE Gas to amortize the MGP costs over a ten-year period beginning with the year subsequent to the year the MGP costs were incurred and the cost deferral and rate recovery mechanism for Citizens approved by the City of Adrian, will prevent environmental costs from having a material adverse impact on the Company’s results of operations. | ||||
Non-utility | ||||
The Company’s non-utility businesses are subject to a number of environmental laws and regulations dealing with the protection of the environment from various pollutants. | ||||
The Michigan coke battery facility received and responded to information requests from the EPA that resulted in the issuance of a NOV in June 2007 alleging potential maximum achievable control technologies and new source review violations. The EPA is in the process of reviewing the Company’s position of demonstrated compliance and has not initiated escalated enforcement. At this time, the Company cannot predict the impact of this issue. Furthermore, the Michigan coke battery facility is the subject of an investigation by the MDEQ concerning visible emissions readings that resulted from the Company self reporting to MDEQ questionable activities by an employee of a contractor hired by the Company to perform the visible emissions readings. At this time, the Company cannot predict the impact of this investigation. | ||||
The Company received two NOVs from the Pennsylvania Department of Environmental Protection (PADEP) in 2010 alleging violations of the permit for the Pennsylvania coke battery facility in connection with coal pile storm water runoff. The Company has implemented best management practices to address this issue. The Company recently received a permit to upgrade its existing waste water treatment system and is currently seeking a permit from the PADEP to upgrade its wastewater treatment technology to a biological treatment facility. The Company expects to spend less than $3 million on the existing waste water treatment system to comply with existing water discharge requirements and to upgrade its coal pile storm water runoff management program. | ||||
The Company believes that its non-utility businesses are substantially in compliance with all environmental requirements, other than as noted above. | ||||
Other | ||||
In March 2011, the EPA finalized a new set of regulations regarding the identification of non-hazardous secondary materials that are considered solid waste, industrial boiler and process heater maximum achievable control technologies (IBMACT) for major and area sources, and commercial/industrial solid waste incinerator new source performance standard and emission guidelines (CISWI). The effective dates of the major source IBMACT and CISWI regulations were stayed and a re-proposal was issued by the EPA in December 2011. Final IBMACT and CISWI were issued by the EPA in December 2012. The Company is developing compliance plans to upgrade or convert existing industrial boilers to natural gas and to perform required energy assessments in compliance with the applicable new standards. Capital costs for the boiler conversions and the expenses for the one-time energy assessments are not expected to be material. | ||||
In 2010, the EPA finalized a new 1-hour sulfur dioxide ambient air quality standard that requires states to submit plans for non-attainment areas to be in compliance by 2017. Michigan's non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Preliminary modeling runs by the MDEQ suggest that emission reductions may be required by significant sources of sulfur dioxide emissions in these areas, including DTE Electric power plants and our Michigan coke battery. The state implementation plan process is in the gathering stage and any required emission reductions for DTE Energy sources to meet the standard cannot be estimated currently. | ||||
Nuclear Operations | ||||
Property Insurance | ||||
DTE Electric maintains property insurance policies specifically for the Fermi 2 plant. These policies cover such items as replacement power and property damage. The Nuclear Electric Insurance Limited (NEIL) is the primary supplier of the insurance policies. | ||||
DTE Electric maintains a policy for extra expenses, including replacement power costs necessitated by Fermi 2’s unavailability due to an insured event. This policy has a 12-week waiting period and provides an aggregate $490 million of coverage over a three-year period. | ||||
DTE Electric has $500 million in primary coverage and $2.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property and decommissioning. The combined coverage limit for total property damage is $2.75 billion, subject to a $1 million deductible. As of April 1, 2013, the total limit for property damage for non-nuclear events is $1.8 billion and an aggregate of $327 million of coverage for extra expenses over a two-year period. | ||||
In 2007, the Terrorism Risk Insurance Extension Act of 2005 (TRIA) was extended through December 31, 2014. A major change in the extension is the inclusion of “domestic” acts of terrorism in the definition of covered or “certified” acts. For multiple terrorism losses caused by acts of terrorism not covered under the TRIA occurring within one year after the first loss from terrorism, the NEIL policies would make available to all insured entities up to $3.2 billion, plus any amounts recovered from reinsurance, government indemnity, or other sources to cover losses. | ||||
Under the NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $34 million per event if the loss associated with any one event at any nuclear plant should exceed the accumulated funds available to NEIL. | ||||
Public Liability Insurance | ||||
As required by federal law, DTE Electric maintains $375 million of public liability insurance for a nuclear incident. For liabilities arising from a terrorist act outside the scope of TRIA, the policy is subject to one industry aggregate limit of $300 million. Further, under the Price-Anderson Amendments Act of 2005, deferred premium charges up to $127.3 million could be levied against each licensed nuclear facility, but not more than $19 million per year per facility. Thus, deferred premium charges could be levied against all owners of licensed nuclear facilities in the event of a nuclear incident at any of these facilities. | ||||
Nuclear Fuel Disposal Costs | ||||
In accordance with the Federal Nuclear Waste Policy Act of 1982, DTE Electric has a contract with the U.S. Department of Energy (DOE) for the future storage and disposal of spent nuclear fuel from Fermi 2. DTE Electric is obligated to pay the DOE a fee of 1 mill per kWh of Fermi 2 electricity generated and sold. The fee is a component of nuclear fuel expense. The DOE's Yucca Mountain Nuclear Waste Repository program for the acceptance and disposal of spent nuclear fuel was terminated in 2011. DTE Electric currently employs a spent nuclear fuel storage strategy utilizing a fuel pool. The Company continues to develop its on-site dry cask storage facility and has scheduled the initial offload from the spent fuel pool in 2014. The dry cask storage facility is expected to provide sufficient spent fuel storage capability for the life of the plant as defined by the original operating license. | ||||
DTE Electric is a party in the litigation against the DOE for both past and future costs associated with the DOE's failure to accept spent nuclear fuel under the timetable set forth in the Federal Nuclear Waste Policy Act of 1982. In July 2012, DTE Electric executed a settlement agreement with the federal government for costs associated with the DOE's delay in acceptance of spent nuclear fuel from Fermi 2 for permanent storage. The settlement provided for a payment of approximately $48 million, received in August 2012, for delay-related costs experienced by DTE Electric through 2010, and a claims process for submittal of delay-related costs from 2011 through 2013. DTE Electric has begun the claims process and claims are being settled on a timely basis. The settlement proceeds reduced the cost of the dry cask storage facility assets. In January 2014, the settlement agreement was extended through 2016. The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action. | ||||
In February 2013, the U.S. Court of Appeals for the District of Columbia (COA) granted a motion to reopen the fee adequacy litigation to review the DOE's latest fee adequacy report which was released in January 2013. In November 2013, the COA issued a decision ordering the DOE to submit a proposal to Congress to reduce the nuclear waste fee to zero until the DOE enacts an alternative nuclear waste management plan. In January 2014, the DOE submitted such a proposal to Congress that will take effect in 90 legislative calendar days, absent legislative action to the contrary. Simultaneously, the DOE filed a petition for rehearing of the November 2013 decision with the COA. DTE Electric continues to pay fees to the U.S. government's nuclear waste fund pending further developments in this proceeding. | ||||
Synthetic Fuel Guarantees | ||||
The Company discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. The Company provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price and tax-related obligations and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at December 31, 2013 is approximately $1.1 billion. Payment under these guarantees is considered remote. | ||||
Reduced Emissions Fuel Guarantees | ||||
The Company has provided certain guarantees and indemnities in conjunction with the sales of interests in its reduced emissions fuel facilities. The guarantees cover potential commercial, environmental, and tax-related obligations and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at December 31, 2013 is approximately $144 million. Payment under these guarantees is considered remote. | ||||
Other Guarantees | ||||
In certain limited circumstances, the Company enters into contractual guarantees. The Company may guarantee another entity’s obligation in the event it fails to perform. The Company may provide guarantees in certain indemnification agreements. Finally, the Company may provide indirect guarantees for the indebtedness of others. The Company’s guarantees are not individually material with maximum potential payments totaling $60 million at December 31, 2013. Payment under these guarantees is considered remote. | ||||
The Company is periodically required to obtain performance surety bonds in support of obligations to various governmental entities and other companies in connection with its operations. As of December 31, 2013, the Company had approximately $41 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, the Company would be obligated to reimburse the issuer of the performance bond. The Company is released from the performance bonds as the contractual performance is completed and does not believe that a material amount of any currently outstanding performance bonds will be called. | ||||
Labor Contracts | ||||
There are several bargaining units for the Company's approximately 4,900 represented employees. The majority of the represented employees are under contracts that expire in 2016 and 2017. | ||||
Purchase Commitments | ||||
As of December 31, 2013, the Company was party to numerous long-term purchase commitments relating to a variety of goods and services required for the Company’s business. These agreements primarily consist of fuel supply commitments, renewable energy contracts and energy trading contracts. The Company estimates that these commitments will be approximately $8.6 billion from 2014 through 2051 as detailed in the following table: | ||||
(In millions) | ||||
2014 | $ | 2,617 | ||
2015 | 1,195 | |||
2016 | 643 | |||
2017 | 345 | |||
2018 | 311 | |||
2019 — 2051 | 3,487 | |||
$ | 8,598 | |||
The Company also estimates that 2014 capital expenditures will be approximately $2.3 billion. The Company has made certain commitments in connection with expected capital expenditures. | ||||
Bankruptcies | ||||
The Company purchases and sells electricity, natural gas, coal, coke and other energy products from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail, financial and other industries. Certain of its customers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Company regularly reviews contingent matters relating to these customers and its purchase and sale contracts and records provisions for amounts considered at risk of probable loss. The Company believes its accrued amounts are adequate for probable loss. | ||||
The Company's utilities provide services to the city of Detroit, Michigan (Detroit). Detroit filed for Chapter 9 bankruptcy protection on July 18, 2013. The Company had pre-petition accounts receivable of approximately $20 million outstanding as of the bankruptcy filing date. Detroit has been paying amounts owed in a timely manner and its accounts are substantially current. The Company does not expect Detroit's bankruptcy filing to have a material impact on its financial results. | ||||
Other Contingencies | ||||
The Company is involved in certain other legal, regulatory, administrative and environmental proceedings before various courts, arbitration panels and governmental agencies concerning claims arising in the ordinary course of business. These proceedings include certain contract disputes, additional environmental reviews and investigations, audits, inquiries from various regulators, and pending judicial matters. The Company cannot predict the final disposition of such proceedings. The Company regularly reviews legal matters and records provisions for claims that it can estimate and are considered probable of loss. The resolution of these pending proceedings is not expected to have a material effect on the Company’s operations or financial statements in the periods they are resolved. | ||||
See Notes 4 and 11 for a discussion of contingencies related to derivatives and regulatory matters. |
Retirement_Benefits_and_Truste
Retirement Benefits and Trusteed Assets (Notes) | 12 Months Ended | |||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||
Defined Benefit Pension Plans and Defined Benefit Postretirement Plans Disclosure [Abstract] | ' | |||||||||||||||||||||||||||||||
Retirement Benefits and Trusteed Assets | ' | |||||||||||||||||||||||||||||||
RETIREMENT BENEFITS AND TRUSTEED ASSETS | ||||||||||||||||||||||||||||||||
Pension Plan Benefits | ||||||||||||||||||||||||||||||||
The Company has qualified defined benefit retirement plans for eligible represented and non-represented employees. The plans are noncontributory and cover most employees. The plans provide traditional retirement benefits based on the employees’ years of benefit service, average final compensation and age at retirement. In addition, certain represented and non-represented employees are covered under cash balance provisions that determine benefits on annual employer contributions and interest credits. The Company also maintains supplemental nonqualified, noncontributory, retirement benefit plans for selected management employees. These plans provide for benefits that supplement those provided by DTE Energy’s other retirement plans. | ||||||||||||||||||||||||||||||||
Effective January 1, 2012 for non-represented employees, and in June 2011 and March 2013 for the majority of represented employees, the Company discontinued offering a defined benefit retirement plan. In its place, the Company will annually contribute an amount equivalent to 4% (8% for certain DTE Gas represented employees) of an employee's eligible pay to the employee's defined contribution retirement savings plan. | ||||||||||||||||||||||||||||||||
The Company’s policy is to fund pension costs by contributing amounts consistent with the provisions of the Pension Protection Act of 2006 and additional amounts when it deems appropriate. The Company contributed $277 million to its qualified pension plans in 2013. At the discretion of management, and depending upon financial market conditions, we anticipate making up to $345 million in contributions to the pension plans in 2014. | ||||||||||||||||||||||||||||||||
Net pension cost includes the following components: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Service cost | $ | 94 | $ | 82 | $ | 69 | ||||||||||||||||||||||||||
Interest cost | 192 | 204 | 202 | |||||||||||||||||||||||||||||
Expected return on plan assets | (266 | ) | (244 | ) | (246 | ) | ||||||||||||||||||||||||||
Amortization of: | ||||||||||||||||||||||||||||||||
Net loss | 208 | 176 | 142 | |||||||||||||||||||||||||||||
Prior service cost | — | — | 3 | |||||||||||||||||||||||||||||
Special termination benefits | — | 2 | 2 | |||||||||||||||||||||||||||||
Net pension cost | $ | 228 | $ | 220 | $ | 172 | ||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income | ||||||||||||||||||||||||||||||||
Net actuarial (gain) loss | $ | (581 | ) | $ | 395 | |||||||||||||||||||||||||||
Amortization of net actuarial loss | (208 | ) | (178 | ) | ||||||||||||||||||||||||||||
Total recognized Regulatory assets and Other comprehensive income | $ | (789 | ) | $ | 217 | |||||||||||||||||||||||||||
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income | $ | (561 | ) | $ | 437 | |||||||||||||||||||||||||||
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 151 | $ | 202 | ||||||||||||||||||||||||||||
The following table reconciles the obligations, assets and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in the Consolidated Statements of Financial Position at December 31: | ||||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Accumulated benefit obligation, end of year | $ | 4,068 | $ | 4,349 | ||||||||||||||||||||||||||||
Change in projected benefit obligation | ||||||||||||||||||||||||||||||||
Projected benefit obligation, beginning of year | $ | 4,729 | $ | 4,195 | ||||||||||||||||||||||||||||
Service cost | 94 | 82 | ||||||||||||||||||||||||||||||
Interest cost | 192 | 204 | ||||||||||||||||||||||||||||||
Plan amendments | (3 | ) | — | |||||||||||||||||||||||||||||
Actuarial (gain) loss | (400 | ) | 474 | |||||||||||||||||||||||||||||
Special termination benefits | — | 2 | ||||||||||||||||||||||||||||||
Benefits paid | (232 | ) | (228 | ) | ||||||||||||||||||||||||||||
Projected benefit obligation, end of year | $ | 4,380 | $ | 4,729 | ||||||||||||||||||||||||||||
Change in plan assets | ||||||||||||||||||||||||||||||||
Plan assets at fair value, beginning of year | $ | 3,223 | $ | 2,886 | ||||||||||||||||||||||||||||
Actual return on plan assets | 445 | 325 | ||||||||||||||||||||||||||||||
Company contributions | 284 | 240 | ||||||||||||||||||||||||||||||
Benefits paid | (232 | ) | (228 | ) | ||||||||||||||||||||||||||||
Plan assets at fair value, end of year | $ | 3,720 | $ | 3,223 | ||||||||||||||||||||||||||||
Funded status of the plans | $ | (660 | ) | $ | (1,506 | ) | ||||||||||||||||||||||||||
Amount recorded as: | ||||||||||||||||||||||||||||||||
Current liabilities | $ | (7 | ) | $ | (8 | ) | ||||||||||||||||||||||||||
Noncurrent liabilities | (653 | ) | (1,498 | ) | ||||||||||||||||||||||||||||
$ | (660 | ) | $ | (1,506 | ) | |||||||||||||||||||||||||||
Amounts recognized in Accumulated other comprehensive loss, pre-tax | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 174 | $ | 205 | ||||||||||||||||||||||||||||
Prior service (credit) | (1 | ) | (2 | ) | ||||||||||||||||||||||||||||
$ | 173 | $ | 203 | |||||||||||||||||||||||||||||
Amounts recognized in Regulatory assets (see Note 11) | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 1,654 | $ | 2,413 | ||||||||||||||||||||||||||||
Prior service cost | 6 | 7 | ||||||||||||||||||||||||||||||
$ | 1,660 | $ | 2,420 | |||||||||||||||||||||||||||||
At December 31, 2013, the benefits related to the Company’s qualified and nonqualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows: | ||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
2014 | $ | 242 | ||||||||||||||||||||||||||||||
2015 | 250 | |||||||||||||||||||||||||||||||
2016 | 258 | |||||||||||||||||||||||||||||||
2017 | 268 | |||||||||||||||||||||||||||||||
2018 | 280 | |||||||||||||||||||||||||||||||
2019-2023 | 1,529 | |||||||||||||||||||||||||||||||
$ | 2,827 | |||||||||||||||||||||||||||||||
Assumptions used in determining the projected benefit obligation and net pension costs are listed below: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
Projected benefit obligation | ||||||||||||||||||||||||||||||||
Discount rate | 4.95 | % | 4.15 | % | 5 | % | ||||||||||||||||||||||||||
Rate of compensation increase | 4.2 | % | 4.2 | % | 4.2 | % | ||||||||||||||||||||||||||
Net pension costs | ||||||||||||||||||||||||||||||||
Discount rate | 4.15 | % | 5 | % | 5.5 | % | ||||||||||||||||||||||||||
Rate of compensation increase | 4.2 | % | 4.2 | % | 4 | % | ||||||||||||||||||||||||||
Expected long-term rate of return on plan assets | 8.25 | % | 8.25 | % | 8.5 | % | ||||||||||||||||||||||||||
The Company employs a formal process in determining the long-term rate of return for various asset classes. Management reviews historic financial market risks and returns and long-term historic relationships between the asset classes of equities, fixed income and other assets, consistent with the widely accepted capital market principle that asset classes with higher volatility generate a greater return over the long-term. Current market factors such as inflation, interest rates, asset class risks and asset class returns are evaluated and considered before long-term capital market assumptions are determined. The long-term portfolio return is also established employing a consistent formal process, with due consideration of diversification, active investment management and rebalancing. Peer data is reviewed to check for reasonableness. As a result of this process, the Company has long-term rate of return assumptions for its pension plans of 7.75% and other postretirement benefit plans of 8.00%, for 2014. The Company believes these rates are a reasonable assumption for the long-term rate of return on its plan assets for 2014 given its investment strategy. | ||||||||||||||||||||||||||||||||
The Company employs a total return investment approach whereby a mix of equities, fixed income and other investments are used to maximize the long-term return on plan assets consistent with prudent levels of risk, with consideration given to the liquidity needs of the plan. Risk tolerance is established through consideration of future plan cash flows, plan funded status, and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks, growth and value stocks, and large and small market capitalizations. Fixed income securities generally include market and long duration bonds of companies from diversified industries, mortgage-backed securities, non-US securities, bank loans and U.S. Treasuries. Other assets such as private markets and hedge funds are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner, to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies, and quarterly investment portfolio reviews. | ||||||||||||||||||||||||||||||||
Target allocations for pension plan assets as of December 31, 2013 are listed below: | ||||||||||||||||||||||||||||||||
U.S. Large Cap Equity Securities | 22 | % | ||||||||||||||||||||||||||||||
U.S. Small Cap and Mid Cap Equity Securities | 5 | |||||||||||||||||||||||||||||||
Non U.S. Equity Securities | 20 | |||||||||||||||||||||||||||||||
Fixed Income Securities | 25 | |||||||||||||||||||||||||||||||
Hedge Funds and Similar Investments | 20 | |||||||||||||||||||||||||||||||
Private Equity and Other | 8 | |||||||||||||||||||||||||||||||
100 | % | |||||||||||||||||||||||||||||||
Fair Value Measurements for pension plan assets at December 31, 2013 and 2012 (a): | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Asset Category: | ||||||||||||||||||||||||||||||||
Short-term investments (b) | $ | 22 | $ | — | $ | — | $ | 22 | $ | — | $ | 24 | $ | — | $ | 24 | ||||||||||||||||
Equity securities | ||||||||||||||||||||||||||||||||
U.S. Large Cap (c) | 896 | — | — | 896 | 688 | 44 | — | 732 | ||||||||||||||||||||||||
U.S. Small/Mid Cap (d) | 221 | — | — | 221 | 153 | 5 | — | 158 | ||||||||||||||||||||||||
Non U.S. (e) | 611 | 130 | — | 741 | 530 | 120 | — | 650 | ||||||||||||||||||||||||
Fixed income securities (f) | 16 | 921 | — | 937 | 87 | 765 | — | 852 | ||||||||||||||||||||||||
Hedge Funds and Similar Investments (g) | 268 | 70 | 395 | 733 | 209 | 80 | 339 | 628 | ||||||||||||||||||||||||
Private Equity and Other (h) | — | — | 170 | 170 | — | — | 179 | 179 | ||||||||||||||||||||||||
Total | $ | 2,034 | $ | 1,121 | $ | 565 | $ | 3,720 | $ | 1,667 | $ | 1,038 | $ | 518 | $ | 3,223 | ||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||||||
(a) | See Note 3 — Fair Value for a description of levels within the fair value hierarchy. | |||||||||||||||||||||||||||||||
(b) | This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services. | |||||||||||||||||||||||||||||||
(c) | This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(d) | This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(e) | This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(f) | This category includes corporate bonds from diversified industries, U.S. Treasuries, and mortgage-backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(g) | This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing. | |||||||||||||||||||||||||||||||
(h) | This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions. | |||||||||||||||||||||||||||||||
The pension trust holds debt and equity securities directly and indirectly through commingled funds and institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds and institutional mutual funds hold exchange-traded equity or debt securities and are valued based on stated net asset values (NAV). Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustees challenge an assigned price and determine that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair values of securities by comparison of market-based price sources. | ||||||||||||||||||||||||||||||||
Fair Value Measurements Using Significant Unobservable Inputs (Level 3): | ||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||
Hedge Funds | Private Equity | Total | Hedge Funds | Private Equity | Total | |||||||||||||||||||||||||||
and Similar | and Other | and Similar | and Other | |||||||||||||||||||||||||||||
Investments | Investments | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Beginning Balance at January 1 | $ | 339 | $ | 179 | $ | 518 | $ | 296 | $ | 168 | $ | 464 | ||||||||||||||||||||
Total realized/unrealized gains (losses): | ||||||||||||||||||||||||||||||||
Realized gains (losses) | — | 18 | 18 | 18 | (6 | ) | 12 | |||||||||||||||||||||||||
Unrealized gains (losses) | 40 | (14 | ) | 26 | (5 | ) | 12 | 7 | ||||||||||||||||||||||||
Purchases, sales and settlements: | ||||||||||||||||||||||||||||||||
Purchases | 16 | 15 | 31 | 250 | 33 | 283 | ||||||||||||||||||||||||||
Sales | — | (28 | ) | (28 | ) | (220 | ) | (28 | ) | (248 | ) | |||||||||||||||||||||
Ending Balance at December 31 | $ | 395 | $ | 170 | $ | 565 | $ | 339 | $ | 179 | $ | 518 | ||||||||||||||||||||
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period | $ | 38 | $ | 3 | $ | 41 | $ | 16 | $ | 6 | $ | 22 | ||||||||||||||||||||
There were no transfers between Level 3 and Level 2 and there were no significant transfers between Level 2 and Level 1 in the years ended December 31, 2013 and 2012. | ||||||||||||||||||||||||||||||||
Other Postretirement Benefits | ||||||||||||||||||||||||||||||||
The Company provides certain other postretirement health care and life insurance benefits for employees who are eligible for these benefits. The Company’s policy is to fund certain trusts to meet its other postretirement benefit obligations. Separate qualified Voluntary Employees Beneficiary Association (VEBA) and 401(h) trusts exist for represented and non-represented employees. The Company contributed $264 million to its other postretirement medical and life insurance benefit plans during 2013. At the discretion of management, we anticipate making up to $145 million of contributions to the VEBA trusts in 2014. | ||||||||||||||||||||||||||||||||
Starting in 2012, in lieu of offering future employees post-employment health care and life insurance benefits, the Company allocates a fixed amount per year to an account in a tax-exempt trust for each employee. These trusts are managed either by the Company (for non-represented and certain represented groups), or by the Utility Workers of America (UWUA) for Local 223 employees. The cost of these plans was $2 million in 2013 and less than $1 million in 2012. | ||||||||||||||||||||||||||||||||
Beginning in 2013, the Company replaced sponsored retiree medical, prescription drug and dental coverage with a Retiree Health Care Allowance (RHCA). This change applies to both current and future Medicare eligible non-represented retirees, spouses, surviving spouses or same sex domestic partners; as well as future Medicare eligible represented retirees, spouses, surviving spouses or same sex domestic partners. The 2013 RHCA allowance ranged between $3,250 and $3,500 depending on an employee’s date of hire and will increase each year at the lower of the rate of medical inflation or 2%. | ||||||||||||||||||||||||||||||||
Net other postretirement cost includes the following components: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Service cost | $ | 47 | $ | 68 | $ | 64 | ||||||||||||||||||||||||||
Interest cost | 88 | 120 | 121 | |||||||||||||||||||||||||||||
Expected return on plan assets | (110 | ) | (92 | ) | (94 | ) | ||||||||||||||||||||||||||
Amortization of: | ||||||||||||||||||||||||||||||||
Net loss | 64 | 80 | 55 | |||||||||||||||||||||||||||||
Prior service credit | (131 | ) | (27 | ) | (26 | ) | ||||||||||||||||||||||||||
Net transition asset | — | 2 | 2 | |||||||||||||||||||||||||||||
Net other postretirement cost (benefit) | $ | (42 | ) | $ | 151 | $ | 122 | |||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Other changes in plan assets and APBO recognized in Regulatory assets (liabilities) and Other comprehensive income | ||||||||||||||||||||||||||||||||
Net actuarial gain | $ | (353 | ) | $ | (34 | ) | ||||||||||||||||||||||||||
Amortization of net actuarial loss | (64 | ) | (80 | ) | ||||||||||||||||||||||||||||
Prior service credit | (218 | ) | (264 | ) | ||||||||||||||||||||||||||||
Amortization of prior service credit | 131 | 27 | ||||||||||||||||||||||||||||||
Amortization of transition asset | — | (2 | ) | |||||||||||||||||||||||||||||
Total recognized in Regulatory assets (liabilities) and Other comprehensive income | $ | (504 | ) | $ | (353 | ) | ||||||||||||||||||||||||||
Total recognized in net periodic benefit cost, Regulatory assets (liabilities) and Other comprehensive income | $ | (546 | ) | $ | (202 | ) | ||||||||||||||||||||||||||
Estimated amounts to be amortized from Regulatory assets (liabilities) and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 21 | $ | 69 | ||||||||||||||||||||||||||||
Prior service credit | $ | (144 | ) | $ | (91 | ) | ||||||||||||||||||||||||||
The following table reconciles the obligations, assets and funded status of the plans including amounts recorded as Accrued postretirement liability in the Consolidated Statements of Financial Position at December 31: | ||||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Change in accumulated postretirement benefit obligation | ||||||||||||||||||||||||||||||||
Accumulated postretirement benefit obligation, beginning of year | $ | 2,315 | $ | 2,470 | ||||||||||||||||||||||||||||
Service cost | 47 | 68 | ||||||||||||||||||||||||||||||
Interest cost | 88 | 120 | ||||||||||||||||||||||||||||||
Plan amendments | (218 | ) | (264 | ) | ||||||||||||||||||||||||||||
Actuarial (gain) loss | (267 | ) | 5 | |||||||||||||||||||||||||||||
Medicare Part D subsidy | 1 | 6 | ||||||||||||||||||||||||||||||
Benefits paid | (88 | ) | (90 | ) | ||||||||||||||||||||||||||||
Accumulated postretirement benefit obligation, end of year | $ | 1,878 | $ | 2,315 | ||||||||||||||||||||||||||||
Change in plan assets | ||||||||||||||||||||||||||||||||
Plan assets at fair value, beginning of year | $ | 1,153 | $ | 985 | ||||||||||||||||||||||||||||
Actual return on plan assets | 196 | 131 | ||||||||||||||||||||||||||||||
Company contributions | 264 | 140 | ||||||||||||||||||||||||||||||
Benefits paid | (86 | ) | (103 | ) | ||||||||||||||||||||||||||||
Plan assets at fair value, end of year | $ | 1,527 | $ | 1,153 | ||||||||||||||||||||||||||||
Funded status, end of year | $ | (351 | ) | $ | (1,162 | ) | ||||||||||||||||||||||||||
Amount recorded as: | ||||||||||||||||||||||||||||||||
Current liabilities | $ | (1 | ) | $ | (2 | ) | ||||||||||||||||||||||||||
Noncurrent liabilities | (350 | ) | (1,160 | ) | ||||||||||||||||||||||||||||
$ | (351 | ) | $ | (1,162 | ) | |||||||||||||||||||||||||||
Amounts recognized in Accumulated other comprehensive loss, pre-tax | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 29 | $ | 40 | ||||||||||||||||||||||||||||
Prior service credit | (10 | ) | (14 | ) | ||||||||||||||||||||||||||||
Net transition asset | — | (1 | ) | |||||||||||||||||||||||||||||
$ | 19 | $ | 25 | |||||||||||||||||||||||||||||
Amounts recognized in Regulatory assets (liabilities) (See Note 11) | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 321 | $ | 727 | ||||||||||||||||||||||||||||
Prior service credit | (393 | ) | (302 | ) | ||||||||||||||||||||||||||||
Net transition obligation | — | 1 | ||||||||||||||||||||||||||||||
$ | (72 | ) | $ | 426 | ||||||||||||||||||||||||||||
At December 31, 2013, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows: | ||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
2014 | $ | 103 | ||||||||||||||||||||||||||||||
2015 | 110 | |||||||||||||||||||||||||||||||
2016 | 115 | |||||||||||||||||||||||||||||||
2017 | 123 | |||||||||||||||||||||||||||||||
2018 | 130 | |||||||||||||||||||||||||||||||
2019 — 2023 | 724 | |||||||||||||||||||||||||||||||
$ | 1,305 | |||||||||||||||||||||||||||||||
Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs are listed below: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
Accumulated postretirement benefit obligation | ||||||||||||||||||||||||||||||||
Discount rate | 4.95 | % | 4.15 | % | 5 | % | ||||||||||||||||||||||||||
Health care trend rate pre- and post- 65 | 7.5 | / 6.50% | 7 | % | 7 | % | ||||||||||||||||||||||||||
Ultimate health care trend rate | 4.5 | % | 5 | % | 5 | % | ||||||||||||||||||||||||||
Year in which ultimate reached pre- and post- 65 | 2025 / 2024 | 2021 | 2020 | |||||||||||||||||||||||||||||
Other postretirement benefit costs | ||||||||||||||||||||||||||||||||
Discount rate (prior to interim remeasurement) | 4.15 | % | 5 | % | 5.5 | % | ||||||||||||||||||||||||||
Discount rate (post interim remeasurement) | 4.3 | % | N/A | N/A | ||||||||||||||||||||||||||||
Expected long-term rate of return on plan assets | 8.25 | % | 8.25 | % | 8.75 | % | ||||||||||||||||||||||||||
Health care trend rate pre- and post- 65 | 7 | % | 7 | % | 7 | % | ||||||||||||||||||||||||||
Ultimate health care trend rate | 5 | % | 5 | % | 5 | % | ||||||||||||||||||||||||||
Year in which ultimate reached | 2021 | 2020 | 2019 | |||||||||||||||||||||||||||||
A one percentage point increase in health care cost trend rates would have increased the total service cost and interest cost components of benefit costs by $9 million in 2013 and increased the accumulated benefit obligation by $124 million at December 31, 2013. A one percentage point decrease in the health care cost trend rates would have decreased the total service and interest cost components of benefit costs by $8 million in 2013 and would have decreased the accumulated benefit obligation by $108 million at December 31, 2013. | ||||||||||||||||||||||||||||||||
The process used in determining the long-term rate of return for assets and the investment approach for the Company’s other postretirement benefits plans is similar to those previously described for its pension plans. | ||||||||||||||||||||||||||||||||
Target allocations for other postretirement benefit plan assets as of December 31, 2013 are listed below: | ||||||||||||||||||||||||||||||||
U.S. Large Cap Equity Securities | 17 | % | ||||||||||||||||||||||||||||||
U.S. Small Cap and Mid Cap Equity Securities | 4 | |||||||||||||||||||||||||||||||
Non U.S. Equity Securities | 20 | |||||||||||||||||||||||||||||||
Fixed Income Securities | 25 | |||||||||||||||||||||||||||||||
Hedge Funds and Similar Investments | 20 | |||||||||||||||||||||||||||||||
Private Equity and Other | 14 | |||||||||||||||||||||||||||||||
100 | % | |||||||||||||||||||||||||||||||
Fair Value Measurements for other postretirement benefit plan assets at December 31, 2013 and 2012 (a): | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||||||
Asset Category: | (In millions) | |||||||||||||||||||||||||||||||
Short-term investments (b) | $ | 5 | $ | — | $ | — | $ | 5 | $ | 1 | $ | 2 | $ | — | $ | 3 | ||||||||||||||||
Equity securities: | ||||||||||||||||||||||||||||||||
U.S. Large Cap (c) | 302 | — | — | 302 | 189 | 3 | — | 192 | ||||||||||||||||||||||||
U.S. Small/Mid Cap (d) | 147 | — | — | 147 | 105 | — | — | 105 | ||||||||||||||||||||||||
Non U.S. (e) | 282 | 9 | — | 291 | 230 | 7 | — | 237 | ||||||||||||||||||||||||
Fixed income securities (f) | 17 | 350 | — | 367 | 38 | 247 | — | 285 | ||||||||||||||||||||||||
Hedge Funds and Similar Investments (g) | 130 | 25 | 159 | 314 | 102 | 24 | 119 | 245 | ||||||||||||||||||||||||
Private Equity and Other (h) | — | — | 101 | 101 | — | — | 86 | 86 | ||||||||||||||||||||||||
Total | $ | 883 | $ | 384 | $ | 260 | $ | 1,527 | $ | 665 | $ | 283 | $ | 205 | $ | 1,153 | ||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||||||
(a) | See Note 3 — Fair Value for a description of levels within the fair value hierarchy. | |||||||||||||||||||||||||||||||
(b) | This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services. | |||||||||||||||||||||||||||||||
(c) | This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(d) | This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(e) | This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(f) | This category includes corporate bonds from diversified industries, U.S. Treasuries, bank loans and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(g) | This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing. | |||||||||||||||||||||||||||||||
(h) | This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions. | |||||||||||||||||||||||||||||||
The VEBA trusts hold debt and equity securities directly and indirectly through commingled funds and institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds and institutional mutual funds hold exchange-traded equity or debt securities and are valued based on net asset values (NAV). Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustees monitor prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustees challenge an assigned price and determine that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair values of securities by comparison of market-based price sources. | ||||||||||||||||||||||||||||||||
Fair Value Measurements Using Significant Unobservable Inputs (Level 3): | ||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||
Hedge Funds | Private Equity | Total | Hedge Funds | Private Equity | Total | |||||||||||||||||||||||||||
and Similar | and Other | and Similar | and Other | |||||||||||||||||||||||||||||
Investments | Investments | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Beginning Balance at January 1 | $ | 119 | $ | 86 | $ | 205 | $ | 95 | $ | 60 | $ | 155 | ||||||||||||||||||||
Total realized/unrealized gains (losses): | ||||||||||||||||||||||||||||||||
Realized gains (losses) | — | 2 | 2 | 6 | (11 | ) | (5 | ) | ||||||||||||||||||||||||
Unrealized gains | 14 | 7 | 21 | — | 14 | 14 | ||||||||||||||||||||||||||
Purchases, sales and settlements: | ||||||||||||||||||||||||||||||||
Purchases | 26 | 15 | 41 | 86 | 36 | 122 | ||||||||||||||||||||||||||
Sales | — | (9 | ) | (9 | ) | (68 | ) | (13 | ) | (81 | ) | |||||||||||||||||||||
Ending Balance at December 31 | $ | 159 | $ | 101 | $ | 260 | $ | 119 | $ | 86 | $ | 205 | ||||||||||||||||||||
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period | $ | 14 | $ | 9 | $ | 23 | $ | 6 | $ | 2 | $ | 8 | ||||||||||||||||||||
There were no transfers between Level 3 and Level 2 and there were no significant transfers between Level 2 and Level 1 in the years ended December 31, 2013 and 2012. | ||||||||||||||||||||||||||||||||
Interim Re-Measurement of Other Postretirement Benefit Obligation | ||||||||||||||||||||||||||||||||
In March 2013, the Company reached agreements on new four-year labor contracts with certain represented employees under several bargaining units. As a term of the agreements, the Company replaced sponsored retiree medical, prescription drug and dental coverage for future Medicare eligible retirees with a Retiree Health Care Allowance (RHCA) account of $3,250 per year. The modification in retiree health coverage will reduce future other postretirement benefit costs. | ||||||||||||||||||||||||||||||||
Based on the impact of such benefit cost savings on the consolidated financial statements, the Company re-measured its retiree health plan as of March 31, 2013. In performing the re-measurement, the Company updated its significant actuarial assumptions, including an adjustment to the discount rate from 4.15% at December 31, 2012 to 4.30% at March 31, 2013. Plan assets were also updated to reflect fair value as of the re-measurement date. Beginning April 2013, net other postretirement benefit costs were recorded based on the updated actuarial assumptions and benefit changes resulting from the new labor contracts. | ||||||||||||||||||||||||||||||||
Healthcare Legislation | ||||||||||||||||||||||||||||||||
In December 2003, the Medicare Act was signed into law which provides for a non-taxable federal subsidy to sponsors of retiree health care benefit plans that provide a benefit that is at least “actuarially equivalent” to the benefit established by law. The effects of the subsidy reduced net periodic other postretirement benefit costs by $1 million in 2013, $6 million in 2012 and $6 million in 2011. | ||||||||||||||||||||||||||||||||
Grantor Trust | ||||||||||||||||||||||||||||||||
DTE Gas maintains a Grantor Trust to fund other postretirement benefit obligations that invests in life insurance contracts and income securities. Employees and retirees have no right, title or interest in the assets of the Grantor Trust, and DTE Gas can revoke the trust subject to providing the MPSC with prior notification. The Company accounts for its investment at fair value, approximately $17 million and $14 million at December 31, 2013 and 2012, respectively, with unrealized gains and losses recorded to earnings. The Grantor Trust investment is included in Other investments on the Consolidated Statements of Financial Position. | ||||||||||||||||||||||||||||||||
Defined Contribution Plans | ||||||||||||||||||||||||||||||||
The Company also sponsors defined contribution retirement savings plans. Participation in one of these plans is available to substantially all represented and non-represented employees. The Company matches employee contributions up to certain predefined limits based upon eligible compensation, the employee’s contribution rate and, in some cases, years of credited service. The cost of these plans was $41 million, $37 million, and $35 million in each of the years 2013, 2012, and 2011, respectively. |
StockBased_Compensation_Notes
Stock-Based Compensation (Notes) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Share-based Compensation [Abstract] | ' | |||||||||||||||
Stock-based Compensation | ' | |||||||||||||||
STOCK-BASED COMPENSATION | ||||||||||||||||
The Company’s stock incentive program permits the grant of incentive stock options, non-qualifying stock options, stock awards, performance shares and performance units to employees and members of its Board of Directors. Key provisions of the stock incentive program are: | ||||||||||||||||
• | Authorized limit is 11,500,000 shares of common stock; | |||||||||||||||
• | Prohibits the grant of a stock option with an exercise price that is less than the fair market value of the Company’s stock on the date of the grant; and | |||||||||||||||
• | Imposes the following award limits to a single participant in a single calendar year, (1) options for more than 500,000 shares of common stock; (2) stock awards for more than 150,000 shares of common stock; (3) performance share awards for more than 300,000 shares of common stock (based on the maximum payout under the award); or (4) more than 1,000,000 performance units, which have a face amount of $1.00 each. | |||||||||||||||
The Company records compensation expense at fair value over the vesting period for all awards it grants. | ||||||||||||||||
Stock-based compensation for the reporting periods is as follows: | ||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||
(In millions) | ||||||||||||||||
Stock-based compensation expense | $ | 99 | $ | 83 | $ | 66 | ||||||||||
Tax benefit | 38 | 33 | 25 | |||||||||||||
Stock-based compensation cost capitalized in property, plant and equipment | 15 | 5 | 4 | |||||||||||||
Stock Options | ||||||||||||||||
Options are exercisable according to the terms of the individual stock option award agreements and expire 10 years after the date of the grant. The option exercise price equals the fair value of the stock on the date that the option was granted. Stock options vest ratably over a 3-year period. | ||||||||||||||||
Stock option activity was as follows: | ||||||||||||||||
Number of | Weighted | Aggregate | ||||||||||||||
Options | Average | Intrinsic | ||||||||||||||
Exercise Price | Value (In millions) | |||||||||||||||
Options outstanding at December 31, 2012 | 1,192,670 | $ | 41.86 | |||||||||||||
Granted | — | $ | — | |||||||||||||
Exercised | (458,603 | ) | $ | 40.71 | ||||||||||||
Forfeited or expired | (10,370 | ) | $ | 41.46 | ||||||||||||
Options outstanding and exercisable at December 31, 2013 | 723,697 | $ | 42.6 | $ | 18 | |||||||||||
As of December 31, 2013, the weighted average remaining contractual life for the exercisable shares is 3.83 years. As of December 31, 2013, all options were vested. During 2013, 200,844 options vested. | ||||||||||||||||
There were no options granted during 2013, 2012 or 2011. The intrinsic value of options exercised for the years ended December 31, 2013, 2012 and 2011 was $12 million, $25 million, and $20 million, respectively. Total option expense recognized during 2013, 2012 and 2011 was zero, $0.7 million and $2 million, respectively. | ||||||||||||||||
The number, weighted average exercise price and weighted average remaining contractual life of options outstanding were as follows: | ||||||||||||||||
Weighted Average | Weighted Average | |||||||||||||||
Number of Options | Exercise Price | Remaining Contractual Life (Years) | ||||||||||||||
Range of Exercise Prices | ||||||||||||||||
$ | 27 | — | $ | 38 | 67,257 | $ | 28.3 | 5.15 | ||||||||
$ | 38.01 | — | $ | 42 | 167,447 | $ | 41.23 | 3.21 | ||||||||
$ | 42.01 | — | $ | 45 | 351,893 | $ | 44.02 | 4.16 | ||||||||
$ | 45.01 | — | $ | 50 | 137,100 | $ | 47.67 | 3.08 | ||||||||
723,697 | $ | 42.6 | 3.83 | |||||||||||||
Restricted Stock Awards | ||||||||||||||||
Stock awards granted under the plan are restricted for varying periods, generally for three years. Participants have all rights of a shareholder with respect to a stock award, including the right to receive dividends and vote the shares. Prior to vesting in stock awards, the participant: (i) may not sell, transfer, pledge, exchange or otherwise dispose of shares; (ii) shall not retain custody of the share certificates; and (iii) will deliver to the Company a stock power with respect to each stock award upon request. | ||||||||||||||||
The stock awards are recorded at cost that approximates fair value on the date of grant. The cost is amortized to compensation expense over the vesting period. | ||||||||||||||||
Stock award activity for the years ended December 31 was: | ||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||
Fair value of awards vested (in millions) | $ | 8 | $ | 9 | $ | 13 | ||||||||||
Restricted common shares awarded | 127,785 | 167,320 | 381,840 | |||||||||||||
Weighted average market price of shares awarded | $ | 64.72 | $ | 53.71 | $ | 47.98 | ||||||||||
Compensation cost charged against income (in millions) | $ | 23 | $ | 12 | $ | 12 | ||||||||||
The following table summarizes the Company’s stock awards activity for the period ended December 31, 2013: | ||||||||||||||||
Restricted | Weighted Average | |||||||||||||||
Stock | Grant Date | |||||||||||||||
Fair Value | ||||||||||||||||
Balance at December 31, 2012 | 597,648 | $ | 48.33 | |||||||||||||
Grants | 127,785 | $ | 64.72 | |||||||||||||
Forfeitures | (7,155 | ) | $ | 54.61 | ||||||||||||
Vested and issued | (225,949 | ) | $ | 45.54 | ||||||||||||
Balance at December 31, 2013 | 492,329 | $ | 53.76 | |||||||||||||
Performance Share Awards | ||||||||||||||||
Performance shares awarded under the plan are for a specified number of shares of common stock that entitle the holder to receive a cash payment, shares of common stock or a combination thereof. The final value of the award is determined by the achievement of certain performance objectives and market conditions. The awards vest at the end of a specified period, usually three years. The Company accounts for performance share awards by accruing compensation expense over the vesting period based on: (i) the number of shares expected to be paid which is based on the probable achievement of performance objectives; and (ii) the closing stock price market value. The settlement of the award is based on the closing price at the settlement date. | ||||||||||||||||
The Company recorded compensation expense for performance share awards as follows: | ||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||
(In millions) | ||||||||||||||||
Compensation expense | $ | 77 | $ | 71 | $ | 53 | ||||||||||
Cash settlements (a) | $ | 9 | $ | 4 | $ | 3 | ||||||||||
Stock settlements (a) | $ | 56 | $ | 41 | $ | 25 | ||||||||||
_______________________________________ | ||||||||||||||||
(a) | Sum of cash and stock settlements approximates the intrinsic value of the liability. | |||||||||||||||
During the vesting period, the recipient of a performance share award has no shareholder rights. During the period beginning on the date the performance shares are awarded and ending on the certification date of the performance objectives, the number of performance shares awarded will be increased, assuming full dividend reinvestment at the fair market value on the dividend payment date. The cumulative number of performance shares will be adjusted to determine the final payment based on the performance objectives achieved. Performance share awards are nontransferable and are subject to risk of forfeiture. | ||||||||||||||||
The following table summarizes the Company’s performance share activity for the period ended December 31, 2013: | ||||||||||||||||
Performance Shares | ||||||||||||||||
Balance at December 31, 2012 | 1,634,364 | |||||||||||||||
Grants | 564,561 | |||||||||||||||
Forfeitures | (41,512 | ) | ||||||||||||||
Payouts | (548,624 | ) | ||||||||||||||
Balance at December 31, 2013 | 1,608,789 | |||||||||||||||
Unrecognized Compensation Costs | ||||||||||||||||
As of December 31, 2013, there was $55 million of total unrecognized compensation cost related to non-vested stock-based compensation arrangements. That cost is expected to be recognized over a weighted-average period of 0.93 years. | ||||||||||||||||
Unrecognized | Weighted Average | |||||||||||||||
Compensation | to be Recognized | |||||||||||||||
Cost | ||||||||||||||||
(In millions) | (In years) | |||||||||||||||
Stock awards | $ | 10 | 0.93 | |||||||||||||
Performance shares | 45 | 0.93 | ||||||||||||||
$ | 55 | 0.93 | ||||||||||||||
Segment_Information_Notes
Segment Information (Notes) | 12 Months Ended | |||||||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||||||
Segment Reporting [Abstract] | ' | |||||||||||||||||||||||||||||||||||
Segment Information | ' | |||||||||||||||||||||||||||||||||||
SEGMENT AND RELATED INFORMATION | ||||||||||||||||||||||||||||||||||||
The Company sets strategic goals, allocates resources and evaluates performance based on the following structure: | ||||||||||||||||||||||||||||||||||||
Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million residential, commercial and industrial customers in southeastern Michigan. | ||||||||||||||||||||||||||||||||||||
Gas segment consists of DTE Gas and Citizens. DTE Gas is engaged in the purchase, storage, transportation, distribution and sale of natural gas to approximately 1.2 million residential, commercial and industrial customers throughout Michigan and the sale of storage and transportation capacity. Citizens distributes natural gas in Adrian, Michigan to approximately 17,000 customers. | ||||||||||||||||||||||||||||||||||||
Gas Storage and Pipelines consists of natural gas pipeline, gathering and storage businesses. | ||||||||||||||||||||||||||||||||||||
Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial and institutional customers; produce reduced emissions fuel (REF) and sell electricity from biomass-fired energy projects. | ||||||||||||||||||||||||||||||||||||
Energy Trading consists of energy marketing and trading operations. | ||||||||||||||||||||||||||||||||||||
Corporate and Other, includes various holding company activities, holds certain non-utility debt and energy-related investments. | ||||||||||||||||||||||||||||||||||||
The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of production tax credits and net operating losses if applicable. The state and local income tax provisions of the utility subsidiaries is determined on an individual company basis and recognizes the tax benefit of various tax credits and net operating losses if applicable. The subsidiaries record federal, state and local income taxes payable to or receivable from DTE Energy based on the federal, state and local tax provisions of each company. | ||||||||||||||||||||||||||||||||||||
Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales and natural gas sales in the following segments: | ||||||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
Electric | $ | 26 | $ | 29 | $ | 33 | ||||||||||||||||||||||||||||||
Gas | 4 | 4 | 2 | |||||||||||||||||||||||||||||||||
Gas Storage and Pipelines | 3 | 6 | 8 | |||||||||||||||||||||||||||||||||
Power and Industrial Projects | 816 | 801 | 238 | |||||||||||||||||||||||||||||||||
Energy Trading | 43 | 43 | 70 | |||||||||||||||||||||||||||||||||
Corporate and Other | (24 | ) | (37 | ) | (50 | ) | ||||||||||||||||||||||||||||||
Discontinued Operations | — | 2 | — | |||||||||||||||||||||||||||||||||
$ | 868 | $ | 848 | $ | 301 | |||||||||||||||||||||||||||||||
Financial data of the business segments follows: | ||||||||||||||||||||||||||||||||||||
Operating | Depreciation, | Interest | Interest | Income | Net Income (Loss) | Total | Goodwill | Capital | ||||||||||||||||||||||||||||
Revenue | Depletion & | Income | Expense | Taxes | Attributable | Assets | Expenditures | |||||||||||||||||||||||||||||
Amortization | to DTE | |||||||||||||||||||||||||||||||||||
Energy | ||||||||||||||||||||||||||||||||||||
Company | ||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
2013 | ||||||||||||||||||||||||||||||||||||
Electric | $ | 5,199 | $ | 902 | $ | (1 | ) | $ | 268 | $ | 252 | $ | 484 | $ | 17,508 | $ | 1,208 | $ | 1,325 | |||||||||||||||||
Gas | 1,474 | 95 | (7 | ) | 58 | 77 | 143 | 3,938 | 743 | 209 | ||||||||||||||||||||||||||
Gas Storage and Pipelines | 132 | 23 | (7 | ) | 18 | 45 | 70 | 824 | 24 | 245 | ||||||||||||||||||||||||||
Power and Industrial Projects | 1,950 | 72 | (6 | ) | 27 | (45 | ) | 66 | 1,067 | 26 | 93 | |||||||||||||||||||||||||
Energy Trading | 1,771 | 1 | — | 8 | (38 | ) | (58 | ) | 623 | 17 | 3 | |||||||||||||||||||||||||
Corporate and Other | 3 | 1 | (51 | ) | 120 | (37 | ) | (44 | ) | 2,945 | — | 1 | ||||||||||||||||||||||||
Reclassifications and Eliminations | (868 | ) | — | 63 | (63 | ) | — | — | (970 | ) | — | — | ||||||||||||||||||||||||
Total | $ | 9,661 | $ | 1,094 | $ | (9 | ) | $ | 436 | $ | 254 | $ | 661 | $ | 25,935 | $ | 2,018 | $ | 1,876 | |||||||||||||||||
Operating | Depreciation, | Interest | Interest | Income | Net Income (Loss) | Total | Goodwill | Capital | ||||||||||||||||||||||||||||
Revenue | Depletion & | Income | Expense | Taxes | Attributable | Assets | Expenditures | |||||||||||||||||||||||||||||
Amortization | to DTE | |||||||||||||||||||||||||||||||||||
Energy | ||||||||||||||||||||||||||||||||||||
Company | ||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
2012 | ||||||||||||||||||||||||||||||||||||
Electric | $ | 5,293 | $ | 827 | $ | (1 | ) | $ | 272 | $ | 280 | $ | 483 | $ | 17,755 | $ | 1,208 | $ | 1,230 | |||||||||||||||||
Gas | 1,315 | 92 | (7 | ) | 59 | 50 | 115 | 4,059 | 745 | 221 | ||||||||||||||||||||||||||
Gas Storage and Pipelines | 96 | 8 | (8 | ) | 8 | 39 | 61 | 668 | 22 | 233 | ||||||||||||||||||||||||||
Power and Industrial Projects | 1,823 | 65 | (7 | ) | 37 | (44 | ) | 42 | 991 | 26 | 83 | |||||||||||||||||||||||||
Energy Trading | 1,109 | 2 | — | 8 | 7 | 12 | 629 | 17 | 1 | |||||||||||||||||||||||||||
Corporate and Other | 3 | 1 | (52 | ) | 121 | (46 | ) | (47 | ) | 3,074 | — | 3 | ||||||||||||||||||||||||
Reclassifications and Eliminations | (848 | ) | — | 65 | (65 | ) | — | — | (837 | ) | — | — | ||||||||||||||||||||||||
Total from Continuing Operations | $ | 8,791 | $ | 995 | $ | (10 | ) | $ | 440 | $ | 286 | $ | 666 | $ | 26,339 | $ | 2,018 | $ | 1,771 | |||||||||||||||||
Discontinued Operations (Note 7) | (56 | ) | — | — | 49 | |||||||||||||||||||||||||||||||
Total | $ | 610 | $ | 26,339 | $ | 2,018 | $ | 1,820 | ||||||||||||||||||||||||||||
Operating | Depreciation, | Interest | Interest | Income | Net Income (Loss) | Total | Goodwill | Capital | ||||||||||||||||||||||||||||
Revenue | Depletion & | Income | Expense | Taxes | Attributable | Assets | Expenditures | |||||||||||||||||||||||||||||
Amortization | to DTE | |||||||||||||||||||||||||||||||||||
Energy | ||||||||||||||||||||||||||||||||||||
Company | ||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
2011 | ||||||||||||||||||||||||||||||||||||
Electric | $ | 5,154 | $ | 818 | $ | (1 | ) | $ | 289 | $ | 265 | $ | 434 | $ | 17,567 | $ | 1,208 | $ | 1,203 | |||||||||||||||||
Gas | 1,505 | 89 | (7 | ) | 64 | 60 | 110 | 4,065 | 745 | 179 | ||||||||||||||||||||||||||
Gas Storage and Pipelines | 91 | 6 | (5 | ) | 7 | 35 | 57 | 538 | 22 | 16 | ||||||||||||||||||||||||||
Power and Industrial Projects | 1,129 | 60 | (8 | ) | 32 | 11 | 38 | 789 | 26 | 56 | ||||||||||||||||||||||||||
Energy Trading | 1,276 | 3 | — | 9 | 34 | 52 | 612 | 17 | 1 | |||||||||||||||||||||||||||
Corporate & Other | 4 | 1 | (47 | ) | 145 | (136 | ) | 23 | 2,605 | — | — | |||||||||||||||||||||||||
Reclassifications and Eliminations | (301 | ) | — | 58 | (58 | ) | (1 | ) | — | (485 | ) | — | — | |||||||||||||||||||||||
Total from Continuing Operations | $ | 8,858 | $ | 977 | $ | (10 | ) | $ | 488 | $ | 268 | $ | 714 | $ | 25,691 | $ | 2,018 | $ | 1,455 | |||||||||||||||||
Discontinued Operations (Note 7) | (3 | ) | 318 | 2 | 29 | |||||||||||||||||||||||||||||||
Total | $ | 711 | $ | 26,009 | $ | 2,020 | $ | 1,484 | ||||||||||||||||||||||||||||
Supplementary_Quarterly_Financ
Supplementary Quarterly Financial Information (Unaudited) | 12 Months Ended | |||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||
Quarterly Financial Information Disclosure [Abstract] | ' | |||||||||||||||||||
Quarterly Financial Information [Text Block] | ' | |||||||||||||||||||
SUPPLEMENTARY QUARTERLY FINANCIAL INFORMATION (UNAUDITED) | ||||||||||||||||||||
Quarterly earnings per share may not equal full year totals, since quarterly computations are based on weighted average common shares outstanding during each quarter. | ||||||||||||||||||||
First | Second | Third | Fourth | Year | ||||||||||||||||
Quarter | Quarter | Quarter | Quarter | |||||||||||||||||
(In millions, except per share amounts) | ||||||||||||||||||||
2013 | ||||||||||||||||||||
Operating Revenues | $ | 2,516 | $ | 2,225 | $ | 2,387 | $ | 2,533 | $ | 9,661 | ||||||||||
Operating Income | $ | 410 | $ | 223 | $ | 329 | $ | 241 | $ | 1,203 | ||||||||||
Net Income Attributable to DTE Energy Company | $ | 234 | $ | 105 | $ | 198 | $ | 124 | $ | 661 | ||||||||||
Basic Earnings per Share | $ | 1.35 | $ | 0.6 | $ | 1.13 | $ | 0.7 | $ | 3.76 | ||||||||||
Diluted Earnings per Share | $ | 1.34 | $ | 0.6 | $ | 1.13 | $ | 0.7 | $ | 3.76 | ||||||||||
2012 | ||||||||||||||||||||
Operating Revenues | $ | 2,239 | $ | 2,013 | $ | 2,190 | $ | 2,349 | $ | 8,791 | ||||||||||
Operating Income | $ | 312 | $ | 294 | $ | 406 | $ | 267 | $ | 1,279 | ||||||||||
Net Income Attributable to DTE Energy Company | ||||||||||||||||||||
Continuing Operations | $ | 156 | $ | 147 | $ | 226 | $ | 137 | $ | 666 | ||||||||||
Discontinued Operations | — | (1 | ) | 1 | (56 | ) | (56 | ) | ||||||||||||
Net Income Attributable to DTE Energy Company | $ | 156 | $ | 146 | $ | 227 | $ | 81 | $ | 610 | ||||||||||
Basic Earnings per Share | ||||||||||||||||||||
Continuing Operations | $ | 0.91 | $ | 0.87 | $ | 1.31 | $ | 0.79 | $ | 3.89 | ||||||||||
Discontinued Operations | — | (0.01 | ) | 0.01 | (0.32 | ) | (0.33 | ) | ||||||||||||
Total | $ | 0.91 | $ | 0.86 | $ | 1.32 | $ | 0.47 | $ | 3.56 | ||||||||||
Diluted Earnings per Share | ||||||||||||||||||||
Continuing Operations | $ | 0.91 | $ | 0.87 | $ | 1.3 | $ | 0.79 | $ | 3.88 | ||||||||||
Discontinued Operations | — | (0.01 | ) | 0.01 | (0.32 | ) | (0.33 | ) | ||||||||||||
Total | $ | 0.91 | $ | 0.86 | $ | 1.31 | $ | 0.47 | $ | 3.55 | ||||||||||
Valuation_and_Qualifying_Accou
Valuation and Qualifying Accounts (Notes) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Valuation and Qualifying Accounts [Abstract] | ' | |||||||||||
Schedule of Valuation and Qualifying Accounts Disclosure [Text Block] | ' | |||||||||||
Valuation and Qualifying Accounts | ||||||||||||
Year Ending December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Allowance for Doubtful Accounts (shown as deduction from Accounts Receivable in the Consolidated Statements of Financial Position) | ||||||||||||
Balance at Beginning of Period | $ | 62 | $ | 162 | $ | 196 | ||||||
Additions: | ||||||||||||
Charged to costs and expenses | 94 | 79 | 94 | |||||||||
Charged to other accounts (a) | 23 | 16 | 18 | |||||||||
Deductions (b) | (124 | ) | (195 | ) | (146 | ) | ||||||
Balance at End of Period | $ | 55 | $ | 62 | $ | 162 | ||||||
_______________________________________ | ||||||||||||
(a) | Collection of accounts previously written off. | |||||||||||
(b) | Uncollectible accounts written off. |
Significant_Accounting_Policie1
Significant Accounting Policies (Policies) | 12 Months Ended | |
Dec. 31, 2013 | ||
Accounting Policies [Abstract] | ' | |
Basis of Accounting, Policy [Policy Text Block] | ' | |
The accompanying Consolidated Financial Statements are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Company’s estimates. | ||
Consolidation, Variable Interest Entity, Policy [Policy Text Block] | ' | |
The Company consolidates all majority-owned subsidiaries and investments in entities in which it has controlling influence. Non-majority owned investments are accounted for using the equity method when the Company is able to influence the operating policies of the investee. When the Company does not influence the operating policies of an investee, the cost method is used. These consolidated financial statements also reflect the Company's proportionate interests in certain jointly owned utility plant. The Company eliminates all intercompany balances and transactions. | ||
The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, the Company considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed. | ||
Legal entities within the Company's Power and Industrial Projects segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with the Company retaining operational and customer default risk. These entities generally are VIEs and are consolidated when the Company is the primary beneficiary. In addition, we have interests in certain VIEs that we share control of all significant activities for those entities with our partners, and therefore are accounted for under the equity method. | ||
The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of December 31, 2013, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of its variable interests through these long-term purchase contracts. | ||
In 2001, DTE Electric financed a regulatory asset related to Fermi 2 and certain other regulatory assets through the sale of rate reduction bonds by a wholly-owned special purpose entity, Securitization. DTE Electric performs servicing activities including billing and collecting surcharge revenue for Securitization. This entity is a VIE and is consolidated by the Company. | ||
The maximum risk exposure for consolidated VIEs is reflected on the Company's Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment and amounts which it has guaranteed. | ||
The following table summarizes the major balance sheet items for consolidated VIEs as of December 31, 2013 and 2012. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. VIEs, in which the Company holds a majority voting interest and is the primary beneficiary, that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIE's obligations have been excluded from the table below. | ||
Revenues Policy [Policy Text Block] | ' | |
Revenues | ||
Revenues from the sale and delivery of electricity, and the sale, delivery and storage of natural gas are recognized as services are provided. DTE Electric and DTE Gas record revenues for electricity and gas provided but unbilled at the end of each month. Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are recorded on the Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors. | ||
See Note 11 for further discussion of recovery mechanisms authorized by the MPSC. | ||
Non-utility businesses recognize revenues as services are provided and products are delivered. See Note 4 for discussion of derivative contracts. | ||
Accounting For ISO Transactions [Policy Text Block] | ' | |
Accounting for ISO Transactions | ||
DTE Electric participates in the energy market through MISO. MISO requires that we submit hourly day-ahead, real- time and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time and FTR markets and net transactions across all MISO energy market locations. In any single hour DTE Electric records net purchases in Fuel, purchased power and gas and net sales in Operating revenues on the Consolidated Statements of Operations. | ||
Energy Trading participates in the energy markets through various independent system operators and regional transmission organizations (ISOs and RTOs). These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the regional transmission organizations. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time and FTR markets. These transactions are related to trading contracts which are presented on a net basis in Operating Revenues in the Consolidated Statements of Operations. | ||
DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience, and reconcile accruals to actual costs when invoices are received from MISO, and other ISOs and RTOs. | ||
Comprehensive Income [Policy Text Block] | ' | |
Comprehensive Income (Loss) | ||
Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the year ended December 31, 2013 include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities, the Company’s interest in other comprehensive income of equity investees, which comprise the net unrealized gains and losses on investments, changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans, and foreign currency translation adjustments. | ||
Cash and Cash Equivalents [Policy Text Block] | ' | |
Cash Equivalents and Restricted Cash | ||
Cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt, primarily Securitization bonds, and partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a current asset. | ||
Receivables [Policy Text Block] | ' | |
Receivables | ||
Accounts receivable are primarily composed of trade receivables and unbilled revenue. Our accounts receivable are stated at net realizable value. | ||
The allowance for doubtful accounts for DTE Electric and DTE Gas is generally calculated using the aging approach that utilizes rates developed in reserve studies. We establish an allowance for uncollectible accounts based on historical losses and management’s assessment of existing economic conditions, customer trends, and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. We assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated. | ||
The customer allowance for doubtful accounts for our other businesses is calculated based on specific review of probable future collections based on receivable balances in excess of 30 days. | ||
Unbilled revenues of $815 million and $686 million are included in customer accounts receivable at December 31, 2013 and 2012, respectively. | ||
Notes Receivable | ||
Notes receivable, or financing receivables, are primarily comprised of capital lease receivables and loans and are included in Notes receivable and Other current assets on the Company’s Consolidated Statements of Financial Position. | ||
Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Company ceases accruing interest (nonaccrual status), considers a note receivable impaired, and establishes an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected in accordance with the contractual terms of the note receivable. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current. | ||
In determining the allowance for credit losses for notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty’s ability to pay. In addition, the Company monitors the credit ratings of the counterparties from which we have notes receivable. | ||
Inventories [Policy Text Block] | ' | |
Inventories | ||
The Company generally values inventory at average cost. | ||
Natural gas inventory of $4 million and $37 million as of December 31, 2013 and 2012, respectively, at DTE Gas is determined using the last-in, first-out (LIFO) method. At December 31, 2013, the replacement cost of gas remaining in storage exceeded the LIFO cost by $170 million. At December 31, 2012, the replacement cost of gas remaining in storage exceeded the LIFO cost by $113 million. | ||
Property, Retirement and Maintenance, Depreciation, Depletion and Amortization [Policy Text Block] | ' | |
Property, Retirement and Maintenance, and Depreciation, Depletion and Amortization | ||
Property is stated at cost and includes construction-related labor, materials, overheads and, for utility property, an allowance for funds used during construction (AFUDC). The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred, except for Fermi 2. | ||
Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC. | ||
Non-utility property is depreciated over its estimated useful life using the straight-line and units of production methods. | ||
Depreciation, depletion and amortization expense also includes the amortization of certain regulatory assets. | ||
Approximately $26 million and $12 million of expenses related to Fermi 2 refueling outages were accrued at December 31, 2013 and 2012, respectively. Amounts are accrued on a pro-rata basis, generally over an 18-month period, that coincides with scheduled refueling outages at Fermi 2. This accrual of outage costs matches the regulatory recovery of these costs in rates set by the MPSC. See Note 11. | ||
The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas in the Consolidated Statements of Operations and is recorded using the units-of-production method. | ||
Capitalized software costs are classified as Property, plant and equipment and the related amortization is included in Accumulated depreciation, depletion and amortization on the Consolidated Statements of Financial Position. The Company capitalizes the costs associated with computer software it develops or obtains for use in its business. The Company amortizes capitalized software costs on a straight-line basis over the expected period of benefit | ||
Long-Lived Assets [Policy Text Block] | ' | |
Long-Lived Assets | ||
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected discounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell. | ||
Intangible Assets | ' | |
Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business. The Company amortizes contract intangible assets on a straight-line basis over the expected period of benefit, ranging from 1 to 28 years. Intangible assets amortization expense was $14 million in 2013, $6 million in 2012 and $5 million in 2011. | ||
Deferred Debt Costs [Policy Text Block] | ' | |
Deferred Debt Costs | ||
The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. In accordance with MPSC regulations applicable to the Company’s electric and gas utilities, the unamortized discount, premium and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium and expense on early redemptions of debt associated with non-utility operations are charged to earnings. | ||
Investments in Debt and Equity Securities [Policy Text Block] | ' | |
Investments in Debt and Equity Securities | ||
The Company generally classifies investments in debt and equity securities as either trading or available-for-sale and has recorded such investments at market value with unrealized gains or losses included in earnings or in other comprehensive income or loss, respectively. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to regulatory assets or liabilities, due to a recovery mechanism from customers. The Company’s equity investments are reviewed for impairment each reporting period. If the assessment indicates that the impairment is other than temporary, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 3. | ||
Government Grants [Policy Text Block] | ' | |
Government Grants | ||
Grants are recognized when there is reasonable assurance that the grant will be received and that any conditions associated with the grant will be met. When grants are received related to Property, Plant and Equipment, the Company reduces the cost of the assets on the Consolidated Statements of Financial Position, resulting in lower depreciation expense over the life of the associated asset. Grants received related to expenses are reflected as a reduction of the associated expense in the period in which the expense is incurred. | ||
Foundation Related Party [Policy Text Block] | ' | |
DTE Energy Foundation | ||
Charitable contributions to the DTE Energy Foundation were $18 million, $21 million, and $21 million for the years ended December 31, 2013, 2012 and 2011, respectively. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations and does not serve a direct business or political purpose of DTE. | ||
Fair Value Measurement, Policy [Policy Text Block] | ' | |
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated or generally unobservable inputs. The Company makes certain assumptions it believes that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Company and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 2013 and 2012. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs. | ||
A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Company classifies fair value balances based on the fair value hierarchy defined as follows: | ||
• | Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date. | |
• | Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data. | |
• | Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints. | |
Nuclear Decommissioning Trust and Other Investments, Policy [Policy Text Block] | ' | |
The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds which hold exchange-traded equity or debt securities are valued based on the underlying securities, using quoted prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by the Company's Trust Investments Department which reports to the Company's Vice President and Treasurer. | ||
Derivatives, Reporting of Derivative Activity [Policy Text Block] | ' | |
DTE Energy considers the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality and basis differential factors. DTE Energy monitors the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. DTE Energy has obtained an understanding of how these prices are derived. Additionally, DTE Energy selectively corroborates the fair value of its transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Company has established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of our forward price curves has been assigned to our Risk Management Department, which is separate and distinct from the trading functions within the Company. | ||
Fair Value Transfer, Policy [Policy Text Block] | ' | |
Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period. | ||
Fair Value of Financial Instruments, Policy [Policy Text Block] | ' | |
The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. DTE Energy has obtained an understanding of how the fair values are derived. DTE Energy also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are estimated using discounted cash flow techniques that incorporate market interest rates as well assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures are determined by DTE Energy's Treasury Department which reports to the Company's Vice President and Treasurer. | ||
Derivatives, Policy [Policy Text Block] | ' | |
The Company recognizes all derivatives at their fair value as Derivative assets or liabilities on the Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge), or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in the fair value are recognized in earnings each period. | ||
The Company’s primary market risk exposure is associated with commodity prices, credit and interest rates. The Company has risk management policies to monitor and manage market risks. The Company uses derivative instruments to manage some of the exposure. The Company uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include power, natural gas, oil and certain coal forwards, futures, options and swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits and natural gas storage assets. | ||
Derivatives, Offsetting Fair Value Amounts, Policy [Policy Text Block] | ' | |
Certain of the Company's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, the Company offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces the Company's total assets and liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in accounts receivable and accounts payable as collateral paid or received, respectively. | ||
The Company also provides and receives collateral in the form of letters of credit which can be offset against net derivative assets and liabilities as well as accounts receivable and payable. The Company had issued letters of credit of approximately $19 million and $63 million at December 31, 2013 and 2012, respectively, which could be used to offset our net derivative liabilities. Letters of credit received from third parties which could be used to offset our net derivative assets were not material for the periods presented. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in the Consolidated Statements of Financial Position. | ||
For contracts with certain clearing agents the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a derivative asset or liability or 2) an account receivable or payable. Other than certain clearing agents, accounts receivable and accounts payable that are subject to netting arrangements have not been offset against the fair value of derivative assets and liabilities. Certain contracts that have netting arrangements have not been offset in the Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below. | ||
Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges [Policy Text Block] | ' | |
Revenues and energy costs related to trading contracts are presented on a net basis in the Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the mark-to-market method with unrealized and realized gains and losses recorded in Operating revenues. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the mark-to-market method with unrealized and realized gains and losses for sales recorded in Operating revenue and purchases recorded in Fuel, purchased power and gas. | ||
Asset Retirement Obligations, Policy [Policy Text Block] | ' | |
The Company has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property and various other operations. The Company has conditional retirement obligations for gas pipelines, asbestos and PCB removal at certain of its power plants and various distribution equipment. The Company recognizes such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at our credit-adjusted risk-free rate. In its regulated operations, the Company recognizes regulatory assets or liabilities for timing differences in expense recognition for legal asset retirement costs that are currently recovered in rates. | ||
If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets. | ||
Public Utilities, Policy [Policy Text Block] | ' | |
DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of our businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment. | ||
Income Tax, Policy [Policy Text Block] | ' | |
Excise and Sales Taxes | ||
The Company records the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Consolidated Statements of Operations. | ||
Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the financial statements. Deferred tax assets and liabilities are classified as current or noncurrent according to the classification of the related assets or liabilities. Deferred tax assets and liabilities not related to assets or liabilities are classified according to the expected reversal date of the temporary differences. Consistent with rate making treatment, deferred taxes are offset in the table below for temporary differences which have related regulatory assets and liabilities. | ||
The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of production tax credits and net operating losses if applicable. The state and local income tax provisions of the utility subsidiaries is determined on an individual company basis and recognizes the tax benefit of various tax credits and net operating losses if applicable. The subsidiaries record federal, state and local income taxes payable to or receivable from DTE Energy based on the federal, state and local tax provisions of each company. | ||
Compensation Related Costs, Policy [Policy Text Block] | ' | |
The Company records compensation expense at fair value over the vesting period for all awards it grants. |
Organization_and_Basis_of_Pres1
Organization and Basis of Presentation (Tables) | 12 Months Ended | |||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||
Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract] | ' | |||||||||||||||||||||||
Schedule of Variable Interest Entities [Table Text Block] | ' | |||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||
Securitization | Other | Total | Securitization | Other | Total | |||||||||||||||||||
(In millions) | ||||||||||||||||||||||||
ASSETS | ||||||||||||||||||||||||
Cash and cash equivalents | $ | — | $ | 12 | $ | 12 | $ | — | $ | 10 | $ | 10 | ||||||||||||
Restricted cash | 100 | 8 | 108 | 102 | 7 | 109 | ||||||||||||||||||
Accounts receivable | 34 | 16 | 50 | 34 | 7 | 41 | ||||||||||||||||||
Inventories | — | 118 | 118 | — | 141 | 141 | ||||||||||||||||||
Other current assets | — | 1 | 1 | — | 1 | 1 | ||||||||||||||||||
Property, plant and equipment | — | 99 | 99 | — | 93 | 93 | ||||||||||||||||||
Securitized regulatory assets | 231 | — | 231 | 413 | — | 413 | ||||||||||||||||||
Other assets | 4 | 8 | 12 | 7 | 11 | 18 | ||||||||||||||||||
$ | 369 | $ | 262 | $ | 631 | $ | 556 | $ | 270 | $ | 826 | |||||||||||||
LIABILITIES | ||||||||||||||||||||||||
Accounts payable and accrued current liabilities | $ | 7 | $ | 23 | $ | 30 | $ | 11 | $ | 14 | $ | 25 | ||||||||||||
Current portion long-term debt, including capital leases | 196 | 9 | 205 | 177 | 8 | 185 | ||||||||||||||||||
Current regulatory liabilities | 43 | — | 43 | 50 | — | 50 | ||||||||||||||||||
Other current liabilities | — | 4 | 4 | — | 4 | 4 | ||||||||||||||||||
Mortgage bonds, notes and other | — | 21 | 21 | — | 25 | 25 | ||||||||||||||||||
Securitization bonds | 105 | — | 105 | 302 | — | 302 | ||||||||||||||||||
Capital lease obligations | — | 7 | 7 | — | 11 | 11 | ||||||||||||||||||
Other long-term liabilities | 8 | 2 | 10 | 7 | 2 | 9 | ||||||||||||||||||
$ | 359 | $ | 66 | $ | 425 | $ | 547 | $ | 64 | $ | 611 | |||||||||||||
Summary of amounts for non-consolidated VIEs [Table Text Block | ' | |||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||
Other investments | $ | 141 | $ | 130 | ||||||||||||||||||||
Notes receivable | $ | 8 | $ | 6 | ||||||||||||||||||||
Significant_Accounting_Policie2
Significant Accounting Policies (Tables) | 12 Months Ended | |||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||
Accounting Policies [Abstract] | ' | |||||||||||||||||||
Schedule of Comprehensive Income (Loss) [Table Text Block] | ' | |||||||||||||||||||
Changes in Accumulated Other Comprehensive Loss by Component (a) | ||||||||||||||||||||
For The Year Ended December 31, 2013 | ||||||||||||||||||||
Net | Net | Benefit | Foreign | Total | ||||||||||||||||
Unrealized | Unrealized | Obligations | Currency | |||||||||||||||||
Gain/(Loss) | Gain/(Loss) | (b) | Translation | |||||||||||||||||
on Derivatives | on Investments | |||||||||||||||||||
(In millions) | ||||||||||||||||||||
Beginning balances December 31, 2012 | $ | (4 | ) | $ | (8 | ) | $ | (148 | ) | $ | 2 | $ | (158 | ) | ||||||
Other comprehensive income (loss) before reclassifications | — | 2 | 13 | (2 | ) | 13 | ||||||||||||||
Amounts reclassified from accumulated other comprehensive income (loss) | — | — | 9 | — | 9 | |||||||||||||||
Net current-period other comprehensive income (loss) | — | 2 | 22 | (2 | ) | 22 | ||||||||||||||
Ending balances December 31, 2013 | $ | (4 | ) | $ | (6 | ) | $ | (126 | ) | $ | — | $ | (136 | ) | ||||||
______________________________________ | ||||||||||||||||||||
(a) | All amounts are net of tax. | |||||||||||||||||||
(b) | The amounts reclassified from accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 20). | |||||||||||||||||||
Schedule of Finite-Lived Intangible Assets by Major Class [Table Text Block] | ' | |||||||||||||||||||
The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below: | ||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||
2013 | 2012 | |||||||||||||||||||
(In millions) | ||||||||||||||||||||
Emission allowances | $ | 2 | $ | 6 | ||||||||||||||||
Renewable energy credits | 51 | 44 | ||||||||||||||||||
Contract intangible assets | 126 | 139 | ||||||||||||||||||
179 | 189 | |||||||||||||||||||
Less accumulated amortization | 45 | 34 | ||||||||||||||||||
Intangible assets, net | 134 | 155 | ||||||||||||||||||
Less current intangible assets | 12 | 20 | ||||||||||||||||||
$ | 122 | $ | 135 | |||||||||||||||||
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block] | ' | |||||||||||||||||||
The following table summarizes the estimated amortization expense expected to be recognized during each year through 2018: | ||||||||||||||||||||
Estimated amortization expense | (In millions) | |||||||||||||||||||
2014 | $ | 13 | ||||||||||||||||||
2015 | $ | 12 | ||||||||||||||||||
2016 | $ | 11 | ||||||||||||||||||
2017 | $ | 8 | ||||||||||||||||||
2018 | $ | 8 | ||||||||||||||||||
Fair_Value_Tables
Fair Value (Tables) | 12 Months Ended | |||||||||||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||||||||||
Fair Value Disclosures [Abstract] | ' | |||||||||||||||||||||||||||||||||||||||
Assets and liabilities measured and recorded at fair value on a recurring basis | ' | |||||||||||||||||||||||||||||||||||||||
The following table presents assets and liabilities measured and recorded at fair value on a recurring basis as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Netting (a) | Net Balance | Level 1 | Level 2 | Level 3 | Netting (a) | Net Balance | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Assets: | ||||||||||||||||||||||||||||||||||||||||
Cash equivalents (b) | $ | 10 | $ | 115 | $ | — | $ | — | $ | 125 | $ | — | $ | 123 | $ | — | $ | — | $ | 123 | ||||||||||||||||||||
Nuclear decommissioning trusts | 779 | 412 | — | — | 1,191 | 694 | 343 | — | — | 1,037 | ||||||||||||||||||||||||||||||
Other investments (c) (d) | 92 | 44 | — | — | 136 | 66 | 44 | — | — | 110 | ||||||||||||||||||||||||||||||
Derivative assets: | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | 273 | 89 | 34 | (382 | ) | 14 | 555 | 66 | 24 | (605 | ) | 40 | ||||||||||||||||||||||||||||
Electricity | — | 261 | 139 | (291 | ) | 109 | — | 226 | 134 | (258 | ) | 102 | ||||||||||||||||||||||||||||
Other | 33 | 1 | 3 | (34 | ) | 3 | 6 | 3 | 2 | (6 | ) | 5 | ||||||||||||||||||||||||||||
Total derivative assets | 306 | 351 | 176 | (707 | ) | 126 | 561 | 295 | 160 | (869 | ) | 147 | ||||||||||||||||||||||||||||
Total | $ | 1,187 | $ | 922 | $ | 176 | $ | (707 | ) | $ | 1,578 | $ | 1,321 | $ | 805 | $ | 160 | $ | (869 | ) | $ | 1,417 | ||||||||||||||||||
Liabilities: | ||||||||||||||||||||||||||||||||||||||||
Derivative liabilities: | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | $ | (277 | ) | $ | (140 | ) | $ | (86 | ) | $ | 395 | $ | (108 | ) | $ | (526 | ) | $ | (73 | ) | $ | (62 | ) | $ | 605 | $ | (56 | ) | ||||||||||||
Electricity | — | (272 | ) | (126 | ) | 269 | (129 | ) | — | (240 | ) | (111 | ) | 258 | (93 | ) | ||||||||||||||||||||||||
Other | (32 | ) | (2 | ) | — | 34 | — | (6 | ) | (1 | ) | — | 6 | (1 | ) | |||||||||||||||||||||||||
Other derivative contracts (f) | — | (1 | ) | — | — | (1 | ) | — | (1 | ) | — | — | (1 | ) | ||||||||||||||||||||||||||
Total derivative liabilities | (309 | ) | (415 | ) | (212 | ) | 698 | (238 | ) | (532 | ) | (315 | ) | (173 | ) | 869 | (151 | ) | ||||||||||||||||||||||
Total | $ | (309 | ) | $ | (415 | ) | $ | (212 | ) | $ | 698 | $ | (238 | ) | $ | (532 | ) | $ | (315 | ) | $ | (173 | ) | $ | 869 | $ | (151 | ) | ||||||||||||
Net Assets (liabilities) at the end of the period | $ | 878 | $ | 507 | $ | (36 | ) | $ | (9 | ) | $ | 1,340 | $ | 789 | $ | 490 | $ | (13 | ) | $ | — | $ | 1,266 | |||||||||||||||||
Assets: | ||||||||||||||||||||||||||||||||||||||||
Current | $ | 277 | $ | 400 | $ | 139 | $ | (592 | ) | $ | 224 | $ | 493 | $ | 372 | $ | 120 | $ | (754 | ) | $ | 231 | ||||||||||||||||||
Noncurrent (e) | 910 | 522 | 37 | (115 | ) | 1,354 | 828 | 433 | 40 | (115 | ) | 1,186 | ||||||||||||||||||||||||||||
Total Assets | $ | 1,187 | $ | 922 | $ | 176 | $ | (707 | ) | $ | 1,578 | $ | 1,321 | $ | 805 | $ | 160 | $ | (869 | ) | $ | 1,417 | ||||||||||||||||||
Liabilities: | ||||||||||||||||||||||||||||||||||||||||
Current | $ | (268 | ) | $ | (328 | ) | $ | (177 | ) | $ | 578 | $ | (195 | ) | $ | (466 | ) | $ | (269 | ) | $ | (144 | ) | $ | 754 | $ | (125 | ) | ||||||||||||
Noncurrent | (41 | ) | (87 | ) | (35 | ) | 120 | (43 | ) | (66 | ) | (46 | ) | (29 | ) | 115 | (26 | ) | ||||||||||||||||||||||
Total Liabilities | $ | (309 | ) | $ | (415 | ) | $ | (212 | ) | $ | 698 | $ | (238 | ) | $ | (532 | ) | $ | (315 | ) | $ | (173 | ) | $ | 869 | $ | (151 | ) | ||||||||||||
Net Assets (liabilities) at the end of the period | $ | 878 | $ | 507 | $ | (36 | ) | $ | (9 | ) | $ | 1,340 | $ | 789 | $ | 490 | $ | (13 | ) | $ | — | $ | 1,266 | |||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||||||||||||||
(a) | Amounts represent the impact of master netting agreements that allow the Company to net gain and loss positions and cash collateral held or placed with the same counterparties. | |||||||||||||||||||||||||||||||||||||||
(b) | At December 31, 2013, available-for-sale securities of $125 million included $109 million and $16 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. At December 31, 2012, available-for-sale securities of $123 million, included $109 million and $14 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. | |||||||||||||||||||||||||||||||||||||||
(c) | Excludes cash surrender value of life insurance investments. | |||||||||||||||||||||||||||||||||||||||
(d) | Available-for-sale equity securities of $7 million at December 31, 2013 and $5 million at December 31, 2012 are included in Other investments on the Consolidated Statements of Financial Position. | |||||||||||||||||||||||||||||||||||||||
(e) | Includes $136 million and $110 million of Other investments that are included in the Consolidated Statements of Financial Position in Other investments at December 31, 2013 and 2012, respectively. | |||||||||||||||||||||||||||||||||||||||
(f) | Includes Interest rate contracts and Foreign currency exchange contracts. | |||||||||||||||||||||||||||||||||||||||
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||||||
The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||||||||||
Natural Gas | Electricity | Other | Total | Natural Gas | Electricity | Other | Total | |||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Net Assets (Liabilities) as of December 31 | $ | (38 | ) | $ | 23 | $ | 2 | $ | (13 | ) | $ | 6 | $ | 32 | $ | 6 | $ | 44 | ||||||||||||||||||||||
Transfers into Level 3 | 1 | — | — | 1 | 1 | — | — | 1 | ||||||||||||||||||||||||||||||||
Total gains (losses): | ||||||||||||||||||||||||||||||||||||||||
Included in earnings | (32 | ) | 75 | — | 43 | (41 | ) | 101 | — | 60 | ||||||||||||||||||||||||||||||
Recorded in regulatory assets/liabilities | — | — | 5 | 5 | — | — | 15 | 15 | ||||||||||||||||||||||||||||||||
Purchases, issuances and settlements: | ||||||||||||||||||||||||||||||||||||||||
Purchases | (8 | ) | 1 | — | (7 | ) | — | 2 | — | 2 | ||||||||||||||||||||||||||||||
Issuances | — | (1 | ) | — | (1 | ) | — | — | — | — | ||||||||||||||||||||||||||||||
Settlements | 25 | (85 | ) | (4 | ) | (64 | ) | (4 | ) | (112 | ) | (19 | ) | (135 | ) | |||||||||||||||||||||||||
Net Assets (Liabilities) as of December 31 | $ | (52 | ) | $ | 13 | $ | 3 | $ | (36 | ) | $ | (38 | ) | $ | 23 | $ | 2 | $ | (13 | ) | ||||||||||||||||||||
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2013 and 2012 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations | $ | (49 | ) | $ | 48 | $ | — | $ | (1 | ) | $ | (33 | ) | $ | 91 | $ | — | $ | 58 | |||||||||||||||||||||
Transfers Between Level 1 Level 2 and Level 3 [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||||||
The following table shows transfers between the levels of the fair value hierarchy for the years ended December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Level 1 | Level 2 | Level 3 | |||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Transfers into Level 1 from | $ N/A | $ | — | $ | — | $ N/A | $ | — | $ | — | ||||||||||||||||||||||||||||||
Transfers into Level 2 from | — | N/A | — | — | N/A | — | ||||||||||||||||||||||||||||||||||
Transfers into Level 3 from | — | 1 | N/A | — | 1 | N/A | ||||||||||||||||||||||||||||||||||
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||||||
The following table presents the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts | Derivative Assets | Derivative Liabilities | Valuation Techniques | Unobservable Input | Range | Weighted Average | ||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | $ | 34 | $ | (86 | ) | Discounted Cash Flow | Forward basis price (per MMBtu) | $ | (0.88 | ) | — | $ | 5.07 | /MMBtu | $ | (0.16 | )/MMBtu | |||||||||||||||||||||||
Electricity | $ | 139 | $ | (126 | ) | Discounted Cash Flow | Forward basis price (per MWh) | $ | (7 | ) | — | $ | 15 | /MWh | $ | 3 | /MWh | |||||||||||||||||||||||
31-Dec-12 | ||||||||||||||||||||||||||||||||||||||||
Commodity Contracts | Derivative Assets | Derivative Liabilities | Valuation Techniques | Unobservable Input | Range | Weighted Average | ||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Natural Gas | $ | 24 | $ | (62 | ) | Discounted Cash Flow | Forward basis price (per MMBtu) | $ | (0.63 | ) | — | $ | 1.95 | /MMBtu | $ | 0.03 | /MMBtu | |||||||||||||||||||||||
Electricity | $ | 134 | $ | (111 | ) | Discounted Cash Flow | Forward basis price (per MWh) | $ | (2 | ) | — | $ | 16 | /MWh | $ | 3 | /MWh | |||||||||||||||||||||||
Fair Value of Financial Instruments [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||||||
The following table presents the carrying amount and fair value of financial instruments as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||||||||||
Carrying | Fair Value | Carrying | Fair Value | |||||||||||||||||||||||||||||||||||||
Amount | Level 1 | Level 2 | Level 3 | Amount | Level 1 | Level 2 | Level 3 | |||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Notes receivable, excluding capital leases | $ | 41 | $ | — | $ | — | $ | 41 | $ | 39 | $ | — | $ | — | $ | 39 | ||||||||||||||||||||||||
Dividends payable | $ | 116 | $ | 116 | $ | — | $ | — | $ | 107 | $ | 107 | $ | — | $ | — | ||||||||||||||||||||||||
Short-term borrowings | $ | 131 | $ | — | $ | 131 | $ | — | $ | 240 | $ | — | $ | 240 | $ | — | ||||||||||||||||||||||||
Long-term debt | $ | 8,094 | $ | 425 | $ | 7,551 | $ | 499 | $ | 7,813 | $ | 507 | $ | 7,453 | $ | 933 | ||||||||||||||||||||||||
Fair Value of Nuclear Decommissioning Trust Fund Assets Text Block [Table] | ' | |||||||||||||||||||||||||||||||||||||||
The following table summarizes the fair value of the nuclear decommissioning trust fund assets: | ||||||||||||||||||||||||||||||||||||||||
December 31, | December 31, | |||||||||||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Fermi 2 | $ | 1,172 | $ | 1,021 | ||||||||||||||||||||||||||||||||||||
Fermi 1 | 3 | 3 | ||||||||||||||||||||||||||||||||||||||
Low level radioactive waste | 16 | 13 | ||||||||||||||||||||||||||||||||||||||
Total | $ | 1,191 | $ | 1,037 | ||||||||||||||||||||||||||||||||||||
Schedule of Realized Gain (Loss) [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||||||
The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds: | ||||||||||||||||||||||||||||||||||||||||
Year Ended December 31 | ||||||||||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Realized gains | $ | 83 | $ | 37 | $ | 46 | ||||||||||||||||||||||||||||||||||
Realized losses | $ | (41 | ) | $ | (31 | ) | $ | (38 | ) | |||||||||||||||||||||||||||||||
Proceeds from sales of securities | $ | 1,118 | $ | 759 | $ | 833 | ||||||||||||||||||||||||||||||||||
Fair Value and Unrealized Gains for Nuclear Decommissioning Trust Fund Table [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||||||
The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds: | ||||||||||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||||||||||
Fair | Unrealized | Fair | Unrealized | |||||||||||||||||||||||||||||||||||||
Value | Gains | Value | Gains | |||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||||||
Equity securities | $ | 730 | $ | 201 | $ | 631 | $ | 122 | ||||||||||||||||||||||||||||||||
Debt securities | 442 | 12 | 399 | 27 | ||||||||||||||||||||||||||||||||||||
Cash and cash equivalents | 19 | — | 7 | — | ||||||||||||||||||||||||||||||||||||
$ | 1,191 | $ | 213 | $ | 1,037 | $ | 149 | |||||||||||||||||||||||||||||||||
Financial_and_Other_Derivative1
Financial and Other Derivative Instruments (Tables) | 12 Months Ended | |||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||
Derivative Instruments and Hedging Activities Disclosure [Abstract] | ' | |||||||||||||||||||||||||||||||
Fair value of derivative instruments | ' | |||||||||||||||||||||||||||||||
The following tables present the fair value of derivative instruments as of December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Derivative Assets | Derivative Liabilities | Derivative Assets | Derivative Liabilities | |||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Derivatives designated as hedging instruments: | ||||||||||||||||||||||||||||||||
Interest rate contracts | $ | — | $ | — | $ | — | $ | (1 | ) | |||||||||||||||||||||||
Derivatives not designated as hedging instruments: | ||||||||||||||||||||||||||||||||
Foreign currency exchange contracts | $ | — | $ | (1 | ) | $ | — | $ | — | |||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | 396 | (503 | ) | 645 | (661 | ) | ||||||||||||||||||||||||||
Electricity | 400 | (398 | ) | 360 | (351 | ) | ||||||||||||||||||||||||||
Other | 37 | (34 | ) | 11 | (7 | ) | ||||||||||||||||||||||||||
Total derivatives not designated as hedging instruments: | $ | 833 | $ | (936 | ) | $ | 1,016 | $ | (1,019 | ) | ||||||||||||||||||||||
Total derivatives: | ||||||||||||||||||||||||||||||||
Current | $ | 691 | $ | (773 | ) | $ | 862 | $ | (879 | ) | ||||||||||||||||||||||
Noncurrent | 142 | (163 | ) | 154 | (141 | ) | ||||||||||||||||||||||||||
Total derivatives | $ | 833 | $ | (936 | ) | $ | 1,016 | $ | (1,020 | ) | ||||||||||||||||||||||
Netting Offsets of Derivative Assets and Liabilities [Table Text Block] | ' | |||||||||||||||||||||||||||||||
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Gross Amounts of Recognized Assets (Liabilities) | Gross Amounts Offset in the Consolidated Statements of Financial Position | Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position | Gross Amounts of Recognized Assets (Liabilities) | Gross Amounts Offset in the Consolidated Statements of Financial Position | Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position | |||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Derivative assets: | ||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | $ | 396 | $ | (382 | ) | $ | 14 | $ | 645 | $ | (605 | ) | $ | 40 | ||||||||||||||||||
Electricity | 400 | (291 | ) | 109 | 360 | (258 | ) | 102 | ||||||||||||||||||||||||
Other | 37 | (34 | ) | 3 | 11 | (6 | ) | 5 | ||||||||||||||||||||||||
Total derivative assets | $ | 833 | $ | (707 | ) | $ | 126 | $ | 1,016 | $ | (869 | ) | $ | 147 | ||||||||||||||||||
Derivative liabilities: | ||||||||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | $ | (503 | ) | $ | 395 | $ | (108 | ) | $ | (661 | ) | $ | 605 | $ | (56 | ) | ||||||||||||||||
Electricity | (398 | ) | 269 | (129 | ) | (351 | ) | 258 | (93 | ) | ||||||||||||||||||||||
Other | (34 | ) | 34 | — | (7 | ) | 6 | (1 | ) | |||||||||||||||||||||||
Other derivative liabilities | (1 | ) | — | (1 | ) | (1 | ) | — | (1 | ) | ||||||||||||||||||||||
Total derivative liabilities | $ | (936 | ) | $ | 698 | $ | (238 | ) | $ | (1,020 | ) | $ | 869 | $ | (151 | ) | ||||||||||||||||
Netting Offsets of Derivative Assets and Liabilities Reconciliation to the Statements of Financial Position [Table Text Block] | ' | |||||||||||||||||||||||||||||||
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2013 and 2012: | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Derivative Assets | Derivative Liabilities | Derivative Assets | Derivative Liabilities | |||||||||||||||||||||||||||||
Current | Noncurrent | Current | Noncurrent | Current | Noncurrent | Current | Noncurrent | |||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Reconciliation of derivative instruments to Consolidated Statements of Financial Position: | ||||||||||||||||||||||||||||||||
Total fair value of derivatives | $ | 691 | $ | 142 | $ | (773 | ) | $ | (163 | ) | $ | 862 | $ | 154 | $ | (879 | ) | $ | (141 | ) | ||||||||||||
Counterparty netting | (566 | ) | (115 | ) | 566 | 115 | (754 | ) | (115 | ) | 754 | 115 | ||||||||||||||||||||
Collateral adjustment | (26 | ) | — | 12 | 5 | — | — | — | — | |||||||||||||||||||||||
Total derivatives as reported | $ | 99 | $ | 27 | $ | (195 | ) | $ | (43 | ) | $ | 108 | $ | 39 | $ | (125 | ) | $ | (26 | ) | ||||||||||||
Gain (Loss) Recognized in Income on Derivative | ' | |||||||||||||||||||||||||||||||
The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for years ended December 31, 2013 and 2012 is as follows: | ||||||||||||||||||||||||||||||||
Location of Gain | Gain (Loss) | |||||||||||||||||||||||||||||||
(Loss) Recognized | Recognized in | |||||||||||||||||||||||||||||||
in Income on Derivatives | Income on | |||||||||||||||||||||||||||||||
Derivatives for | ||||||||||||||||||||||||||||||||
Years Ended | ||||||||||||||||||||||||||||||||
December 31 | ||||||||||||||||||||||||||||||||
Derivatives not Designated as Hedging Instruments | 2013 | 2012 | ||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Foreign currency exchange contracts | Operating Revenue | $ | (1 | ) | $ | — | ||||||||||||||||||||||||||
Commodity Contracts: | ||||||||||||||||||||||||||||||||
Natural Gas | Operating Revenue | (48 | ) | (29 | ) | |||||||||||||||||||||||||||
Natural Gas | Fuel, purchased power and gas | (44 | ) | 25 | ||||||||||||||||||||||||||||
Electricity | Operating Revenue | 82 | 64 | |||||||||||||||||||||||||||||
Other | Operating Revenue | — | 5 | |||||||||||||||||||||||||||||
Total | $ | (11 | ) | $ | 65 | |||||||||||||||||||||||||||
Volume of Commodity Contracts [Table Text Block] | ' | |||||||||||||||||||||||||||||||
The following represents the cumulative gross volume of derivative contracts outstanding as of December 31, 2013: | ||||||||||||||||||||||||||||||||
Commodity | Number of Units | |||||||||||||||||||||||||||||||
Natural Gas (MMBtu) | 795,553,773 | |||||||||||||||||||||||||||||||
Electricity (MWh) | 55,658,483 | |||||||||||||||||||||||||||||||
Foreign Currency Exchange ($ CAD) | 65,074,206 | |||||||||||||||||||||||||||||||
FTR (MWh) | 10,485,618 |
Goodwill_Tables
Goodwill (Tables) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Goodwill and Intangible Assets Disclosure [Abstract] | ' | |||||||
Schedule of Goodwill [Table Text Block] | ' | |||||||
The change in the carrying amount of goodwill for the fiscal years ended December 31, 2013 and 2012 is as follows: | ||||||||
2013 | 2012 | |||||||
(In millions) | ||||||||
Balance as of January 1 | $ | 2,018 | $ | 2,020 | ||||
Goodwill attributable to sale of Unconventional Gas Production business | — | (2 | ) | |||||
Balance at December 31 | $ | 2,018 | $ | 2,018 | ||||
Acquisition_Tables
Acquisition (Tables) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Business Combinations [Abstract] | ' | |||
Schedule of Purchase Price Allocation [Table Text Block] | ' | |||
The following table summarizes the fair value of the assets acquired and liabilities assumed as of the closing date: | ||||
(In millions) | ||||
Cash | $ | 22 | ||
Accounts receivable | 14 | |||
Other current assets | 8 | |||
Property, plant and equipment | 100 | |||
Intangible assets | 75 | |||
Other noncurrent assets | 9 | |||
Current liabilities | (7 | ) | ||
Non-controlling interest | (1 | ) | ||
Total purchase price | $ | 220 | ||
Discontinued_Operations_Tables
Discontinued Operations (Tables) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Discontinued Operations and Disposal Groups [Abstract] | ' | |||||||
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block] | ' | |||||||
2012 | 2011 | |||||||
(In millions) | ||||||||
Operating Revenues | $ | 55 | $ | 39 | ||||
Operation and Maintenance | 24 | 16 | ||||||
Depreciation, Depletion and Amortization | 23 | 18 | ||||||
Taxes Other Than Income | 4 | 3 | ||||||
Asset (Gains) and Losses, Net | 83 | — | ||||||
134 | 37 | |||||||
Operating Income (Loss) | (79 | ) | 2 | |||||
Other (Income) and Deductions | 6 | 6 | ||||||
Loss Before Income Taxes | (85 | ) | (4 | ) | ||||
Income Tax Expense (Benefit) | (29 | ) | (1 | ) | ||||
Net Loss Attributable to DTE Energy Company | $ | (56 | ) | $ | (3 | ) |
Property_Plant_and_Equipment_T
Property, Plant and Equipment (Tables) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Property, Plant and Equipment [Abstract] | ' | |||||||
Property, Plant and Equipment [Table Text Block] | ' | |||||||
Summary of property by classification as of December 31: | ||||||||
2013 | 2012 | |||||||
Property, Plant and Equipment | (In millions) | |||||||
DTE Electric | ||||||||
Generation | $ | 11,127 | $ | 10,383 | ||||
Distribution | 7,603 | 7,306 | ||||||
Total DTE Electric | 18,730 | 17,689 | ||||||
DTE Gas | ||||||||
Distribution | 2,834 | 2,704 | ||||||
Storage | 431 | 426 | ||||||
Other | 836 | 852 | ||||||
Total DTE Gas | 4,101 | 3,982 | ||||||
Non-utility and other | 2,292 | 1,960 | ||||||
Total | 25,123 | 23,631 | ||||||
Less Accumulated Depreciation, Depletion and Amortization | ||||||||
DTE Electric | ||||||||
Generation | (4,004 | ) | (3,880 | ) | ||||
Distribution | (2,947 | ) | (2,837 | ) | ||||
Total DTE Electric | (6,951 | ) | (6,717 | ) | ||||
DTE Gas | ||||||||
Distribution | (1,129 | ) | (1,057 | ) | ||||
Storage | (138 | ) | (132 | ) | ||||
Other | (338 | ) | (365 | ) | ||||
Total DTE Gas | (1,605 | ) | (1,554 | ) | ||||
Non-utility and other | (767 | ) | (676 | ) | ||||
Total | (9,323 | ) | (8,947 | ) | ||||
Net Property, Plant and Equipment | $ | 15,800 | $ | 14,684 | ||||
Useful Life [Table Text Block] | ' | |||||||
The average estimated useful life for each major class of utility property, plant and equipment as of December 31, 2013 follows: | ||||||||
Estimated Useful Lives in Years | ||||||||
Utility | Generation | Distribution | Storage | |||||
Electric | 40 | 41 | N/A | |||||
Gas | N/A | 50 | 53 |
Jointly_Owned_Utility_Plant_Ta
Jointly Owned Utility Plant (Tables) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Jointly Owned Utility Plant, Net Ownership Amount [Abstract] | ' | |||||||
Schedule of Jointly Owned Utility Plants [Table Text Block] | ' | |||||||
Ownership information of the two utility plants as of December 31, 2013 was as follows: | ||||||||
Belle River | Ludington | |||||||
Hydroelectric | ||||||||
Pumped Storage | ||||||||
In-service date | 1984-1985 | 1973 | ||||||
Total plant capacity | 1,270 | MW | 1,872 | MW | ||||
Ownership interest | (a) | 49 | % | |||||
Investment in property, plant and equipment (in millions) | $ | 1,702 | $ | 354 | ||||
Accumulated depreciation (in millions) | $ | 969 | $ | 170 | ||||
_______________________________________ | ||||||||
(a) | DTE Electric's ownership interest is 63% in Unit No. 1, 81% of the facilities applicable to Belle River used jointly by the Belle River and St. Clair Power Plants and 75% in common facilities used at Unit No. 2. |
Asset_Retirement_Obligations_T
Asset Retirement Obligations (Tables) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Asset Retirement Obligation Disclosure [Abstract] | ' | |||
Schedule of Change in Asset Retirement Obligation [Table Text Block] | ' | |||
A reconciliation of the asset retirement obligations for 2013 follows: | ||||
(In millions) | ||||
Asset retirement obligations at December 31, 2012 | $ | 1,719 | ||
Accretion | 106 | |||
Liabilities incurred | 5 | |||
Liabilities settled | (13 | ) | ||
Revision in estimated cash flows | 10 | |||
Asset retirement obligations at December 31, 2013 | $ | 1,827 | ||
Regulatory_Matters_Tables
Regulatory Matters (Tables) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Regulatory Assets and Liabilities Disclosure [Abstract] | ' | |||||||
Schedule of Regulatory Assets [Table Text Block] | ' | |||||||
The following are balances and a brief description of the regulatory assets and liabilities at December 31: | ||||||||
2013 | 2012 | |||||||
(In millions) | ||||||||
Assets | ||||||||
Recoverable pension and other postretirement costs: | ||||||||
Pension | $ | 1,660 | $ | 2,420 | ||||
Other postretirement costs | — | 426 | ||||||
Asset retirement obligation | 394 | 424 | ||||||
Recoverable Michigan income taxes | 286 | 304 | ||||||
Recoverable income taxes related to securitized regulatory assets | 126 | 226 | ||||||
Cost to achieve Performance Excellence Process | 75 | 96 | ||||||
Other recoverable income taxes | 71 | 76 | ||||||
Unamortized loss on reacquired debt | 63 | 63 | ||||||
Deferred environmental costs | 59 | 58 | ||||||
Enterprise Business Systems costs | 13 | 16 | ||||||
Recoverable revenue decoupling | 9 | 28 | ||||||
Choice incentive mechanism | 3 | 66 | ||||||
Accrued PSCR/GCR revenue | — | 87 | ||||||
Recoverable restoration expense | — | 49 | ||||||
Other | 104 | 78 | ||||||
2,863 | 4,417 | |||||||
Less amount included in current assets | (26 | ) | (182 | ) | ||||
$ | 2,837 | $ | 4,235 | |||||
Securitized regulatory assets | $ | 231 | $ | 413 | ||||
Schedule of Regulatory Liabilities [Table Text Block] | ' | |||||||
2013 | 2012 | |||||||
(In millions) | ||||||||
Liabilities | ||||||||
Asset removal costs | $ | 351 | $ | 439 | ||||
Renewable energy | 277 | 230 | ||||||
Refundable revenue decoupling/deferred gain | 127 | 127 | ||||||
Negative pension offset | 84 | 105 | ||||||
Over recovery of Securitization | 72 | 54 | ||||||
Refundable other postretirement costs | 72 | — | ||||||
Accrued PSCR/GCR | 65 | 16 | ||||||
Refundable income taxes | 45 | 56 | ||||||
Energy optimization | 31 | 34 | ||||||
Fermi 2 refueling outage | 26 | 12 | ||||||
Refundable uncollectible expense | 12 | 37 | ||||||
Other | 2 | 10 | ||||||
$ | 1,164 | $ | 1,120 | |||||
Less amount included current liabilities | (302 | ) | (89 | ) | ||||
$ | 862 | $ | 1,031 | |||||
Income_Taxes_Tables
Income Taxes (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Income Tax Disclosure [Abstract] | ' | |||||||||||
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block] | ' | |||||||||||
Total income tax expense varied from the statutory federal income tax rate for the following reasons: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Income before income taxes | $ | 922 | $ | 960 | $ | 991 | ||||||
Income tax expense at 35% statutory rate | $ | 323 | $ | 336 | $ | 347 | ||||||
Production tax credits | (68 | ) | (49 | ) | (6 | ) | ||||||
Investment tax credits | (6 | ) | (6 | ) | (6 | ) | ||||||
Depreciation | (4 | ) | (4 | ) | (4 | ) | ||||||
AFUDC - Equity | (5 | ) | (4 | ) | (1 | ) | ||||||
Employee Stock Ownership Plan dividends | (4 | ) | (4 | ) | (4 | ) | ||||||
Domestic production activities deduction | (14 | ) | (14 | ) | (7 | ) | ||||||
State and local income taxes, net of federal benefit | 37 | 37 | 37 | |||||||||
Enactment of Michigan Corporate Income Tax, net of federal expense | — | — | (87 | ) | ||||||||
Other, net | (5 | ) | (6 | ) | (1 | ) | ||||||
Income tax expense | $ | 254 | $ | 286 | $ | 268 | ||||||
Effective income tax rate | 27.5 | % | 29.8 | % | 27 | % | ||||||
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block] | ' | |||||||||||
Components of income tax expense were as follows: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Current income tax expense (benefit) | ||||||||||||
Federal | $ | 74 | $ | 190 | $ | 27 | ||||||
State and other income tax | 16 | 49 | 21 | |||||||||
Total current income taxes | 90 | 239 | 48 | |||||||||
Deferred income tax expense (benefit) | ||||||||||||
Federal | 122 | 39 | 318 | |||||||||
State and other income tax | 42 | 8 | (98 | ) | ||||||||
Total deferred income taxes | 164 | 47 | 220 | |||||||||
Total income taxes from continuing operations | 254 | 286 | 268 | |||||||||
Discontinued operations | — | (29 | ) | (1 | ) | |||||||
Total | $ | 254 | $ | 257 | $ | 267 | ||||||
Schedule of Deferred Tax Assets and Liabilities [Table Text Block] | ' | |||||||||||
Deferred tax assets (liabilities) were comprised of the following at December 31: | ||||||||||||
2013 | 2012 | |||||||||||
(In millions) | ||||||||||||
Property, plant and equipment | $ | (3,372 | ) | $ | (3,389 | ) | ||||||
Securitized regulatory assets | (127 | ) | (256 | ) | ||||||||
Alternative minimum tax credit carry-forwards | 266 | 254 | ||||||||||
Merger basis differences | 18 | 42 | ||||||||||
Pension and benefits | (30 | ) | (33 | ) | ||||||||
Other comprehensive loss | — | 101 | ||||||||||
Derivative assets and liabilities | — | 66 | ||||||||||
State net operating loss and credit carry-forwards | 43 | 37 | ||||||||||
Other | (110 | ) | 41 | |||||||||
(3,312 | ) | (3,137 | ) | |||||||||
Less valuation allowance | (37 | ) | (33 | ) | ||||||||
$ | (3,349 | ) | $ | (3,170 | ) | |||||||
Current deferred income tax assets (liabilities) | $ | (28 | ) | $ | 21 | |||||||
Long-term deferred income tax liabilities | (3,321 | ) | (3,191 | ) | ||||||||
$ | (3,349 | ) | $ | (3,170 | ) | |||||||
Deferred income tax assets | $ | 1,808 | $ | 1,038 | ||||||||
Deferred income tax liabilities | (5,157 | ) | (4,208 | ) | ||||||||
$ | (3,349 | ) | $ | (3,170 | ) | |||||||
Schedule of Unrecognized Tax Benefits Roll Forward [Table Text Block] | ' | |||||||||||
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Balance at January 1 | $ | 11 | $ | 48 | $ | 28 | ||||||
Additions for tax positions of prior years | — | — | 27 | |||||||||
Reductions for tax positions of prior years | — | (2 | ) | (4 | ) | |||||||
Additions for tax positions of current year | — | 1 | 1 | |||||||||
Settlements | — | (30 | ) | (3 | ) | |||||||
Lapse of statute of limitations | (1 | ) | (6 | ) | (1 | ) | ||||||
Balance at December 31 | $ | 10 | $ | 11 | $ | 48 | ||||||
Earnings_Per_Share_Tables
Earnings Per Share (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Earnings Per Share [Abstract] | ' | |||||||||||
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block] | ' | |||||||||||
A reconciliation of both calculations is presented in the following table as of December 31: | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions, expect per share amounts) | ||||||||||||
Basic Earnings per Share | ||||||||||||
Net income attributable to DTE Energy Company | $ | 661 | $ | 610 | $ | 711 | ||||||
Average number of common shares outstanding | 175 | 171 | 169 | |||||||||
Weighted average net restricted shares outstanding | 1 | 1 | 1 | |||||||||
Dividends declared — common shares | $ | 453 | $ | 413 | $ | 392 | ||||||
Dividends declared — net restricted shares | 1 | 1 | 1 | |||||||||
Total distributed earnings | $ | 454 | $ | 414 | $ | 393 | ||||||
Net income less distributed earnings | $ | 207 | $ | 196 | $ | 318 | ||||||
Distributed (dividends per common share) | $ | 2.59 | $ | 2.42 | $ | 2.32 | ||||||
Undistributed | 1.17 | 1.14 | 1.87 | |||||||||
Total Basic Earnings per Common Share | $ | 3.76 | $ | 3.56 | $ | 4.19 | ||||||
Diluted Earnings per Share | ||||||||||||
Net income attributable to DTE Energy Company | $ | 661 | $ | 610 | $ | 711 | ||||||
Average number of common shares outstanding | 175 | 171 | 169 | |||||||||
Average incremental shares from assumed exercise of options | — | 1 | 1 | |||||||||
Common shares for dilutive calculation | 175 | 172 | 170 | |||||||||
Weighted average net restricted shares outstanding | 1 | 1 | 1 | |||||||||
Dividends declared — common shares | $ | 453 | $ | 413 | $ | 392 | ||||||
Dividends declared — net restricted shares | 1 | 1 | 1 | |||||||||
Total distributed earnings | $ | 454 | $ | 414 | $ | 393 | ||||||
Net income less distributed earnings | $ | 207 | $ | 196 | $ | 318 | ||||||
Distributed (dividends per common share) | $ | 2.59 | $ | 2.42 | $ | 2.32 | ||||||
Undistributed | 1.17 | 1.13 | 1.86 | |||||||||
Total Diluted Earnings per Common Share | $ | 3.76 | $ | 3.55 | $ | 4.18 | ||||||
LongTerm_Debt_Tables
Long-Term Debt (Tables) | 12 Months Ended | |||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||
Long-term Debt, Unclassified [Abstract] | ' | |||||||||||||||||||||||||||
Schedule of Long-term Debt Instruments [Table Text Block] | ' | |||||||||||||||||||||||||||
The Company’s long-term debt outstanding and weighted average interest rates (a) of debt outstanding at December 31 were: | ||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
Mortgage bonds, notes, and other | ||||||||||||||||||||||||||||
DTE Energy Debt, Unsecured | ||||||||||||||||||||||||||||
6.1% due 2014 to 2033 | $ | 1,297 | $ | 1,298 | ||||||||||||||||||||||||
DTE Electric Taxable Debt, Principally Secured | ||||||||||||||||||||||||||||
4.7% due 2014 to 2043 | 4,286 | 3,777 | ||||||||||||||||||||||||||
DTE Electric Tax-Exempt Revenue Bonds (b) | ||||||||||||||||||||||||||||
5.1% due 2014 to 2036 | 558 | 707 | ||||||||||||||||||||||||||
DTE Gas Taxable Debt, Principally Secured | ||||||||||||||||||||||||||||
5.6% due 2014 to 2042 | 1,029 | 919 | ||||||||||||||||||||||||||
Other Long-Term Debt, Including Non-Recourse Debt | 142 | 153 | ||||||||||||||||||||||||||
7,312 | 6,854 | |||||||||||||||||||||||||||
Less amount due within one year | (694 | ) | (634 | ) | ||||||||||||||||||||||||
$ | 6,618 | $ | 6,220 | |||||||||||||||||||||||||
Securitization bonds | ||||||||||||||||||||||||||||
6.6% due 2015 | $ | 302 | $ | 479 | ||||||||||||||||||||||||
Less amount due within one year | (197 | ) | (177 | ) | ||||||||||||||||||||||||
$ | 105 | $ | 302 | |||||||||||||||||||||||||
Junior Subordinated Debentures | ||||||||||||||||||||||||||||
6.5% due 2061 | $ | 280 | $ | 280 | ||||||||||||||||||||||||
5.25% due 2062 | 200 | 200 | ||||||||||||||||||||||||||
$ | 480 | $ | 480 | |||||||||||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||
(a) | Weighted average interest rates as of December 31, 2013 are shown below the description of each category of debt. | |||||||||||||||||||||||||||
(b) | DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds. | |||||||||||||||||||||||||||
Schedule of Issued Debt [Table Text Block] | ' | |||||||||||||||||||||||||||
In 2013, the following debt was issued: | ||||||||||||||||||||||||||||
Company | Month Issued | Type | Interest Rate | Maturity | Amount | |||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
DTE Electric | March | Mortgage Bonds (a) | 4 | % | 2043 | $ | 375 | |||||||||||||||||||||
DTE Electric | August | Mortgage Bonds (a) | 3.65 | % | 2024 | 400 | ||||||||||||||||||||||
DTE Energy | November | Senior Notes (a) | 3.85 | % | 2023 | 300 | ||||||||||||||||||||||
DTE Gas | December | Mortgage Bonds (a) | 3.64 | % | 2023 | 50 | ||||||||||||||||||||||
DTE Gas | December | Mortgage Bonds (a) | 3.74 | % | 2025 | 70 | ||||||||||||||||||||||
DTE Gas | December | Mortgage Bonds (a) | 3.94 | % | 2028 | 50 | ||||||||||||||||||||||
$ | 1,245 | |||||||||||||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||
(a) | Proceeds were used for the redemption of long-term debt, repayment of short-term borrowings and general corporate purposes. | |||||||||||||||||||||||||||
Schedule of Extinguishment of Debt [Table Text Block] | ' | |||||||||||||||||||||||||||
In 2013, the following debt was redeemed: | ||||||||||||||||||||||||||||
Company | Month | Type | Interest Rate | Maturity | Amount | |||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
DTE Electric | March | Securitization Bonds | 6.42 | % | 2013 | $ | 88 | |||||||||||||||||||||
DTE Electric | March | Tax Exempt Revenue Bonds (a) | 5.3 | % | 2030 | 51 | ||||||||||||||||||||||
DTE Electric | April | Other Long-Term Debt | Various | 2013 | 13 | |||||||||||||||||||||||
DTE Gas | April | Senior Notes | 5.26 | % | 2013 | 60 | ||||||||||||||||||||||
DTE Energy | June | Senior Notes | Variable | 2013 | 300 | |||||||||||||||||||||||
DTE Electric | September | Securitization Bonds | 6.62 | % | 2013 | 89 | ||||||||||||||||||||||
DTE Electric | September | Senior Notes | 6.4 | % | 2013 | 250 | ||||||||||||||||||||||
DTE Electric | December | Tax Exempt Revenue Bonds (a) | 5.5 | % | 2030 | 49 | ||||||||||||||||||||||
DTE Electric | December | Tax Exempt Revenue Bonds (a) | 6.75 | % | 2038 | 50 | ||||||||||||||||||||||
DTE Energy | Various | Other Long-Term Debt | Various | 2013 | 11 | |||||||||||||||||||||||
$ | 961 | |||||||||||||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||
(a) | DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds. | |||||||||||||||||||||||||||
Schedule of Maturities of Long-term Debt [Table Text Block] | ' | |||||||||||||||||||||||||||
The following table shows the scheduled debt maturities: | ||||||||||||||||||||||||||||
2014 | 2015 | 2016 | 2017 | 2018 | 2019 and | Total | ||||||||||||||||||||||
Thereafter | ||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||
Amount to mature | $ | 891 | $ | 476 | $ | 465 | $ | 9 | $ | 407 | $ | 5,846 | $ | 8,094 | ||||||||||||||
Preferred_and_Preferenced_Secu1
Preferred and Preferenced Securities (Tables) | 12 Months Ended | |||||||||
Dec. 31, 2013 | ||||||||||
Preferred Stock, Number of Shares, Par Value and Other Disclosures [Abstract] | ' | |||||||||
Preferred and Preference Securities [Table Text Block] | ' | |||||||||
As of December 31, 2013, the amount of authorized and unissued stock is as follows: | ||||||||||
Company | Type of Stock | Par Value | Shares Authorized | |||||||
DTE Energy | Preferred | $ | — | 5,000,000 | ||||||
DTE Electric | Preferred | $ | 100 | 6,747,484 | ||||||
DTE Electric | Preference | $ | 1 | 30,000,000 | ||||||
DTE Gas | Preferred | $ | 1 | 7,000,000 | ||||||
DTE Gas | Preference | $ | 1 | 4,000,000 | ||||||
ShortTerm_Credit_Arrangements_1
Short-Term Credit Arrangements and Borrowings (Tables) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Short-term Debt [Abstract] | ' | |||||||||||||||
Schedule of Line of Credit Facilities [Table Text Block] | ' | |||||||||||||||
The availability under the facilities in place at December 31, 2013 is shown in the following table: | ||||||||||||||||
DTE Energy | DTE Electric | DTE Gas | Total | |||||||||||||
(In millions) | ||||||||||||||||
Unsecured letter of credit facility, expiring in May 2014 | $ | 50 | $ | — | $ | — | $ | 50 | ||||||||
Unsecured letter of credit facility, expiring in August 2015 | 125 | — | — | 125 | ||||||||||||
Unsecured revolving credit facility, expiring April 2018 | 1,200 | 300 | 300 | 1,800 | ||||||||||||
1,375 | 300 | 300 | 1,975 | |||||||||||||
Amounts outstanding at December 31, 2013: | ||||||||||||||||
Commercial paper issuances | 35 | — | 96 | 131 | ||||||||||||
Letters of credit | 244 | — | — | 244 | ||||||||||||
279 | — | 96 | 375 | |||||||||||||
Net availability at December 31, 2013 | $ | 1,096 | $ | 300 | $ | 204 | $ | 1,600 | ||||||||
Capital_and_Operating_Leases_T
Capital and Operating Leases (Tables) | 12 Months Ended | |||||||
Dec. 31, 2013 | ||||||||
Capital and Operating Leases [Abstract] | ' | |||||||
Capital and Operating Leases [Table Text Block] | ' | |||||||
Future minimum lease payments under non-cancelable leases at December 31, 2013 were: | ||||||||
Capital | Operating | |||||||
Leases | Leases | |||||||
(In millions) | ||||||||
2014 | $ | 8 | $ | 35 | ||||
2015 | 8 | 31 | ||||||
2016 | 3 | 27 | ||||||
2017 | — | 25 | ||||||
2018 | — | 20 | ||||||
Thereafter | — | 92 | ||||||
Total minimum lease payments | $ | 19 | $ | 230 | ||||
Less imputed interest | 1 | |||||||
Present value of net minimum lease payments | 18 | |||||||
Less current portion | 7 | |||||||
Non-current portion | $ | 11 | ||||||
Schedule of Capital Lease of Lessor [Table Text Block] | ' | |||||||
The components of the net investment in the capital leases at December 31, 2013, were as follows: | ||||||||
(In millions) | ||||||||
2014 | $ | 12 | ||||||
2015 | 12 | |||||||
2016 | 12 | |||||||
2017 | 12 | |||||||
2018 | 12 | |||||||
Thereafter | 19 | |||||||
Total minimum future lease receipts | 79 | |||||||
Residual value of leased pipeline | 40 | |||||||
Less unearned income | (40 | ) | ||||||
Net investment in capital lease | 79 | |||||||
Less current portion | (5 | ) | ||||||
$ | 74 | |||||||
Commitments_and_Contingencies_1
Commitments and Contingencies (Tables) | 12 Months Ended | |||
Dec. 31, 2013 | ||||
Commitments and Contingencies Disclosure [Abstract] | ' | |||
Long-term Purchase Commitment [Table Text Block] | ' | |||
The Company estimates that these commitments will be approximately $8.6 billion from 2014 through 2051 as detailed in the following table: | ||||
(In millions) | ||||
2014 | $ | 2,617 | ||
2015 | 1,195 | |||
2016 | 643 | |||
2017 | 345 | |||
2018 | 311 | |||
2019 — 2051 | 3,487 | |||
$ | 8,598 | |||
Retirement_Benefits_and_Truste1
Retirement Benefits and Trusteed Assets (Tables) | 12 Months Ended | |||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||
Pension Plan, Defined Benefit [Member] | ' | |||||||||||||||||||||||||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | |||||||||||||||||||||||||||||||
Schedule of Net Benefit Costs [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Net pension cost includes the following components: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Service cost | $ | 94 | $ | 82 | $ | 69 | ||||||||||||||||||||||||||
Interest cost | 192 | 204 | 202 | |||||||||||||||||||||||||||||
Expected return on plan assets | (266 | ) | (244 | ) | (246 | ) | ||||||||||||||||||||||||||
Amortization of: | ||||||||||||||||||||||||||||||||
Net loss | 208 | 176 | 142 | |||||||||||||||||||||||||||||
Prior service cost | — | — | 3 | |||||||||||||||||||||||||||||
Special termination benefits | — | 2 | 2 | |||||||||||||||||||||||||||||
Net pension cost | $ | 228 | $ | 220 | $ | 172 | ||||||||||||||||||||||||||
Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block] | ' | |||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income | ||||||||||||||||||||||||||||||||
Net actuarial (gain) loss | $ | (581 | ) | $ | 395 | |||||||||||||||||||||||||||
Amortization of net actuarial loss | (208 | ) | (178 | ) | ||||||||||||||||||||||||||||
Total recognized Regulatory assets and Other comprehensive income | $ | (789 | ) | $ | 217 | |||||||||||||||||||||||||||
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income | $ | (561 | ) | $ | 437 | |||||||||||||||||||||||||||
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 151 | $ | 202 | ||||||||||||||||||||||||||||
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | ' | |||||||||||||||||||||||||||||||
The following table reconciles the obligations, assets and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in the Consolidated Statements of Financial Position at December 31: | ||||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Accumulated benefit obligation, end of year | $ | 4,068 | $ | 4,349 | ||||||||||||||||||||||||||||
Change in projected benefit obligation | ||||||||||||||||||||||||||||||||
Projected benefit obligation, beginning of year | $ | 4,729 | $ | 4,195 | ||||||||||||||||||||||||||||
Service cost | 94 | 82 | ||||||||||||||||||||||||||||||
Interest cost | 192 | 204 | ||||||||||||||||||||||||||||||
Plan amendments | (3 | ) | — | |||||||||||||||||||||||||||||
Actuarial (gain) loss | (400 | ) | 474 | |||||||||||||||||||||||||||||
Special termination benefits | — | 2 | ||||||||||||||||||||||||||||||
Benefits paid | (232 | ) | (228 | ) | ||||||||||||||||||||||||||||
Projected benefit obligation, end of year | $ | 4,380 | $ | 4,729 | ||||||||||||||||||||||||||||
Change in plan assets | ||||||||||||||||||||||||||||||||
Plan assets at fair value, beginning of year | $ | 3,223 | $ | 2,886 | ||||||||||||||||||||||||||||
Actual return on plan assets | 445 | 325 | ||||||||||||||||||||||||||||||
Company contributions | 284 | 240 | ||||||||||||||||||||||||||||||
Benefits paid | (232 | ) | (228 | ) | ||||||||||||||||||||||||||||
Plan assets at fair value, end of year | $ | 3,720 | $ | 3,223 | ||||||||||||||||||||||||||||
Funded status of the plans | $ | (660 | ) | $ | (1,506 | ) | ||||||||||||||||||||||||||
Amount recorded as: | ||||||||||||||||||||||||||||||||
Current liabilities | $ | (7 | ) | $ | (8 | ) | ||||||||||||||||||||||||||
Noncurrent liabilities | (653 | ) | (1,498 | ) | ||||||||||||||||||||||||||||
$ | (660 | ) | $ | (1,506 | ) | |||||||||||||||||||||||||||
Amounts recognized in Accumulated other comprehensive loss, pre-tax | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 174 | $ | 205 | ||||||||||||||||||||||||||||
Prior service (credit) | (1 | ) | (2 | ) | ||||||||||||||||||||||||||||
$ | 173 | $ | 203 | |||||||||||||||||||||||||||||
Amounts recognized in Regulatory assets (see Note 11) | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 1,654 | $ | 2,413 | ||||||||||||||||||||||||||||
Prior service cost | 6 | 7 | ||||||||||||||||||||||||||||||
$ | 1,660 | $ | 2,420 | |||||||||||||||||||||||||||||
Schedule of Expected Benefit Payments [Table Text Block] | ' | |||||||||||||||||||||||||||||||
At December 31, 2013, the benefits related to the Company’s qualified and nonqualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows: | ||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
2014 | $ | 242 | ||||||||||||||||||||||||||||||
2015 | 250 | |||||||||||||||||||||||||||||||
2016 | 258 | |||||||||||||||||||||||||||||||
2017 | 268 | |||||||||||||||||||||||||||||||
2018 | 280 | |||||||||||||||||||||||||||||||
2019-2023 | 1,529 | |||||||||||||||||||||||||||||||
$ | 2,827 | |||||||||||||||||||||||||||||||
Schedule of Assumptions Used [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Assumptions used in determining the projected benefit obligation and net pension costs are listed below: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
Projected benefit obligation | ||||||||||||||||||||||||||||||||
Discount rate | 4.95 | % | 4.15 | % | 5 | % | ||||||||||||||||||||||||||
Rate of compensation increase | 4.2 | % | 4.2 | % | 4.2 | % | ||||||||||||||||||||||||||
Net pension costs | ||||||||||||||||||||||||||||||||
Discount rate | 4.15 | % | 5 | % | 5.5 | % | ||||||||||||||||||||||||||
Rate of compensation increase | 4.2 | % | 4.2 | % | 4 | % | ||||||||||||||||||||||||||
Expected long-term rate of return on plan assets | 8.25 | % | 8.25 | % | 8.5 | % | ||||||||||||||||||||||||||
Schedule of Allocation of Plan Assets [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Target allocations for pension plan assets as of December 31, 2013 are listed below: | ||||||||||||||||||||||||||||||||
U.S. Large Cap Equity Securities | 22 | % | ||||||||||||||||||||||||||||||
U.S. Small Cap and Mid Cap Equity Securities | 5 | |||||||||||||||||||||||||||||||
Non U.S. Equity Securities | 20 | |||||||||||||||||||||||||||||||
Fixed Income Securities | 25 | |||||||||||||||||||||||||||||||
Hedge Funds and Similar Investments | 20 | |||||||||||||||||||||||||||||||
Private Equity and Other | 8 | |||||||||||||||||||||||||||||||
100 | % | |||||||||||||||||||||||||||||||
Pension Plans Fair Value Hierachy Level [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Fair Value Measurements for pension plan assets at December 31, 2013 and 2012 (a): | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Asset Category: | ||||||||||||||||||||||||||||||||
Short-term investments (b) | $ | 22 | $ | — | $ | — | $ | 22 | $ | — | $ | 24 | $ | — | $ | 24 | ||||||||||||||||
Equity securities | ||||||||||||||||||||||||||||||||
U.S. Large Cap (c) | 896 | — | — | 896 | 688 | 44 | — | 732 | ||||||||||||||||||||||||
U.S. Small/Mid Cap (d) | 221 | — | — | 221 | 153 | 5 | — | 158 | ||||||||||||||||||||||||
Non U.S. (e) | 611 | 130 | — | 741 | 530 | 120 | — | 650 | ||||||||||||||||||||||||
Fixed income securities (f) | 16 | 921 | — | 937 | 87 | 765 | — | 852 | ||||||||||||||||||||||||
Hedge Funds and Similar Investments (g) | 268 | 70 | 395 | 733 | 209 | 80 | 339 | 628 | ||||||||||||||||||||||||
Private Equity and Other (h) | — | — | 170 | 170 | — | — | 179 | 179 | ||||||||||||||||||||||||
Total | $ | 2,034 | $ | 1,121 | $ | 565 | $ | 3,720 | $ | 1,667 | $ | 1,038 | $ | 518 | $ | 3,223 | ||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||||||
(a) | See Note 3 — Fair Value for a description of levels within the fair value hierarchy. | |||||||||||||||||||||||||||||||
(b) | This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services. | |||||||||||||||||||||||||||||||
(c) | This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(d) | This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(e) | This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(f) | This category includes corporate bonds from diversified industries, U.S. Treasuries, and mortgage-backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(g) | This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing. | |||||||||||||||||||||||||||||||
(h) | This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions. | |||||||||||||||||||||||||||||||
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Fair Value Measurements Using Significant Unobservable Inputs (Level 3): | ||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||
Hedge Funds | Private Equity | Total | Hedge Funds | Private Equity | Total | |||||||||||||||||||||||||||
and Similar | and Other | and Similar | and Other | |||||||||||||||||||||||||||||
Investments | Investments | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Beginning Balance at January 1 | $ | 339 | $ | 179 | $ | 518 | $ | 296 | $ | 168 | $ | 464 | ||||||||||||||||||||
Total realized/unrealized gains (losses): | ||||||||||||||||||||||||||||||||
Realized gains (losses) | — | 18 | 18 | 18 | (6 | ) | 12 | |||||||||||||||||||||||||
Unrealized gains (losses) | 40 | (14 | ) | 26 | (5 | ) | 12 | 7 | ||||||||||||||||||||||||
Purchases, sales and settlements: | ||||||||||||||||||||||||||||||||
Purchases | 16 | 15 | 31 | 250 | 33 | 283 | ||||||||||||||||||||||||||
Sales | — | (28 | ) | (28 | ) | (220 | ) | (28 | ) | (248 | ) | |||||||||||||||||||||
Ending Balance at December 31 | $ | 395 | $ | 170 | $ | 565 | $ | 339 | $ | 179 | $ | 518 | ||||||||||||||||||||
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period | $ | 38 | $ | 3 | $ | 41 | $ | 16 | $ | 6 | $ | 22 | ||||||||||||||||||||
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | |||||||||||||||||||||||||||||||
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | |||||||||||||||||||||||||||||||
Schedule of Net Benefit Costs [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Net other postretirement cost includes the following components: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Service cost | $ | 47 | $ | 68 | $ | 64 | ||||||||||||||||||||||||||
Interest cost | 88 | 120 | 121 | |||||||||||||||||||||||||||||
Expected return on plan assets | (110 | ) | (92 | ) | (94 | ) | ||||||||||||||||||||||||||
Amortization of: | ||||||||||||||||||||||||||||||||
Net loss | 64 | 80 | 55 | |||||||||||||||||||||||||||||
Prior service credit | (131 | ) | (27 | ) | (26 | ) | ||||||||||||||||||||||||||
Net transition asset | — | 2 | 2 | |||||||||||||||||||||||||||||
Net other postretirement cost (benefit) | $ | (42 | ) | $ | 151 | $ | 122 | |||||||||||||||||||||||||
Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block] | ' | |||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Other changes in plan assets and APBO recognized in Regulatory assets (liabilities) and Other comprehensive income | ||||||||||||||||||||||||||||||||
Net actuarial gain | $ | (353 | ) | $ | (34 | ) | ||||||||||||||||||||||||||
Amortization of net actuarial loss | (64 | ) | (80 | ) | ||||||||||||||||||||||||||||
Prior service credit | (218 | ) | (264 | ) | ||||||||||||||||||||||||||||
Amortization of prior service credit | 131 | 27 | ||||||||||||||||||||||||||||||
Amortization of transition asset | — | (2 | ) | |||||||||||||||||||||||||||||
Total recognized in Regulatory assets (liabilities) and Other comprehensive income | $ | (504 | ) | $ | (353 | ) | ||||||||||||||||||||||||||
Total recognized in net periodic benefit cost, Regulatory assets (liabilities) and Other comprehensive income | $ | (546 | ) | $ | (202 | ) | ||||||||||||||||||||||||||
Estimated amounts to be amortized from Regulatory assets (liabilities) and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 21 | $ | 69 | ||||||||||||||||||||||||||||
Prior service credit | $ | (144 | ) | $ | (91 | ) | ||||||||||||||||||||||||||
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | ' | |||||||||||||||||||||||||||||||
The following table reconciles the obligations, assets and funded status of the plans including amounts recorded as Accrued postretirement liability in the Consolidated Statements of Financial Position at December 31: | ||||||||||||||||||||||||||||||||
2013 | 2012 | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Change in accumulated postretirement benefit obligation | ||||||||||||||||||||||||||||||||
Accumulated postretirement benefit obligation, beginning of year | $ | 2,315 | $ | 2,470 | ||||||||||||||||||||||||||||
Service cost | 47 | 68 | ||||||||||||||||||||||||||||||
Interest cost | 88 | 120 | ||||||||||||||||||||||||||||||
Plan amendments | (218 | ) | (264 | ) | ||||||||||||||||||||||||||||
Actuarial (gain) loss | (267 | ) | 5 | |||||||||||||||||||||||||||||
Medicare Part D subsidy | 1 | 6 | ||||||||||||||||||||||||||||||
Benefits paid | (88 | ) | (90 | ) | ||||||||||||||||||||||||||||
Accumulated postretirement benefit obligation, end of year | $ | 1,878 | $ | 2,315 | ||||||||||||||||||||||||||||
Change in plan assets | ||||||||||||||||||||||||||||||||
Plan assets at fair value, beginning of year | $ | 1,153 | $ | 985 | ||||||||||||||||||||||||||||
Actual return on plan assets | 196 | 131 | ||||||||||||||||||||||||||||||
Company contributions | 264 | 140 | ||||||||||||||||||||||||||||||
Benefits paid | (86 | ) | (103 | ) | ||||||||||||||||||||||||||||
Plan assets at fair value, end of year | $ | 1,527 | $ | 1,153 | ||||||||||||||||||||||||||||
Funded status, end of year | $ | (351 | ) | $ | (1,162 | ) | ||||||||||||||||||||||||||
Amount recorded as: | ||||||||||||||||||||||||||||||||
Current liabilities | $ | (1 | ) | $ | (2 | ) | ||||||||||||||||||||||||||
Noncurrent liabilities | (350 | ) | (1,160 | ) | ||||||||||||||||||||||||||||
$ | (351 | ) | $ | (1,162 | ) | |||||||||||||||||||||||||||
Amounts recognized in Accumulated other comprehensive loss, pre-tax | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 29 | $ | 40 | ||||||||||||||||||||||||||||
Prior service credit | (10 | ) | (14 | ) | ||||||||||||||||||||||||||||
Net transition asset | — | (1 | ) | |||||||||||||||||||||||||||||
$ | 19 | $ | 25 | |||||||||||||||||||||||||||||
Amounts recognized in Regulatory assets (liabilities) (See Note 11) | ||||||||||||||||||||||||||||||||
Net actuarial loss | $ | 321 | $ | 727 | ||||||||||||||||||||||||||||
Prior service credit | (393 | ) | (302 | ) | ||||||||||||||||||||||||||||
Net transition obligation | — | 1 | ||||||||||||||||||||||||||||||
$ | (72 | ) | $ | 426 | ||||||||||||||||||||||||||||
Schedule of Expected Benefit Payments [Table Text Block] | ' | |||||||||||||||||||||||||||||||
At December 31, 2013, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows: | ||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
2014 | $ | 103 | ||||||||||||||||||||||||||||||
2015 | 110 | |||||||||||||||||||||||||||||||
2016 | 115 | |||||||||||||||||||||||||||||||
2017 | 123 | |||||||||||||||||||||||||||||||
2018 | 130 | |||||||||||||||||||||||||||||||
2019 — 2023 | 724 | |||||||||||||||||||||||||||||||
$ | 1,305 | |||||||||||||||||||||||||||||||
Schedule of Assumptions Used [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs are listed below: | ||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||
Accumulated postretirement benefit obligation | ||||||||||||||||||||||||||||||||
Discount rate | 4.95 | % | 4.15 | % | 5 | % | ||||||||||||||||||||||||||
Health care trend rate pre- and post- 65 | 7.5 | / 6.50% | 7 | % | 7 | % | ||||||||||||||||||||||||||
Ultimate health care trend rate | 4.5 | % | 5 | % | 5 | % | ||||||||||||||||||||||||||
Year in which ultimate reached pre- and post- 65 | 2025 / 2024 | 2021 | 2020 | |||||||||||||||||||||||||||||
Other postretirement benefit costs | ||||||||||||||||||||||||||||||||
Discount rate (prior to interim remeasurement) | 4.15 | % | 5 | % | 5.5 | % | ||||||||||||||||||||||||||
Discount rate (post interim remeasurement) | 4.3 | % | N/A | N/A | ||||||||||||||||||||||||||||
Expected long-term rate of return on plan assets | 8.25 | % | 8.25 | % | 8.75 | % | ||||||||||||||||||||||||||
Health care trend rate pre- and post- 65 | 7 | % | 7 | % | 7 | % | ||||||||||||||||||||||||||
Ultimate health care trend rate | 5 | % | 5 | % | 5 | % | ||||||||||||||||||||||||||
Year in which ultimate reached | 2021 | 2020 | 2019 | |||||||||||||||||||||||||||||
Schedule of Allocation of Plan Assets [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Target allocations for other postretirement benefit plan assets as of December 31, 2013 are listed below: | ||||||||||||||||||||||||||||||||
U.S. Large Cap Equity Securities | 17 | % | ||||||||||||||||||||||||||||||
U.S. Small Cap and Mid Cap Equity Securities | 4 | |||||||||||||||||||||||||||||||
Non U.S. Equity Securities | 20 | |||||||||||||||||||||||||||||||
Fixed Income Securities | 25 | |||||||||||||||||||||||||||||||
Hedge Funds and Similar Investments | 20 | |||||||||||||||||||||||||||||||
Private Equity and Other | 14 | |||||||||||||||||||||||||||||||
100 | % | |||||||||||||||||||||||||||||||
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Fair Value Measurements Using Significant Unobservable Inputs (Level 3): | ||||||||||||||||||||||||||||||||
Year Ended December 31, 2013 | Year Ended December 31, 2012 | |||||||||||||||||||||||||||||||
Hedge Funds | Private Equity | Total | Hedge Funds | Private Equity | Total | |||||||||||||||||||||||||||
and Similar | and Other | and Similar | and Other | |||||||||||||||||||||||||||||
Investments | Investments | |||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||
Beginning Balance at January 1 | $ | 119 | $ | 86 | $ | 205 | $ | 95 | $ | 60 | $ | 155 | ||||||||||||||||||||
Total realized/unrealized gains (losses): | ||||||||||||||||||||||||||||||||
Realized gains (losses) | — | 2 | 2 | 6 | (11 | ) | (5 | ) | ||||||||||||||||||||||||
Unrealized gains | 14 | 7 | 21 | — | 14 | 14 | ||||||||||||||||||||||||||
Purchases, sales and settlements: | ||||||||||||||||||||||||||||||||
Purchases | 26 | 15 | 41 | 86 | 36 | 122 | ||||||||||||||||||||||||||
Sales | — | (9 | ) | (9 | ) | (68 | ) | (13 | ) | (81 | ) | |||||||||||||||||||||
Ending Balance at December 31 | $ | 159 | $ | 101 | $ | 260 | $ | 119 | $ | 86 | $ | 205 | ||||||||||||||||||||
The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period | $ | 14 | $ | 9 | $ | 23 | $ | 6 | $ | 2 | $ | 8 | ||||||||||||||||||||
Other Postretirement Benefit Plans Hierachy Level [Table Text Block] | ' | |||||||||||||||||||||||||||||||
Fair Value Measurements for other postretirement benefit plan assets at December 31, 2013 and 2012 (a): | ||||||||||||||||||||||||||||||||
31-Dec-13 | 31-Dec-12 | |||||||||||||||||||||||||||||||
Level 1 | Level 2 | Level 3 | Total | Level 1 | Level 2 | Level 3 | Total | |||||||||||||||||||||||||
Asset Category: | (In millions) | |||||||||||||||||||||||||||||||
Short-term investments (b) | $ | 5 | $ | — | $ | — | $ | 5 | $ | 1 | $ | 2 | $ | — | $ | 3 | ||||||||||||||||
Equity securities: | ||||||||||||||||||||||||||||||||
U.S. Large Cap (c) | 302 | — | — | 302 | 189 | 3 | — | 192 | ||||||||||||||||||||||||
U.S. Small/Mid Cap (d) | 147 | — | — | 147 | 105 | — | — | 105 | ||||||||||||||||||||||||
Non U.S. (e) | 282 | 9 | — | 291 | 230 | 7 | — | 237 | ||||||||||||||||||||||||
Fixed income securities (f) | 17 | 350 | — | 367 | 38 | 247 | — | 285 | ||||||||||||||||||||||||
Hedge Funds and Similar Investments (g) | 130 | 25 | 159 | 314 | 102 | 24 | 119 | 245 | ||||||||||||||||||||||||
Private Equity and Other (h) | — | — | 101 | 101 | — | — | 86 | 86 | ||||||||||||||||||||||||
Total | $ | 883 | $ | 384 | $ | 260 | $ | 1,527 | $ | 665 | $ | 283 | $ | 205 | $ | 1,153 | ||||||||||||||||
_______________________________________ | ||||||||||||||||||||||||||||||||
(a) | See Note 3 — Fair Value for a description of levels within the fair value hierarchy. | |||||||||||||||||||||||||||||||
(b) | This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services. | |||||||||||||||||||||||||||||||
(c) | This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(d) | This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(e) | This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(f) | This category includes corporate bonds from diversified industries, U.S. Treasuries, bank loans and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets. | |||||||||||||||||||||||||||||||
(g) | This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing. | |||||||||||||||||||||||||||||||
(h) | This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions. |
StockBased_Compensation_Tables
Stock-Based Compensation (Tables) | 12 Months Ended | |||||||||||||||
Dec. 31, 2013 | ||||||||||||||||
Share-based Compensation [Abstract] | ' | |||||||||||||||
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Table Text Block] | ' | |||||||||||||||
Stock-based compensation for the reporting periods is as follows: | ||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||
(In millions) | ||||||||||||||||
Stock-based compensation expense | $ | 99 | $ | 83 | $ | 66 | ||||||||||
Tax benefit | 38 | 33 | 25 | |||||||||||||
Stock-based compensation cost capitalized in property, plant and equipment | 15 | 5 | 4 | |||||||||||||
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block] | ' | |||||||||||||||
Stock option activity was as follows: | ||||||||||||||||
Number of | Weighted | Aggregate | ||||||||||||||
Options | Average | Intrinsic | ||||||||||||||
Exercise Price | Value (In millions) | |||||||||||||||
Options outstanding at December 31, 2012 | 1,192,670 | $ | 41.86 | |||||||||||||
Granted | — | $ | — | |||||||||||||
Exercised | (458,603 | ) | $ | 40.71 | ||||||||||||
Forfeited or expired | (10,370 | ) | $ | 41.46 | ||||||||||||
Options outstanding and exercisable at December 31, 2013 | 723,697 | $ | 42.6 | $ | 18 | |||||||||||
Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, by Exercise Price Range [Table Text Block] | ' | |||||||||||||||
The number, weighted average exercise price and weighted average remaining contractual life of options outstanding were as follows: | ||||||||||||||||
Weighted Average | Weighted Average | |||||||||||||||
Number of Options | Exercise Price | Remaining Contractual Life (Years) | ||||||||||||||
Range of Exercise Prices | ||||||||||||||||
$ | 27 | — | $ | 38 | 67,257 | $ | 28.3 | 5.15 | ||||||||
$ | 38.01 | — | $ | 42 | 167,447 | $ | 41.23 | 3.21 | ||||||||
$ | 42.01 | — | $ | 45 | 351,893 | $ | 44.02 | 4.16 | ||||||||
$ | 45.01 | — | $ | 50 | 137,100 | $ | 47.67 | 3.08 | ||||||||
723,697 | $ | 42.6 | 3.83 | |||||||||||||
Schedule of Share-based Compensation, Restricted Stock Units Award Activity [Table Text Block] | ' | |||||||||||||||
Stock award activity for the years ended December 31 was: | ||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||
Fair value of awards vested (in millions) | $ | 8 | $ | 9 | $ | 13 | ||||||||||
Restricted common shares awarded | 127,785 | 167,320 | 381,840 | |||||||||||||
Weighted average market price of shares awarded | $ | 64.72 | $ | 53.71 | $ | 47.98 | ||||||||||
Compensation cost charged against income (in millions) | $ | 23 | $ | 12 | $ | 12 | ||||||||||
Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block] | ' | |||||||||||||||
The following table summarizes the Company’s stock awards activity for the period ended December 31, 2013: | ||||||||||||||||
Restricted | Weighted Average | |||||||||||||||
Stock | Grant Date | |||||||||||||||
Fair Value | ||||||||||||||||
Balance at December 31, 2012 | 597,648 | $ | 48.33 | |||||||||||||
Grants | 127,785 | $ | 64.72 | |||||||||||||
Forfeitures | (7,155 | ) | $ | 54.61 | ||||||||||||
Vested and issued | (225,949 | ) | $ | 45.54 | ||||||||||||
Balance at December 31, 2013 | 492,329 | $ | 53.76 | |||||||||||||
Share Based Compensation Expense [Table Text Block] | ' | |||||||||||||||
The Company recorded compensation expense for performance share awards as follows: | ||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||
(In millions) | ||||||||||||||||
Compensation expense | $ | 77 | $ | 71 | $ | 53 | ||||||||||
Cash settlements (a) | $ | 9 | $ | 4 | $ | 3 | ||||||||||
Stock settlements (a) | $ | 56 | $ | 41 | $ | 25 | ||||||||||
Summary of Performance Share Activity [Table Text Block] | ' | |||||||||||||||
The following table summarizes the Company’s performance share activity for the period ended December 31, 2013: | ||||||||||||||||
Performance Shares | ||||||||||||||||
Balance at December 31, 2012 | 1,634,364 | |||||||||||||||
Grants | 564,561 | |||||||||||||||
Forfeitures | (41,512 | ) | ||||||||||||||
Payouts | (548,624 | ) | ||||||||||||||
Balance at December 31, 2013 | 1,608,789 | |||||||||||||||
Schedule of Unrecognized Compensation Cost, Nonvested Awards [Table Text Block] | ' | |||||||||||||||
Unrecognized | Weighted Average | |||||||||||||||
Compensation | to be Recognized | |||||||||||||||
Cost | ||||||||||||||||
(In millions) | (In years) | |||||||||||||||
Stock awards | $ | 10 | 0.93 | |||||||||||||
Performance shares | 45 | 0.93 | ||||||||||||||
$ | 55 | 0.93 | ||||||||||||||
Segment_Information_Tables
Segment Information (Tables) | 12 Months Ended | |||||||||||||||||||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||||||||||||||||||
Segment Reporting [Abstract] | ' | |||||||||||||||||||||||||||||||||||
Inter segment billing for goods and services [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||
Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales and natural gas sales in the following segments: | ||||||||||||||||||||||||||||||||||||
2013 | 2012 | 2011 | ||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
Electric | $ | 26 | $ | 29 | $ | 33 | ||||||||||||||||||||||||||||||
Gas | 4 | 4 | 2 | |||||||||||||||||||||||||||||||||
Gas Storage and Pipelines | 3 | 6 | 8 | |||||||||||||||||||||||||||||||||
Power and Industrial Projects | 816 | 801 | 238 | |||||||||||||||||||||||||||||||||
Energy Trading | 43 | 43 | 70 | |||||||||||||||||||||||||||||||||
Corporate and Other | (24 | ) | (37 | ) | (50 | ) | ||||||||||||||||||||||||||||||
Discontinued Operations | — | 2 | — | |||||||||||||||||||||||||||||||||
$ | 868 | $ | 848 | $ | 301 | |||||||||||||||||||||||||||||||
Schedule of Segment Reporting Information, by Segment [Table Text Block] | ' | |||||||||||||||||||||||||||||||||||
Financial data of the business segments follows: | ||||||||||||||||||||||||||||||||||||
Operating | Depreciation, | Interest | Interest | Income | Net Income (Loss) | Total | Goodwill | Capital | ||||||||||||||||||||||||||||
Revenue | Depletion & | Income | Expense | Taxes | Attributable | Assets | Expenditures | |||||||||||||||||||||||||||||
Amortization | to DTE | |||||||||||||||||||||||||||||||||||
Energy | ||||||||||||||||||||||||||||||||||||
Company | ||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
2013 | ||||||||||||||||||||||||||||||||||||
Electric | $ | 5,199 | $ | 902 | $ | (1 | ) | $ | 268 | $ | 252 | $ | 484 | $ | 17,508 | $ | 1,208 | $ | 1,325 | |||||||||||||||||
Gas | 1,474 | 95 | (7 | ) | 58 | 77 | 143 | 3,938 | 743 | 209 | ||||||||||||||||||||||||||
Gas Storage and Pipelines | 132 | 23 | (7 | ) | 18 | 45 | 70 | 824 | 24 | 245 | ||||||||||||||||||||||||||
Power and Industrial Projects | 1,950 | 72 | (6 | ) | 27 | (45 | ) | 66 | 1,067 | 26 | 93 | |||||||||||||||||||||||||
Energy Trading | 1,771 | 1 | — | 8 | (38 | ) | (58 | ) | 623 | 17 | 3 | |||||||||||||||||||||||||
Corporate and Other | 3 | 1 | (51 | ) | 120 | (37 | ) | (44 | ) | 2,945 | — | 1 | ||||||||||||||||||||||||
Reclassifications and Eliminations | (868 | ) | — | 63 | (63 | ) | — | — | (970 | ) | — | — | ||||||||||||||||||||||||
Total | $ | 9,661 | $ | 1,094 | $ | (9 | ) | $ | 436 | $ | 254 | $ | 661 | $ | 25,935 | $ | 2,018 | $ | 1,876 | |||||||||||||||||
Operating | Depreciation, | Interest | Interest | Income | Net Income (Loss) | Total | Goodwill | Capital | ||||||||||||||||||||||||||||
Revenue | Depletion & | Income | Expense | Taxes | Attributable | Assets | Expenditures | |||||||||||||||||||||||||||||
Amortization | to DTE | |||||||||||||||||||||||||||||||||||
Energy | ||||||||||||||||||||||||||||||||||||
Company | ||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
2012 | ||||||||||||||||||||||||||||||||||||
Electric | $ | 5,293 | $ | 827 | $ | (1 | ) | $ | 272 | $ | 280 | $ | 483 | $ | 17,755 | $ | 1,208 | $ | 1,230 | |||||||||||||||||
Gas | 1,315 | 92 | (7 | ) | 59 | 50 | 115 | 4,059 | 745 | 221 | ||||||||||||||||||||||||||
Gas Storage and Pipelines | 96 | 8 | (8 | ) | 8 | 39 | 61 | 668 | 22 | 233 | ||||||||||||||||||||||||||
Power and Industrial Projects | 1,823 | 65 | (7 | ) | 37 | (44 | ) | 42 | 991 | 26 | 83 | |||||||||||||||||||||||||
Energy Trading | 1,109 | 2 | — | 8 | 7 | 12 | 629 | 17 | 1 | |||||||||||||||||||||||||||
Corporate and Other | 3 | 1 | (52 | ) | 121 | (46 | ) | (47 | ) | 3,074 | — | 3 | ||||||||||||||||||||||||
Reclassifications and Eliminations | (848 | ) | — | 65 | (65 | ) | — | — | (837 | ) | — | — | ||||||||||||||||||||||||
Total from Continuing Operations | $ | 8,791 | $ | 995 | $ | (10 | ) | $ | 440 | $ | 286 | $ | 666 | $ | 26,339 | $ | 2,018 | $ | 1,771 | |||||||||||||||||
Discontinued Operations (Note 7) | (56 | ) | — | — | 49 | |||||||||||||||||||||||||||||||
Total | $ | 610 | $ | 26,339 | $ | 2,018 | $ | 1,820 | ||||||||||||||||||||||||||||
Operating | Depreciation, | Interest | Interest | Income | Net Income (Loss) | Total | Goodwill | Capital | ||||||||||||||||||||||||||||
Revenue | Depletion & | Income | Expense | Taxes | Attributable | Assets | Expenditures | |||||||||||||||||||||||||||||
Amortization | to DTE | |||||||||||||||||||||||||||||||||||
Energy | ||||||||||||||||||||||||||||||||||||
Company | ||||||||||||||||||||||||||||||||||||
(In millions) | ||||||||||||||||||||||||||||||||||||
2011 | ||||||||||||||||||||||||||||||||||||
Electric | $ | 5,154 | $ | 818 | $ | (1 | ) | $ | 289 | $ | 265 | $ | 434 | $ | 17,567 | $ | 1,208 | $ | 1,203 | |||||||||||||||||
Gas | 1,505 | 89 | (7 | ) | 64 | 60 | 110 | 4,065 | 745 | 179 | ||||||||||||||||||||||||||
Gas Storage and Pipelines | 91 | 6 | (5 | ) | 7 | 35 | 57 | 538 | 22 | 16 | ||||||||||||||||||||||||||
Power and Industrial Projects | 1,129 | 60 | (8 | ) | 32 | 11 | 38 | 789 | 26 | 56 | ||||||||||||||||||||||||||
Energy Trading | 1,276 | 3 | — | 9 | 34 | 52 | 612 | 17 | 1 | |||||||||||||||||||||||||||
Corporate & Other | 4 | 1 | (47 | ) | 145 | (136 | ) | 23 | 2,605 | — | — | |||||||||||||||||||||||||
Reclassifications and Eliminations | (301 | ) | — | 58 | (58 | ) | (1 | ) | — | (485 | ) | — | — | |||||||||||||||||||||||
Total from Continuing Operations | $ | 8,858 | $ | 977 | $ | (10 | ) | $ | 488 | $ | 268 | $ | 714 | $ | 25,691 | $ | 2,018 | $ | 1,455 | |||||||||||||||||
Discontinued Operations (Note 7) | (3 | ) | 318 | 2 | 29 | |||||||||||||||||||||||||||||||
Total | $ | 711 | $ | 26,009 | $ | 2,020 | $ | 1,484 | ||||||||||||||||||||||||||||
Supplementary_Quarterly_Financ1
Supplementary Quarterly Financial Information (Unaudited ) (Tables) | 12 Months Ended | |||||||||||||||||||
Dec. 31, 2013 | ||||||||||||||||||||
Quarterly Financial Information Disclosure [Abstract] | ' | |||||||||||||||||||
Schedule of Quarterly Financial Information [Table Text Block] | ' | |||||||||||||||||||
Quarterly earnings per share may not equal full year totals, since quarterly computations are based on weighted average common shares outstanding during each quarter. | ||||||||||||||||||||
First | Second | Third | Fourth | Year | ||||||||||||||||
Quarter | Quarter | Quarter | Quarter | |||||||||||||||||
(In millions, except per share amounts) | ||||||||||||||||||||
2013 | ||||||||||||||||||||
Operating Revenues | $ | 2,516 | $ | 2,225 | $ | 2,387 | $ | 2,533 | $ | 9,661 | ||||||||||
Operating Income | $ | 410 | $ | 223 | $ | 329 | $ | 241 | $ | 1,203 | ||||||||||
Net Income Attributable to DTE Energy Company | $ | 234 | $ | 105 | $ | 198 | $ | 124 | $ | 661 | ||||||||||
Basic Earnings per Share | $ | 1.35 | $ | 0.6 | $ | 1.13 | $ | 0.7 | $ | 3.76 | ||||||||||
Diluted Earnings per Share | $ | 1.34 | $ | 0.6 | $ | 1.13 | $ | 0.7 | $ | 3.76 | ||||||||||
2012 | ||||||||||||||||||||
Operating Revenues | $ | 2,239 | $ | 2,013 | $ | 2,190 | $ | 2,349 | $ | 8,791 | ||||||||||
Operating Income | $ | 312 | $ | 294 | $ | 406 | $ | 267 | $ | 1,279 | ||||||||||
Net Income Attributable to DTE Energy Company | ||||||||||||||||||||
Continuing Operations | $ | 156 | $ | 147 | $ | 226 | $ | 137 | $ | 666 | ||||||||||
Discontinued Operations | — | (1 | ) | 1 | (56 | ) | (56 | ) | ||||||||||||
Net Income Attributable to DTE Energy Company | $ | 156 | $ | 146 | $ | 227 | $ | 81 | $ | 610 | ||||||||||
Basic Earnings per Share | ||||||||||||||||||||
Continuing Operations | $ | 0.91 | $ | 0.87 | $ | 1.31 | $ | 0.79 | $ | 3.89 | ||||||||||
Discontinued Operations | — | (0.01 | ) | 0.01 | (0.32 | ) | (0.33 | ) | ||||||||||||
Total | $ | 0.91 | $ | 0.86 | $ | 1.32 | $ | 0.47 | $ | 3.56 | ||||||||||
Diluted Earnings per Share | ||||||||||||||||||||
Continuing Operations | $ | 0.91 | $ | 0.87 | $ | 1.3 | $ | 0.79 | $ | 3.88 | ||||||||||
Discontinued Operations | — | (0.01 | ) | 0.01 | (0.32 | ) | (0.33 | ) | ||||||||||||
Total | $ | 0.91 | $ | 0.86 | $ | 1.31 | $ | 0.47 | $ | 3.55 | ||||||||||
Valuation_and_Qualifying_Accou1
Valuation and Qualifying Accounts (Tables) | 12 Months Ended | |||||||||||
Dec. 31, 2013 | ||||||||||||
Valuation and Qualifying Accounts [Abstract] | ' | |||||||||||
Summary of Valuation Allowance [Table Text Block] | ' | |||||||||||
Valuation and Qualifying Accounts | ||||||||||||
Year Ending December 31, | ||||||||||||
2013 | 2012 | 2011 | ||||||||||
(In millions) | ||||||||||||
Allowance for Doubtful Accounts (shown as deduction from Accounts Receivable in the Consolidated Statements of Financial Position) | ||||||||||||
Balance at Beginning of Period | $ | 62 | $ | 162 | $ | 196 | ||||||
Additions: | ||||||||||||
Charged to costs and expenses | 94 | 79 | 94 | |||||||||
Charged to other accounts (a) | 23 | 16 | 18 | |||||||||
Deductions (b) | (124 | ) | (195 | ) | (146 | ) | ||||||
Balance at End of Period | $ | 55 | $ | 62 | $ | 162 | ||||||
Organization_and_Basis_of_Pres2
Organization and Basis of Presentation (Details Textuals) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | Dec. 31, 2012 | Dec. 31, 2011 |
In Millions, unless otherwise specified | customers | Proceeds from sale of nuclear decommissioning trust funds [Member] | Proceeds from sale of nuclear decommissioning trust funds [Member] | Investment in Nuclear Decommissioning Trust Funds [Member] | Investment in Nuclear Decommissioning Trust Funds [Member] |
Prior Period Reclassification Adjustment | ' | $662 | $753 | ($662) | ($753) |
Number of Electric Utility Customers | 2,100,000 | ' | ' | ' | ' |
Number of Gas Utility Customers | 1,200,000 | ' | ' | ' | ' |
Significant Potential Exposure to Loss Due to VIE Long-Term Purchase Contracts | $0 | ' | ' | ' | ' |
Organization_and_Basis_of_Pres3
Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | Dec. 31, 2010 |
In Millions, unless otherwise specified | ||||
Assets [Abstract] | ' | ' | ' | ' |
Cash and cash equivalents | $52 | $65 | $68 | $65 |
Restricted cash | 123 | 122 | ' | ' |
Accounts receivable | 1,542 | 1,336 | ' | ' |
Other current assets | 209 | 215 | ' | ' |
Property, plant and equipment | 15,800 | 14,684 | ' | ' |
Securitized regulatory assets | 231 | 413 | ' | ' |
Other assets | 198 | 197 | ' | ' |
Total Assets | 25,935 | 26,339 | 26,009 | ' |
Liabilities [Abstract] | ' | ' | ' | ' |
Current portion long-term debt, including capital leases | 898 | 817 | ' | ' |
Current regulatory liabilities | 302 | 89 | ' | ' |
Other current liabilities | 495 | 449 | ' | ' |
Mortgage bonds, notes and other | 6,618 | 6,220 | ' | ' |
Securitization bonds | 105 | 302 | ' | ' |
Capital lease obligations | 11 | 12 | ' | ' |
Other long term liabilities | 297 | 306 | ' | ' |
Variable Interest Entity Securitization [Member] | ' | ' | ' | ' |
Assets [Abstract] | ' | ' | ' | ' |
Cash and cash equivalents | 0 | 0 | ' | ' |
Restricted cash | 100 | 102 | ' | ' |
Accounts receivable | 34 | 34 | ' | ' |
Inventories | 0 | 0 | ' | ' |
Other current assets | 0 | 0 | ' | ' |
Property, plant and equipment | 0 | 0 | ' | ' |
Securitized regulatory assets | 231 | 413 | ' | ' |
Other assets | 4 | 7 | ' | ' |
Total Assets | 369 | 556 | ' | ' |
Liabilities [Abstract] | ' | ' | ' | ' |
Accounts payable and accrued current liabilities | 7 | 11 | ' | ' |
Current portion long-term debt, including capital leases | 196 | 177 | ' | ' |
Current regulatory liabilities | 43 | 50 | ' | ' |
Other current liabilities | 0 | 0 | ' | ' |
Mortgage bonds, notes and other | 0 | 0 | ' | ' |
Securitization bonds | 105 | 302 | ' | ' |
Capital lease obligations | 0 | 0 | ' | ' |
Other long term liabilities | 8 | 7 | ' | ' |
Total Liabilities | 359 | 547 | ' | ' |
Variable Interest Entity, Primary Beneficiary [Member] | ' | ' | ' | ' |
Assets [Abstract] | ' | ' | ' | ' |
Cash and cash equivalents | 12 | 10 | ' | ' |
Restricted cash | 8 | 7 | ' | ' |
Accounts receivable | 16 | 7 | ' | ' |
Inventories | 118 | 141 | ' | ' |
Other current assets | 1 | 1 | ' | ' |
Property, plant and equipment | 99 | 93 | ' | ' |
Securitized regulatory assets | 0 | 0 | ' | ' |
Other assets | 8 | 11 | ' | ' |
Total Assets | 262 | 270 | ' | ' |
Liabilities [Abstract] | ' | ' | ' | ' |
Accounts payable and accrued current liabilities | 23 | 14 | ' | ' |
Current portion long-term debt, including capital leases | 9 | 8 | ' | ' |
Current regulatory liabilities | 0 | 0 | ' | ' |
Other current liabilities | 4 | 4 | ' | ' |
Mortgage bonds, notes and other | 21 | 25 | ' | ' |
Securitization bonds | 0 | 0 | ' | ' |
Capital lease obligations | 7 | 11 | ' | ' |
Other long term liabilities | 2 | 2 | ' | ' |
Total Liabilities | 66 | 64 | ' | ' |
Consolidated Variable Interest Entity [Member] | ' | ' | ' | ' |
Assets [Abstract] | ' | ' | ' | ' |
Cash and cash equivalents | 12 | 10 | ' | ' |
Restricted cash | 108 | 109 | ' | ' |
Accounts receivable | 50 | 41 | ' | ' |
Inventories | 118 | 141 | ' | ' |
Other current assets | 1 | 1 | ' | ' |
Property, plant and equipment | 99 | 93 | ' | ' |
Securitized regulatory assets | 231 | 413 | ' | ' |
Other assets | 12 | 18 | ' | ' |
Total Assets | 631 | 826 | ' | ' |
Liabilities [Abstract] | ' | ' | ' | ' |
Accounts payable and accrued current liabilities | 30 | 25 | ' | ' |
Current portion long-term debt, including capital leases | 205 | 185 | ' | ' |
Current regulatory liabilities | 43 | 50 | ' | ' |
Other current liabilities | 4 | 4 | ' | ' |
Mortgage bonds, notes and other | 21 | 25 | ' | ' |
Securitization bonds | 105 | 302 | ' | ' |
Capital lease obligations | 7 | 11 | ' | ' |
Other long term liabilities | 10 | 9 | ' | ' |
Total Liabilities | $425 | $611 | ' | ' |
Organization_and_Basis_of_Pres4
Organization and Basis of Presentation (Non Consolidated Variable Interest Entities) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net [Abstract] | ' | ' |
Notes receivable | $102 | $112 |
Variable Interest Entity, NonConsolidated [Member] | ' | ' |
Variable Interest Entity, Nonconsolidated, Carrying Amount, Assets and Liabilities, Net [Abstract] | ' | ' |
Other investments | 141 | 130 |
Notes receivable | $8 | $6 |
Significant_Accounting_Policie3
Significant Accounting Policies (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Accumulated Other Comprehensive Income (Loss) [Line Items] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | ($158) | ' | ' |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 13 | ' | ' |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 9 | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | 22 | 0 | -9 |
Accumulated Other Comprehensive Income (Loss), Net of Tax | -136 | -158 | ' |
Accumulated Net Gain (Loss) from Designated or Qualifying Cash Flow Hedges [Member] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss) [Line Items] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | -4 | ' | ' |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 0 | ' | ' |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | 0 | ' | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | -4 | ' | ' |
Accumulated Net Unrealized Investment Gain (Loss) [Member] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss) [Line Items] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | -8 | ' | ' |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 2 | ' | ' |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | 2 | 1 | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | -6 | -8 | ' |
Accumulated Defined Benefit Plans Adjustment [Member] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss) [Line Items] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | -148 | ' | ' |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | 13 | ' | ' |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 9 | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | 22 | -2 | -9 |
Accumulated Other Comprehensive Income (Loss), Net of Tax | -126 | -148 | ' |
Accumulated Translation Adjustment [Member] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss) [Line Items] | ' | ' | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | 2 | ' | ' |
Other Comprehensive Income (Loss), before Reclassifications, Net of Tax | -2 | ' | ' |
Reclassification from Accumulated Other Comprehensive Income, Current Period, Net of Tax | 0 | ' | ' |
Other Comprehensive Income (Loss), Net of Tax | -2 | 1 | ' |
Accumulated Other Comprehensive Income (Loss), Net of Tax | $0 | $2 | ' |
Significant_Accounting_Policie4
Significant Accounting Policies (Intangible Assets) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Finite-Lived Intangible Assets [Line Items] | ' | ' |
Intangible Assets, Gross | $179 | $189 |
Less: Accumulated Amortization | 45 | 34 |
Intangible Assets, Net | 134 | 155 |
Less current intangible assets | 12 | 20 |
Finite-Lived Intangible Assets, Net | 122 | 135 |
Emission Allowances [Member] | ' | ' |
Finite-Lived Intangible Assets [Line Items] | ' | ' |
Intangible Assets, Gross | 2 | 6 |
Renewable Energy Credits [Member] | ' | ' |
Finite-Lived Intangible Assets [Line Items] | ' | ' |
Intangible Assets, Gross | 51 | 44 |
Contract Intangible Assets [Member] | ' | ' |
Finite-Lived Intangible Assets [Line Items] | ' | ' |
Intangible Assets, Gross | $126 | $139 |
Significant_Accounting_Policie5
Significant Accounting Policies (Future Amortization Expense Intangible Assets) (Details) (USD $) | Dec. 31, 2013 |
In Millions, unless otherwise specified | |
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract] | ' |
Finite-Lived Intangible Assets, Amortization Expense, Next Twelve Months | $13 |
Finite-Lived Intangible Assets, Amortization Expense, Year Two | 12 |
Finite-Lived Intangible Assets, Amortization Expense, Year Three | 11 |
Finite-Lived Intangible Assets, Amortization Expense, Year Four | 8 |
Finite-Lived Intangible Assets, Amortization Expense, Year Five | $8 |
Significant_Accounting_Policie6
Significant Accounting Policies (Details Textuals) (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Significant Accounting Policies [Line Items] | ' | ' | ' |
Other Nonoperating Income | $201,000,000 | $173,000,000 | $117,000,000 |
Receivables Due Date | '21 days | ' | ' |
Threshold Period Past Due for Write-off of Trade Accounts Receivable | '150 days | ' | ' |
Specific Review of Probable Future Collections Based on Receivable Balances in Excess of Pre Specified Days | '30 days | ' | ' |
Unbilled Revenues included in Customer Accounts Receivable | 1,542,000,000 | 1,336,000,000 | ' |
Accrued Expense Related to Fermi 2 Refueling Outages | 26,000,000 | 12,000,000 | ' |
Period Expenses Related To Fermi 2 Refueling Outages Are Accrued | '18 months | ' | ' |
Amortization of Intangible Assets | 14,000,000 | 6,000,000 | 5,000,000 |
Excise Sales Tax Net Impact on Statement of Operations | 0 | ' | ' |
Charitable Contributions to a Foundation | 18,000,000 | 21,000,000 | 21,000,000 |
Minimum [Member] | ' | ' | ' |
Significant Accounting Policies [Line Items] | ' | ' | ' |
Notes Receivable Considered Delinquent Period | '60 days | ' | ' |
Finite Lived Asset Useful Life | '1 year | ' | ' |
Maximum [Member] | ' | ' | ' |
Significant Accounting Policies [Line Items] | ' | ' | ' |
Notes Receivable Considered Delinquent Period | '120 days | ' | ' |
Finite Lived Asset Useful Life | '28 years | ' | ' |
Unbilled Revenues [Member] | ' | ' | ' |
Significant Accounting Policies [Line Items] | ' | ' | ' |
Unbilled Revenues included in Customer Accounts Receivable | 815,000,000 | 686,000,000 | ' |
Public Utilities, Inventory, Natural Gas [Member] | ' | ' | ' |
Significant Accounting Policies [Line Items] | ' | ' | ' |
LIFO Inventory Amount | 4,000,000 | 37,000,000 | ' |
Excess of Replacement Costs over Stated LIFO Value | 170,000,000 | 113,000,000 | ' |
Power and Industrial Projects [Member] | ' | ' | ' |
Significant Accounting Policies [Line Items] | ' | ' | ' |
Other Nonoperating Income | $81,000,000 | $63,000,000 | $15,000,000 |
Fair_Value_Assets_and_Liabilit
Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities, Current | ($195) | ($125) |
Derivative Liabilities, Noncurrent | -43 | -26 |
Fair Value, Measurements, Recurring [Member] | ' | ' |
Assets [Abstract] | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 125 | 123 |
Nuclear decommissioning trusts | 1,191 | 1,037 |
Other investments | 136 | 110 |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 126 | 147 |
Assets, Fair Value Disclosure | 1,578 | 1,417 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -238 | -151 |
Derivative Liabilities, Current | -195 | -125 |
Derivative Liabilities, Noncurrent | -43 | -26 |
Fair Value, Net Asset (Liability) | 1,340 | 1,266 |
Fair Value, Measurements, Recurring [Member] | Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 224 | 231 |
Fair Value, Measurements, Recurring [Member] | Non Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 1,354 | 1,186 |
Fair Value, Measurements, Recurring [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 14 | 40 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -108 | -56 |
Fair Value, Measurements, Recurring [Member] | Electricity Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 109 | 102 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -129 | -93 |
Fair Value, Measurements, Recurring [Member] | Other Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 3 | 5 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 0 | -1 |
Fair Value, Measurements, Recurring [Member] | Other Contract [Member] | ' | ' |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -1 | -1 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' |
Assets [Abstract] | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 10 | 0 |
Nuclear decommissioning trusts | 779 | 694 |
Other investments | 92 | 66 |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 306 | 561 |
Assets, Fair Value Disclosure | 1,187 | 1,321 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -309 | -532 |
Derivative Liabilities, Current | -268 | -466 |
Derivative Liabilities, Noncurrent | -41 | -66 |
Fair Value, Net Asset (Liability) | 878 | 789 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 277 | 493 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Non Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 910 | 828 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 273 | 555 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -277 | -526 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Electricity Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 0 | 0 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 0 | 0 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Other Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 33 | 6 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -32 | -6 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Other Contract [Member] | ' | ' |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 0 | 0 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' |
Assets [Abstract] | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 115 | 123 |
Nuclear decommissioning trusts | 412 | 343 |
Other investments | 44 | 44 |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 351 | 295 |
Assets, Fair Value Disclosure | 922 | 805 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -415 | -315 |
Derivative Liabilities, Current | -328 | -269 |
Derivative Liabilities, Noncurrent | -87 | -46 |
Fair Value, Net Asset (Liability) | 507 | 490 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 400 | 372 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Non Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 522 | 433 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 89 | 66 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -140 | -73 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Electricity Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 261 | 226 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -272 | -240 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Other Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 1 | 3 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -2 | -1 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Other Contract [Member] | ' | ' |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -1 | -1 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' |
Assets [Abstract] | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 0 | 0 |
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 176 | 160 |
Assets, Fair Value Disclosure | 176 | 160 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -212 | -173 |
Derivative Liabilities, Current | -177 | -144 |
Derivative Liabilities, Noncurrent | -35 | -29 |
Fair Value, Net Asset (Liability) | -36 | -13 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 139 | 120 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Non Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | 37 | 40 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 34 | 24 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -86 | -62 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 139 | 134 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | -126 | -111 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Other Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | 3 | 2 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 0 | 0 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Other Contract [Member] | ' | ' |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 0 | 0 |
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | ' | ' |
Assets [Abstract] | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 0 | 0 |
Nuclear decommissioning trusts | 0 | 0 |
Other investments | 0 | 0 |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | -707 | -869 |
Assets, Fair Value Disclosure | -707 | -869 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 698 | 869 |
Derivative Liabilities, Current | 578 | 754 |
Derivative Liabilities, Noncurrent | 120 | 115 |
Fair Value, Net Asset (Liability) | 9 | 0 |
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | -592 | -754 |
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Non Current Asset [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Assets, Fair Value Disclosure | -115 | -115 |
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | -382 | -605 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 395 | 605 |
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Electricity Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | -291 | -258 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 269 | 258 |
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Other Commodity Contract [Member] | ' | ' |
Derivative assets [Abstract] | ' | ' |
Derivative Assets | -34 | -6 |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | 34 | 6 |
Fair Value, Measurements, Recurring [Member] | Netting Adjustments [Member] | Other Contract [Member] | ' | ' |
Derivative liabilities [Abstract] | ' | ' |
Derivative Liabilities | $0 | $0 |
Fair_Value_Reconciliation_of_L
Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ' | ' |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | ($13) | $44 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3 | 1 | 1 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings | 43 | 60 |
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities | 5 | 15 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases | -7 | 2 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues | -1 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements | -64 | -135 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | -36 | -13 |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | -1 | 58 |
Natural Gas Commodity Contract [Member] | ' | ' |
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ' | ' |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | -38 | 6 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3 | 1 | 1 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings | -32 | -41 |
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities | 0 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases | -8 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues | 0 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements | 25 | -4 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | -52 | -38 |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | -49 | -33 |
Electricity Commodity Contract [Member] | ' | ' |
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ' | ' |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | 23 | 32 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3 | 0 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings | 75 | 101 |
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities | 0 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases | 1 | 2 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues | -1 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements | -85 | -112 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | 13 | 23 |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | 48 | 91 |
Other Commodity Contract [Member] | ' | ' |
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items] | ' | ' |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | 2 | 6 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Transfers into Level 3 | 0 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Gain (Loss) Included in Earnings | 0 | 0 |
Fair Value Net Derivative Asset (Liability) Measured on Recurring Basis Unobservable Inputs Reconciliation Gains and Losses Recorded In Regulatory Assets Liabilities | 5 | 15 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Purchases | 0 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Issues | 0 | 0 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Inputs Reconciliation, Settlements | -4 | -19 |
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs | 3 | 2 |
Fair Value, Assets Measured on Recurring Basis, Change in Unrealized Gain (Loss) | $0 | $0 |
Fair_Value_Transfers_between_L
Fair Value (Transfers between Levels of the Fair Value Hierarchy) (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Fair Value Transfers Between Level 1, Level 2 and Level 3 [Line Items] | ' | ' |
Fair Value Transfer from Level 1 to Level 2, Amount | $0 | $0 |
Fair Value Transfer from Level 1 to Level 3, Amount | 0 | 0 |
Fair Value Transfer from Level 2 to Level 1, Amount | 0 | 0 |
Fair Value Transfer from Level 2 to Level 3, Amount | 1 | 1 |
Fair Value Transfer from Level 3 to Level 1, Amount | 0 | 0 |
Fair Value Transfer from Level 3 to Level 2, Amount | $0 | $0 |
Fair_Value_Unobservable_Inputs
Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | MMBTU | MMBTU |
Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Weighted Average Forward Basis Price | -0.16 | 0.03 |
Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Weighted Average Forward Basis Price | 3 | 3 |
Fair Value, Measurements, Recurring [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Assets | 126 | 147 |
Derivative Liabilities | -238 | -151 |
Fair Value, Measurements, Recurring [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Assets | 14 | 40 |
Derivative Liabilities | -108 | -56 |
Fair Value, Measurements, Recurring [Member] | Electricity Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Assets | 109 | 102 |
Derivative Liabilities | -129 | -93 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Assets | 176 | 160 |
Derivative Liabilities | -212 | -173 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Assets | 34 | 24 |
Derivative Liabilities | -86 | -62 |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Derivative Assets | 139 | 134 |
Derivative Liabilities | -126 | -111 |
Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Weighted Average Range for Unobservable Inputs | -0.88 | -0.63 |
Minimum [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Weighted Average Range for Unobservable Inputs | -7 | -2 |
Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Weighted Average Range for Unobservable Inputs | 5.07 | 1.95 |
Maximum [Member] | Fair Value, Inputs, Level 3 [Member] | Electricity Commodity Contract [Member] | ' | ' |
Unobservable Inputs Valuation Techniques [Line Items] | ' | ' |
Weighted Average Range for Unobservable Inputs | 15 | 16 |
Fair_Value_Fair_Value_of_Finan
Fair Value (Fair Value of Financial Instruments) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Fair Value of Financial Instruments [Line Items] | ' | ' |
Notes Receivable Excudling Capital Leases | $41 | $39 |
Dividends Payable, Current | 116 | 107 |
Short-term Debt | 131 | 240 |
Long-term Debt | 8,094 | 7,813 |
Fair Value, Inputs, Level 1 [Member] | ' | ' |
Fair Value of Financial Instruments [Line Items] | ' | ' |
Notes Receivable, Fair Value Disclosure | 0 | 0 |
Dividends Payable Fair Value Disclosure | 116 | 107 |
Short-term Debt, Fair Value Disclosure | 0 | 0 |
Long-term Debt, Fair Value | 425 | 507 |
Fair Value, Inputs, Level 2 [Member] | ' | ' |
Fair Value of Financial Instruments [Line Items] | ' | ' |
Notes Receivable, Fair Value Disclosure | 0 | 0 |
Dividends Payable Fair Value Disclosure | 0 | 0 |
Short-term Debt, Fair Value Disclosure | 131 | 240 |
Long-term Debt, Fair Value | 7,551 | 7,453 |
Fair Value, Inputs, Level 3 [Member] | ' | ' |
Fair Value of Financial Instruments [Line Items] | ' | ' |
Notes Receivable, Fair Value Disclosure | 41 | 39 |
Dividends Payable Fair Value Disclosure | 0 | 0 |
Short-term Debt, Fair Value Disclosure | 0 | 0 |
Long-term Debt, Fair Value | $499 | $933 |
Fair_Value_Fair_Value_of_Nucle
Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ' |
Decommissioning Fund Investments | $1,191 | $1,037 |
Fermi 2 [Member] | ' | ' |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ' |
Decommissioning Fund Investments | 1,172 | 1,021 |
Fermi 1 [Member] | ' | ' |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ' |
Decommissioning Fund Investments | 3 | 3 |
Low level radioactive waste [Member] | ' | ' |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ' |
Decommissioning Fund Investments | 16 | 13 |
Nuclear Decommissioning Trust Fund [Member] | ' | ' |
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items] | ' | ' |
Decommissioning Fund Investments | $1,191 | $1,037 |
Fair_Value_Gains_and_Losses_an
Fair Value (Gains and Losses and Proceeds from the Sale of Securities by the Nuclear Decommissioning Trust Funds) (Details) (Nuclear Decommissioning Trust Fund [Member], USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Nuclear Decommissioning Trust Fund [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Realized gains | $83 | $37 | $46 |
Realized losses | -41 | -31 | -38 |
Proceeds from sales of securities | $1,118 | $759 | $833 |
Fair_Value_Fair_Value_and_Unre
Fair Value (Fair Value and Unrealized Gains for the Nuclear Decommissioning Trust Funds) (Details) (Nuclear Decommissioning Trust Fund [Member], USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' |
Nuclear decommissioning trusts | $1,191 | $1,037 |
Unrealized Gains | 213 | 149 |
Equity Securities [Member] | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' |
Equity securities | 730 | 631 |
Unrealized Gains | 201 | 122 |
Debt Securities [Member] | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' |
Debt securities | 442 | 399 |
Unrealized Gains | 12 | 27 |
Cash and Cash Equivalents [Member] | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 19 | 7 |
Unrealized Gains | $0 | $0 |
Fair_Value_Details_Textuals
Fair Value (Details Textuals) (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Other Comprehensive Income (Loss), Unrealized Holding Gain (Loss) on Securities Arising During Period, before Tax | $0 | $0 | ' |
Trading Securities, Change in Unrealized Holding Gain (Loss) | 22,000,000 | 11,000,000 | 4,000,000 |
Equity Securities [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Nuclear Decommissioning Trust Fund Investments | 61.00% | 61.00% | ' |
Debt Securities [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Nuclear Decommissioning Trust Fund Investments | 37.00% | 38.00% | ' |
Cash and Cash Equivalents [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Nuclear Decommissioning Trust Fund Investments | 2.00% | 1.00% | ' |
Fair Value, Measurements, Recurring [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 125,000,000 | 123,000,000 | ' |
Other investments | 136,000,000 | 110,000,000 | ' |
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 115,000,000 | 123,000,000 | ' |
Other investments | 44,000,000 | 44,000,000 | ' |
Other Investments [Member] | Fair Value, Measurements, Recurring [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 16,000,000 | ' | ' |
Other Investments [Member] | Fair Value, Measurements, Recurring [Member] | Equity [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Available-for-sale Securities, Fair Value Disclosure | 7,000,000 | 5,000,000 | ' |
Other investments | 136,000,000 | 110,000,000 | ' |
Other Investments [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | ' | 14,000,000 | ' |
Restricted Assets [Member] | Fair Value, Measurements, Recurring [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 109,000,000 | ' | ' |
Restricted Assets [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | ' | 109,000,000 | ' |
Nuclear Decommissioning Trust Fund [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Average Maturity of Debt Securities | '7 years | '6 years | ' |
Nuclear Decommissioning Trust Fund [Member] | Cash and Cash Equivalents [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Cash and Cash Equivalents, Fair Value Disclosure | 19,000,000 | 7,000,000 | ' |
Fermi 2 [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Unrealized losses recognized as regulatory assets | 31,000,000 | 44,000,000 | ' |
Fermi 1 [Member] | ' | ' | ' |
Fair Value, Option, Quantitative Disclosures [Line Items] | ' | ' | ' |
Other than Temporary Impairment Losses, Investments, Portion Recognized in Earnings, Net | $0 | $0 | $0 |
Financial_and_Other_Derivative2
Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Fair Value, Gross Asset | $833 | $1,016 |
Derivative Liability, Fair Value, Gross Liability | -936 | -1,020 |
Derivative Asset, Current | 99 | 108 |
Derivative Assets, Noncurrent | 27 | 39 |
Derivative Liabilities, Current | -195 | -125 |
Derivative Liabilities, Noncurrent | -43 | -26 |
Estimate of Fair Value, Fair Value Disclosure [Member] | ' | ' |
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Current | 691 | 862 |
Derivative Assets, Noncurrent | 142 | 154 |
Derivative Liabilities, Current | -773 | -879 |
Derivative Liabilities, Noncurrent | -163 | -141 |
Designated as Hedging Instrument [Member] | Interest rate contracts [Member] | ' | ' |
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 0 | 0 |
Derivative Liability, Fair Value, Gross Liability | 0 | -1 |
Not Designated as Hedging Instrument [Member] | ' | ' |
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 833 | 1,016 |
Derivative Liability, Fair Value, Gross Liability | -936 | -1,019 |
Not Designated as Hedging Instrument [Member] | Foreign currency exchange contracts [Member] | ' | ' |
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 0 | 0 |
Derivative Liability, Fair Value, Gross Liability | -1 | 0 |
Not Designated as Hedging Instrument [Member] | Natural Gas [Member] | ' | ' |
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 396 | 645 |
Derivative Liability, Fair Value, Gross Liability | -503 | -661 |
Not Designated as Hedging Instrument [Member] | Electricity [Member] | ' | ' |
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 400 | 360 |
Derivative Liability, Fair Value, Gross Liability | -398 | -351 |
Not Designated as Hedging Instrument [Member] | Other [Member] | ' | ' |
Derivatives designated as hedging instruments: | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 37 | 11 |
Derivative Liability, Fair Value, Gross Liability | ($34) | ($7) |
Financial_and_Other_Derivative3
Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilites) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Netting Offsets of Derivative Assets and Liabilities [Line Items] | ' | ' |
Derivative Asset, Fair Value, Gross Asset | $833 | $1,016 |
Derivative Asset, Fair Value, Gross Liability | -707 | -869 |
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | 126 | 147 |
Derivative Liability, Fair Value, Gross Liability | -936 | -1,020 |
Derivative Liability, Fair Value, Gross Asset | 698 | 869 |
Derivative Liability, Fair Value, Amount Not Offset Against Collateral | -238 | -151 |
Natural Gas Commodity Contract [Member] | ' | ' |
Netting Offsets of Derivative Assets and Liabilities [Line Items] | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 396 | 645 |
Derivative Asset, Fair Value, Gross Liability | -382 | -605 |
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | 14 | 40 |
Derivative Liability, Fair Value, Gross Liability | -503 | -661 |
Derivative Liability, Fair Value, Gross Asset | 395 | 605 |
Derivative Liability, Fair Value, Amount Not Offset Against Collateral | -108 | -56 |
Electricity Commodity Contract [Member] | ' | ' |
Netting Offsets of Derivative Assets and Liabilities [Line Items] | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 400 | 360 |
Derivative Asset, Fair Value, Gross Liability | -291 | -258 |
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | 109 | 102 |
Derivative Liability, Fair Value, Gross Liability | -398 | -351 |
Derivative Liability, Fair Value, Gross Asset | 269 | 258 |
Derivative Liability, Fair Value, Amount Not Offset Against Collateral | -129 | -93 |
Other Commodity Contract [Member] | ' | ' |
Netting Offsets of Derivative Assets and Liabilities [Line Items] | ' | ' |
Derivative Liability, Fair Value, Gross Liability | -34 | -7 |
Derivative Liability, Fair Value, Gross Asset | 34 | 6 |
Derivative Liability, Fair Value, Amount Not Offset Against Collateral | 0 | -1 |
Other Contract [Member] | ' | ' |
Netting Offsets of Derivative Assets and Liabilities [Line Items] | ' | ' |
Derivative Asset, Fair Value, Gross Asset | 37 | 11 |
Derivative Asset, Fair Value, Gross Liability | -34 | -6 |
Derivative Asset, Fair Value, Amount Not Offset Against Collateral | 3 | 5 |
Derivative Liability, Fair Value, Gross Liability | -1 | -1 |
Derivative Liability, Fair Value, Gross Asset | 0 | 0 |
Derivative Liability, Fair Value, Amount Not Offset Against Collateral | ($1) | ($1) |
Financial_and_Other_Derivative4
Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Derivative [Line Items] | ' | ' |
Derivative Asset, Current | $99 | $108 |
Derivative Assets, Noncurrent | 27 | 39 |
Derivative Liabilities, Current | -195 | -125 |
Derivative Liabilities, Noncurrent | -43 | -26 |
Derivative Asset [Member] | ' | ' |
Derivative [Line Items] | ' | ' |
Derivative Asset, Current | 691 | 862 |
Derivative Assets, Noncurrent | 142 | 154 |
Derivative Liabilities [Member] | ' | ' |
Derivative [Line Items] | ' | ' |
Derivative Liabilities, Current | -773 | -879 |
Derivative Liabilities, Noncurrent | -163 | -141 |
Counterparty Netting [Member] | ' | ' |
Derivative [Line Items] | ' | ' |
Derivative Asset, Current | -566 | -754 |
Derivative Assets, Noncurrent | -115 | -115 |
Derivative Liabilities, Current | 566 | 754 |
Derivative Liabilities, Noncurrent | 115 | 115 |
Collateral Adjustment [Member] | ' | ' |
Derivative [Line Items] | ' | ' |
Derivative Asset, Current | -26 | 0 |
Derivative Assets, Noncurrent | 0 | 0 |
Derivative Liabilities, Current | 12 | 0 |
Derivative Liabilities, Noncurrent | $5 | $0 |
Financial_and_Other_Derivative5
Financial and Other Derivative Instruments (Effect of Derivatives not Deisgnated as Hedging Instruments on the Consolidated Statement of Operations) (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' |
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | ($11) | $65 |
Foreign currency exchange contracts [Member] | Operating Revenue [Member] | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' |
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | -1 | 0 |
Natural Gas [Member] | Operating Revenue [Member] | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' |
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | -48 | -29 |
Natural Gas [Member] | Fuel, purchased power and gas [Member] | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' |
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | -44 | 25 |
Electricity [Member] | Operating Revenue [Member] | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' |
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | 82 | 64 |
Other [Member] | Operating Revenue [Member] | ' | ' |
Derivative Instruments, Gain (Loss) [Line Items] | ' | ' |
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net | $0 | $5 |
Financial_and_Other_Derivative6
Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details) | Dec. 31, 2013 |
dte.volumes | |
Natural Gas [Member] | ' |
Derivative [Line Items] | ' |
Volume of Commodity Contracts | 795,553,773 |
Electricity [Member] | ' |
Derivative [Line Items] | ' |
Volume of Commodity Contracts | 55,658,483 |
Foreign currency exchange contracts [Member] | ' |
Derivative [Line Items] | ' |
Volume of Commodity Contracts | 65,074,206 |
FTR [Member] | ' |
Derivative [Line Items] | ' |
Volume of Commodity Contracts | 10,485,618 |
Financial_and_Other_Derivative7
Financial and Other Derivative Instruments (Details Textuals) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Derivative [Line Items] | ' | ' |
Interest Rate Cash Flow Hedge Gain (Loss) to be Reclassified During Next 12 Months, Net | $1 | ' |
Letters of Credit Outstanding, Amount | 19 | 63 |
Cash Collateral Posted Net of Cash Collateral Received | 12 | ' |
Cash Collateral Paid or Received for Derivative Assets | 26 | 0 |
Cash Collateral Paid or Received for Derivative Liabilities | 17 | ' |
Cash Collateral Paid | 34 | 4 |
Cash Collateral Received | 13 | 24 |
Value of Transactions Company Would Have Been Exposed to if Credit Rating Below Investment Grade | 406 | ' |
Derivative, Net Liability Position, Aggregate Fair Value | 1,176 | ' |
Collateral Already Posted, Aggregate Fair Value | 902 | 20 |
Additional Collateral, Aggregate Fair Value | 249 | ' |
FTR [Member] | ' | ' |
Derivative [Line Items] | ' | ' |
Derivative Instruments Recoverable Through PSCR Mechanism | 5 | 15 |
Credit Risk Contract [Member] | ' | ' |
Derivative [Line Items] | ' | ' |
Collateral Already Posted, Aggregate Fair Value | $25 | ' |
Goodwill_Carrying_Amount_of_Go
Goodwill (Carrying Amount of Goodwill) (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Goodwill [Line Items] | ' | ' |
Beginning Balance | $2,018 | $2,020 |
Goodwill Period Increase (Decrease) | 0 | -2 |
Ending Balance | $2,018 | $2,018 |
Acquisition_Details_Textuals
Acquisition (Details Textuals) (USD $) | 3 Months Ended | |
Mar. 31, 2013 | Dec. 31, 2012 | |
facilities | ||
Business Acquisition, Equity Interests Issued or Issuable [Line Items] | ' | ' |
Number of Businesses Acquired | ' | 14 |
Business Combination, Consideration Transferred | ' | $294,000,000 |
Business Combination, Payments to Acquire Businesses, Gross | ' | 220,000,000 |
Business Acquisition, Consideration Transferred, Other | ' | 74,000,000 |
Number of Project Companies Acquired Deemed VIEs that assumed Debt Relates | ' | 2 |
Exposure Loss Related to the Debt Assumed | ' | 0 |
Business Combination, Intangible assets | ' | 75,000,000 |
Amortization Years for Intangible Assets Acquired in a Business Combination | ' | '8 years |
Revenues of Acquired Business Included in the Company's Consolidated Statement of Operations | ' | 30,000,000 |
Earnings of Acquired Business Included in the Company's Consolidated Statements of Operations | ' | $2,000,000 |
The Period of the Acquired Project Companies Following the Closing included in Results of Operations | '3 months | ' |
Minimum [Member] | ' | ' |
Business Acquisition, Equity Interests Issued or Issuable [Line Items] | ' | ' |
Equity Method Investment, Ownership Percentage | ' | 46.00% |
Maximum [Member] | ' | ' |
Business Acquisition, Equity Interests Issued or Issuable [Line Items] | ' | ' |
Equity Method Investment, Ownership Percentage | ' | 100.00% |
Acquisition_Details
Acquisition (Details) (USD $) | Dec. 31, 2012 |
In Millions, unless otherwise specified | |
Allocation of the Purchase Price to Assets and Liabilities [Line Items] | ' |
Business Combination, Cash | $22 |
Business Combination, Accounts receivables | 14 |
Business Combination, Other Current assets | 8 |
Business Combination, Property, Plant and Equipment | 100 |
Business Combination, Intangible assets | 75 |
Business Combination, Other Noncurrent Assets | 9 |
Business Combination, Current Liabilities | -7 |
Business Combination, Non-controlling Interest | -1 |
Business Combination, Purchase Price | $220 |
Discontinued_Operations_Detail
Discontinued Operations (Details Textuals) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ' | ' | ' |
Proceeds from Divestiture of Businesses | $0 | $255 | $0 |
Discontinued Operations [Member] | ' | ' | ' |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ' | ' | ' |
Disposal of Equity Interest In Segment Percentage | ' | 100.00% | ' |
Proceeds from Divestiture of Businesses | ' | 255 | ' |
Discontinued Operation, Loss from Disposal of Discontinued Operation, before Income Tax | ' | 83 | ' |
Discontinued Operation, Loss on Disposal of Discontinued Operation, Net of Tax | ' | 55 | ' |
Allocation of Corporate Interest Costs | $0 | ' | ' |
Discontinued_Operations_Detail1
Discontinued Operations (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||
In Millions, unless otherwise specified | Dec. 31, 2012 | Sep. 30, 2012 | Jun. 30, 2012 | Mar. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ' | ' | ' | ' | ' | ' | ' |
Total operating expenses | ' | ' | ' | ' | $8,458 | $7,512 | $7,437 |
Disposal Group, Income tax expense (benefit) | ' | ' | ' | ' | 0 | 29 | 1 |
Discontinued Operations Income (Loss), net of tax | -56 | 1 | -1 | 0 | 0 | -56 | -3 |
Segment, Discontinued Operations [Member] | ' | ' | ' | ' | ' | ' | ' |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ' | ' | ' | ' | ' | ' | ' |
Disposal Group, Operating Revenues | ' | ' | ' | ' | ' | 55 | 39 |
Disposal Group, Operation and maintenance | ' | ' | ' | ' | ' | 24 | 16 |
Disposal Group, Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | 23 | 18 |
Disposal Group, Taxes Other than Income | ' | ' | ' | ' | ' | 4 | 3 |
Disposal Group, Assets (Gains) and Losses, Net | ' | ' | ' | ' | ' | 83 | 0 |
Total operating expenses | ' | ' | ' | ' | ' | 134 | 37 |
Disposal Group, Operating Income (Loss) | ' | ' | ' | ' | ' | -79 | 2 |
Disposal Group, Other (income) and deductions | ' | ' | ' | ' | ' | 6 | 6 |
Disposal Group, Income (Loss) from Discontinued Operation, before Income Tax | ' | ' | ' | ' | ' | -85 | -4 |
Disposal Group, Income tax expense (benefit) | ' | ' | ' | ' | ' | -29 | -1 |
Discontinued Operations Income (Loss), net of tax | ' | ' | ' | ' | ' | ($56) | ($3) |
Property_Plant_and_Equipment_S
Property, Plant and Equipment (Summary of Property by Classification) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Property, Plant and Equipment [Line Items] | ' | ' |
Property, Plant and Equipment - Non-utility and other | $2,292 | $1,960 |
Property, plant and equipment, Total | 25,123 | 23,631 |
Less Accumulated Depreciation, Depletion and Amortization - Nonutility and Other | -767 | -676 |
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment | -9,323 | -8,947 |
Property, plant and equipment | 15,800 | 14,684 |
Electric Generation Equipment [Member] | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' |
Property Plant and Equipment - Generation | 11,127 | 10,383 |
Less Accumulated Depreciation, Depletion and Amortization - Generation | -4,004 | -3,880 |
Electric Distribution [Member] | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' |
Property Plant and Equipment - Distribution | 7,603 | 7,306 |
Less Accumulated Depreciation, Depletion and Amortization - Distribution | -2,947 | -2,837 |
Electric Generation, Transmission and Distribution Equipment [Member] | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' |
Public Utilities, Property, Plant and Equipment, Plant in Service | 18,730 | 17,689 |
Total Utility Accumulated Depreciation, Depletion and Amortization | -6,951 | -6,717 |
Gas Distribution [Member] | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' |
Property Plant and Equipment - Distribution | 2,834 | 2,704 |
Less Accumulated Depreciation, Depletion and Amortization - Distribution | -1,129 | -1,057 |
Storage [Member] | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' |
Property, Plant and Equipment - Storage | 431 | 426 |
Less Accumulated Depreciation, Depletion and Amortization - Storage | -138 | -132 |
Other [Member] | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' |
Property, Plant and Equipment - Other | 836 | 852 |
Less Accumulated Depreciation, Depletion and Amortization - Other | -338 | -365 |
Gas Distribution and Storage [Member] | ' | ' |
Property, Plant and Equipment [Line Items] | ' | ' |
Public Utilities, Property, Plant and Equipment, Plant in Service | 4,101 | 3,982 |
Total Utility Accumulated Depreciation, Depletion and Amortization | ($1,605) | ($1,554) |
Property_Plant_and_Equipment_A
Property, Plant and Equipment (Average Estimated Useful Life of Each Major Class) (Details) | 12 Months Ended |
Dec. 31, 2013 | |
Electric [Member] | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' |
Useful Life - Generation | '40 years |
Useful Life - Distribution | '41 years |
Gas [Member] | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' |
Useful Life - Distribution | '50 years |
Useful Life - Storage | '53 years |
Property_Plant_and_Equipment_D
Property, Plant and Equipment (Details Textuals) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Public Utility Property, Plant and Equipment [Line Items] | ' | ' | ' |
AFUDC capitalized | $23 | $20 | ' |
Capitalized Computer Software, Amortization | 71 | 68 | 65 |
Capitalized Computer Software, Gross | 668 | 608 | ' |
Capitalized Computer Software, Accumulated Amortization | 384 | 313 | ' |
Capital Leased Assets, Gross | 35 | 32 | ' |
Capital Leases, Lessee Balance Sheet, Assets by Major Class, Accumulated Depreciation | $21 | $20 | ' |
Electric [Member] | ' | ' | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' | ' | ' |
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service | 3.40% | 3.30% | 3.30% |
Gas [Member] | ' | ' | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' | ' | ' |
Public Utilities, Property, Plant and Equipment, Disclosure of Composite Depreciation Rate for Plants in Service | 2.40% | 2.40% | 2.30% |
Minimum [Member] | ' | ' | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' | ' | ' |
Property, Plant and Equipment, Useful Life | '3 years | ' | ' |
Finite-Lived Intangible Assets, Useful Life | '1 year | ' | ' |
Maximum [Member] | ' | ' | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' | ' | ' |
Property, Plant and Equipment, Useful Life | '55 years | ' | ' |
Finite-Lived Intangible Assets, Useful Life | '28 years | ' | ' |
Computer Software, Intangible Asset [Member] | Minimum [Member] | ' | ' | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' | ' | ' |
Finite-Lived Intangible Assets, Useful Life | '3 years | ' | ' |
Computer Software, Intangible Asset [Member] | Maximum [Member] | ' | ' | ' |
Public Utility Property, Plant and Equipment [Line Items] | ' | ' | ' |
Finite-Lived Intangible Assets, Useful Life | '15 years | ' | ' |
Jointly_Owned_Utility_Plant_De
Jointly Owned Utility Plant (Details) (USD $) | Dec. 31, 2013 |
In Millions, unless otherwise specified | dte.capacity |
Belle River [Member] | ' |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Total plant capacity (in MW) | 1,270 |
Investment (in millions) | $1,702 |
Accumulated depreciation (in millions) | 969 |
Ludington [Member] | ' |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Total plant capacity (in MW) | 1,872 |
Ownership interest | 49.00% |
Investment (in millions) | 354 |
Accumulated depreciation (in millions) | $170 |
Jointly_Owned_Utility_Plant_De1
Jointly Owned Utility Plant (Detail Textuals) | Dec. 31, 2013 |
facilities | |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Jointly Owned Utility Plant Number of Plants | 2 |
Belle River Unit 1 [Member] | ' |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Jointly Owned Utility Plant, Proportionate Ownership Share | 63.00% |
Belle River Facilities used jointly by Belle River and St. Clair Power Plants [Member] | ' |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Jointly Owned Utility Plant, Proportionate Ownership Share | 81.00% |
Belle River [Member] | ' |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Joint Owners Percentage of the Total Capacity Energy and Related Responsibilities | 19.00% |
Belle River Unit 2 [Member] | ' |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Jointly Owned Utility Plant, Proportionate Ownership Share | 75.00% |
Ludington [Member] | ' |
Jointly Owned Utility Plant Interests [Line Items] | ' |
Jointly Owned Utility Plant, Proportionate Ownership Share | 49.00% |
Joint Owners Percentage of the Total Capacity Energy and Related Responsibilities | 51.00% |
Asset_Retirement_Obligations_D
Asset Retirement Obligations (Details) (USD $) | 12 Months Ended |
In Millions, unless otherwise specified | Dec. 31, 2013 |
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ' |
Asset retirement obligations, beginning balance | $1,719 |
Accretion | 106 |
Liabilities incurred | 5 |
Liabilities settled | -13 |
Revision in estimated cash flows | 10 |
Asset retirement obligations, ending balance | $1,827 |
Asset_Retirement_Obligations_D1
Asset Retirement Obligations (Details Textuals) (USD $) | 12 Months Ended | 3 Months Ended | 6 Months Ended | 3 Months Ended | 12 Months Ended |
Dec. 31, 2013 | Mar. 31, 2011 | Jun. 30, 2011 | Dec. 31, 2011 | Dec. 31, 2013 | |
Fermi 1 [Member] | Fermi 1 [Member] | Fermi 2 [Member] | Fermi 2 [Member] | ||
Asset Retirement Obligations [Line Items] | ' | ' | ' | ' | ' |
Asset Retirement Obligations, Liability Not Recognized | 'Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets. | ' | ' | ' | ' |
Revision in estimated cash flows | $10,000,000 | $19,000,000 | $20,000,000 | $22,000,000 | ' |
Reserve and Impairment of Retirement Obligation | ' | ' | 6,000,000 | ' | ' |
Proposed Extension of Nuclear Plant 2 License | ' | ' | ' | ' | '20 years |
Estimated decommissioning expenses, current fiscal year dollars | ' | ' | ' | ' | 1,600,000,000 |
Estimated decommissioning expenses, end of extended license dollars | ' | ' | ' | ' | 10,000,000,000 |
Inflation Rate Used to Determine Estimated Decommissioning Expenditures | ' | ' | ' | ' | 6.00% |
Nuclear Decommissioning Liabilities Funded Through Surcharge and Included In ARO Balance | ' | ' | ' | ' | 1,600,000,000 |
Liabilities Balance upon Completion of Decommissioning | $0 | ' | ' | ' | ' |
Regulatory_Matters_Schedule_of
Regulatory Matters (Schedule of Regulatory Assets) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | $2,863 | $4,417 |
Regulatory Assets, Current | -26 | -182 |
Regulatory Assets, Noncurrent | 2,837 | 4,235 |
Securitized Regulatory Assets, Noncurrent | 231 | 413 |
Pension Costs [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 1,660 | 2,420 |
Postretirment Costs [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 0 | 426 |
Asset Retirement Obligation Costs [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 394 | 424 |
Recoverable Michigan Income Taxes [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 286 | 304 |
Recoverable Income Taxes related to Securitized Regulatory Assets [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 126 | 226 |
Cost to Achieve Performance Excellence Process [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 75 | 96 |
Other Recoverabe Income Taxes [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 71 | 76 |
Unamortized Loss on Reacquired Debt [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 63 | 63 |
Environmental Restoration Costs [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 59 | 58 |
Enterprise Business Systems Costs [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 13 | 16 |
Regulatory Clause Revenues, under-recovered [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 9 | 28 |
Choice Incentive Mechanism [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 3 | 66 |
Accrued PSCRandGCR Revenue [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 0 | 87 |
Recoverable Restoration Expense [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | 0 | 49 |
Other Assets [Member] | ' | ' |
Regulatory Assets [Line Items] | ' | ' |
Regulatory Assets | $104 | $78 |
Regulatory_Matters_Regulatory_
Regulatory Matters Regulatory Matters (Schedule of Regulatory Liabilities) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | $1,164 | $1,120 |
Regulatory Liability, Current | -302 | -89 |
Regulatory Liability, Noncurrent | 862 | 1,031 |
Asset Removal Costs [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 351 | 439 |
Renewable Energy [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 277 | 230 |
Refundable Revenue Decoupling [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 127 | 127 |
Pension Costs [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 84 | 105 |
Over Recovery of Securitization [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 72 | 54 |
Refundable postretirement costs [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 72 | 0 |
Accrued PSCR GCR Refund [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 65 | 16 |
Refundable Income Taxes [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 45 | 56 |
Energy Optimization [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 31 | 34 |
Refueling Outage [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 26 | 12 |
Refundable Uncollectible Expense [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | 12 | 37 |
Other Liabilities [Member] | ' | ' |
Regulatory Liabilities [Line Items] | ' | ' |
Regulatory Liabilities | $2 | $10 |
Regulatory_Matters_Details_Tex
Regulatory Matters (Details Textuals) (USD $) | 1 Months Ended | 3 Months Ended | 6 Months Ended | 12 Months Ended | 1 Months Ended | 1 Months Ended | 12 Months Ended | 6 Months Ended | 1 Months Ended | 12 Months Ended | |||||||||||||||
Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2010 | Dec. 31, 2013 | Dec. 31, 2013 | Jul. 29, 2013 | Jul. 30, 2012 | 31-May-13 | Dec. 31, 2013 | 31-May-13 | Dec. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2013 | Jun. 30, 2013 | Oct. 17, 2013 | Aug. 29, 2013 | Feb. 28, 2013 | Oct. 31, 2013 | Feb. 29, 2012 | Dec. 31, 2013 | Nov. 14, 2013 | 15-May-13 | Apr. 16, 2013 | Jun. 30, 2012 | |
Electric [Member] | Electric [Member] | Gas [Member] | Gas [Member] | Five Year (Minimum) [Member] | Seven Year (Maximum) [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | MPSC [Member] | ||||||||
Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Gas [Member] | Gas [Member] | Gas [Member] | Gas [Member] | Gas [Member] | Gas [Member] | Gas [Member] | ||||||||||||
Regulatory Assets [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Probability of Recovery Through Regulatory Rates for Regulatory Assets and Liabilities | ' | ' | ' | ' | $0 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Time Period Required by Non-Bypassable Securitization Bond Surcharge to Recover Securitized Regulatory Asset | ' | ' | ' | ' | '14 years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Amortization Period of Cost to Achieve Deferral | ' | ' | ' | ' | '10 years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Deferral of Investigation and Remediation of Costs Associated with Gas Utilities Former MGP Sites | ' | ' | ' | ' | '10 years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Amortization Period for Enterprise Business Systems | ' | ' | ' | ' | '10 years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Rate increase previously authorized by the MPSC challeged by Court of Appeals affirmed by the MPSC | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 8,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Rate increase previously authorized by the MPSC challenged by Court of Appeals reopened by the MPSC | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 11,000,000 | ' | ' | ' | ' | ' | ' | ' | ' |
Transition PLD customers to DTE Electric distribution system | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '5 years | '7 years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
EO Reconciliation net over-recovery | ' | ' | ' | ' | ' | ' | ' | 26,000,000 | ' | 7,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Approved performance incentive charges | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 10,000,000 | ' | ' | ' | ' | ' | ' | 4,000,000 | ' | ' | ' | ' |
Approved net recovery of restoration expense tracker mechanism and line clearance tracker | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 44,000,000 | ' | ' | ' | ' | ' | ' | ' |
Approved refund of uncollectible expense true up mechanism for two plan years prior | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 9,000,000 | ' | ' | ' | ' | ' |
Monthly Funding Factor for all Michigan Electric utilities participating in Low Income Energy Assistance Fund | ' | ' | ' | ' | ' | 0.0099 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
REP Surcharge Revenue Recovery | ' | ' | ' | 15,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 100,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
REP Time Period | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '20 years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
PSCR under-recovery from Three Plan Years Prior | ' | ' | 52,600,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Pension Equalization Mechanism Reconciliation surcharge length | '1 month | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
PSCR under-recovery from One Plan Year Prior | ' | 87,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
PSCR Under-Recovery from Two Plan Years Prior | ' | 148,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Fermi 2 Production Level of Full Capacity | ' | ' | ' | ' | ' | ' | 68.00% | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Maximum of challenged Fermi 2 outage charges | ' | ' | ' | ' | ' | ' | ' | ' | 32,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Projected Test Year Period for Gas Rate Case | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '12 months | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
MPSC Approved Increase in Annual Gas Rates | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 19,900,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Approved recovery of infrastructure recovery mechanism | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 77,000,000 | ' |
UETM Accrual for Over-Recovery | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 20,000,000 | ' | ' | ' | ' |
Period over which approved UETM will be refunded | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '12 months | ' | ' | ' | ' | ' | ' |
RDM Application Proposed Recovery | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | $5,200,000 | ' | ' | $9,000,000 |
RDM Caps for First Reconciliation Period | ' | ' | ' | ' | 1.13% | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
RDM Cap for Second Period Reconciliation | ' | ' | ' | ' | 2.25% | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Composite Depreciation Rates | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 2.51% | ' | 2.29% | ' | ' |
Income_Taxes_Reconciliation_of
Income Taxes (Reconciliation of Income Tax Expense to the Statutory Federal Income Tax Rate) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Effective Income Tax Rate Reconciliation, Amount [Abstract] | ' | ' | ' |
Income (Loss) from Continuing Operations before Income Taxes, Extraordinary Items, Noncontrolling Interest | $922 | $960 | $991 |
Income tax expense at 35% statutory rate | 323 | 336 | 347 |
Production tax credits | -68 | -49 | -6 |
Investment tax credits | -6 | -6 | -6 |
Depreciation | -4 | -4 | -4 |
AFUDC - Equity | -5 | -4 | -1 |
Employee Stock Ownership Plan dividends | -4 | -4 | -4 |
Domestic production activities deduction | -14 | -14 | -7 |
State and Local income taxes, net of federal benefit | 37 | 37 | 37 |
Enactment of Michigan Corporate income Tax, net of federal expense | 0 | 0 | -87 |
Other, net | -5 | -6 | -1 |
Income Tax Expense (Benefit) | $254 | $286 | $268 |
Effective Income Tax Rate | 27.50% | 29.80% | 27.00% |
Income_Taxes_Components_of_Inc
Income Taxes (Components of Income Tax Expense) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Components of Income Tax Expense (Benefit) [Abstract] | ' | ' | ' |
Federal income tax expense (benefit) | $74 | $190 | $27 |
State and other income tax expense (benefit) | 16 | 49 | 21 |
Total current income taxes expense (benefit) | 90 | 239 | 48 |
Federal deferred income tax expense (benefit) | 122 | 39 | 318 |
State and other income tax deferred expense (benefit) | 42 | 8 | -98 |
Total deferred income taxes exepense (benefit) | 164 | 47 | 220 |
Income Tax Expense (Benefit) | 254 | 286 | 268 |
Income tax expense (benefit) from Discontinued Operations | 0 | -29 | -1 |
Income Tax Expense (Benefit) including Discontinued Operations | $254 | $257 | $267 |
Income_Taxes_Deferred_Tax_Asse
Income Taxes (Deferred Tax Assets (Liabilities)) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Components of Deferred Tax Assets and Liabilities [Abstract] | ' | ' |
Property, plant and equipment | ($3,372) | ($3,389) |
Securitized regulatory assets | -127 | -256 |
Alternative minimum tax credit carry-forwards | 266 | 254 |
Merger basis differences | 18 | 42 |
Pension and benefits | -30 | -33 |
Other comprehensive income | 0 | 101 |
Derivative assets liabilities | 0 | 66 |
State net operating loss and credit carry-forwards | 43 | 37 |
Deferred Tax Liabilities, Other | -110 | ' |
Other | ' | 41 |
Deferred Tax Liabilities, Gross | -3,312 | -3,137 |
Less valuation allowance | -37 | -33 |
Current deferred income tax assets | -28 | 21 |
Long-term deferred income tax liabilities | -3,321 | -3,191 |
Deferred Tax Assets, Net of Valuation Allowance | 1,808 | 1,038 |
Deferred Tax Liability, Net of Valuation Allowance | -5,157 | -4,208 |
Deferred income tax liabilities | ($3,349) | ($3,170) |
Income_Taxes_Reconciliation_of1
Income Taxes (Reconciliation of Unrecognized Tax Benefits) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward] | ' | ' | ' |
Unrecognized Tax Benefits, beginning balance | $11 | $48 | $28 |
Additions for tax positions of prior years | 0 | 0 | 27 |
Reductions for tax positions of prior years | 0 | -2 | -4 |
Additions for tax positions related to the current year | 0 | 1 | 1 |
Settlements | 0 | -30 | -3 |
Lapse of statute of limitations | -1 | -6 | -1 |
Unrecognized Tax Benefits, ending balance | $10 | $11 | $48 |
Income_Taxes_Details_Textuals
Income Taxes (Details Textuals) (USD $) | 3 Months Ended | 12 Months Ended | ||
Jun. 30, 2011 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Income Tax Disclosure [Abstract] | ' | ' | ' | ' |
Production Tax Credits Earned In Prior Years But Not Utilized Carried Forward Indefinitely As Alternative Minimum Tax Credits | ' | $266,000,000 | $254,000,000 | ' |
Deferred Tax Assets State Net Operating Loss and Credit Carry Forwards | ' | 43,000,000 | 37,000,000 | ' |
Valuation Allowance, Amount | ' | 37,000,000 | 33,000,000 | ' |
Unrecognized Tax Benefits that Would Impact Effective Tax Rate | ' | 2,000,000 | 3,000,000 | ' |
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Amount of Unrecorded Benefit | ' | 1,000,000 | ' | ' |
Unrecognized Tax Benefits, Interest on Income Taxes Accrued | ' | 1,000,000 | 1,000,000 | ' |
Unrecognized Tax Benefits, Income Tax Penalties Accrued | ' | 0 | ' | ' |
Unrecognized Tax Benefits, Interest on Income Taxes Expense | ' | 0 | -1,000,000 | -2,000,000 |
Michigan Corporate Income Tax | 6.00% | ' | ' | ' |
Time Period for the MBT Deferred Tax Asset | '1 year | ' | ' | ' |
Net impact of Michigan Corporate Income Tax enactment, decrease in deferred tax liabilities attributable to non-utilities | 87,000,000 | ' | ' | ' |
Consistent with Original Treatment of Deferred Tax Liabilities No Cash Flow Impact | $0 | ' | ' | ' |
Common_Stock_Details
Common Stock (Details) (Pension Plan, Defined Benefit [Member], Common Stock [Member], USD $) | 3 Months Ended | 12 Months Ended | |||
In Millions, except Share data, unless otherwise specified | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Jun. 30, 2012 | Dec. 31, 2013 |
Pension Plan, Defined Benefit [Member] | Common Stock [Member] | ' | ' | ' | ' | ' |
Class of Stock [Line Items] | ' | ' | ' | ' | ' |
Stock Issued During Period, Shares, Employee Benefit Plan | 1,522,301 | 753,579 | 750,075 | 1,334,668 | ' |
Contribution of Common Stock to Pension Plans Amount Per Share | $65.69 | $66.35 | $66.66 | $59.94 | ' |
Pension Contributions | $100 | $50 | $50 | $80 | $200 |
Common_Stock_Details_Textuals
Common Stock (Details Textuals) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Class of Stock [Line Items] | ' | ' |
Maximum Total Funded Debt to Total Capitalization Ratio | 0.65 | ' |
Line of Credit Facility, Dividend Restrictions | '166 | ' |
Retained Earnings (Accumulated Deficit) | $4,150 | $3,944 |
Other Restrictions on Payment of Dividends | '0 | ' |
Earnings_Per_Share_Details
Earnings Per Share (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||||||
In Millions, except Per Share data, unless otherwise specified | Dec. 31, 2013 | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2012 | Jun. 30, 2012 | Mar. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Basic Earnings per Share | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Net Income Attributable to DTE Energy Company | $124 | $198 | $105 | $234 | $81 | $227 | $146 | $156 | $661 | $610 | $711 |
Average number of common shares outstanding | ' | ' | ' | ' | ' | ' | ' | ' | 175 | 171 | 169 |
Weighted average net restricted shares outstanding | ' | ' | ' | ' | ' | ' | ' | ' | 1 | 1 | 1 |
Dividends declared, Common Stock | ' | ' | ' | ' | ' | ' | ' | ' | 453 | 413 | 392 |
Dividends declared, Net restricted shares | ' | ' | ' | ' | ' | ' | ' | ' | 1 | 1 | 1 |
Total distributed earnings | ' | ' | ' | ' | ' | ' | ' | ' | 454 | 414 | 393 |
Net income less distributed earnings, Basic | ' | ' | ' | ' | ' | ' | ' | ' | 207 | 196 | 318 |
Distributed (dividends per common share) | ' | ' | ' | ' | ' | ' | ' | ' | $2.59 | $2.42 | $2.32 |
Undistributed | ' | ' | ' | ' | ' | ' | ' | ' | $1.17 | $1.14 | $1.87 |
Total Basic Earnings per Common Share | $0.70 | $1.13 | $0.60 | $1.35 | $0.47 | $1.32 | $0.86 | $0.91 | $3.76 | $3.56 | $4.19 |
Diluted Earnings per Share | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Net Income Attributable to DTE Energy Company | 124 | 198 | 105 | 234 | 81 | 227 | 146 | 156 | 661 | 610 | 711 |
Common shares for dilutive calculation | ' | ' | ' | ' | ' | ' | ' | ' | 175 | 171 | 169 |
Average incremental shares from assumed exercise of options | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 1 | 1 |
Weighted Average Number Common shares for dilutive calculation | ' | ' | ' | ' | ' | ' | ' | ' | 175 | 172 | 170 |
Weighted average net restricted shares outstanding | ' | ' | ' | ' | ' | ' | ' | ' | 1 | 1 | 1 |
Dividends declared, Common Stock | ' | ' | ' | ' | ' | ' | ' | ' | 453 | 413 | 392 |
Dividends declared, Net restricted shares | ' | ' | ' | ' | ' | ' | ' | ' | 1 | 1 | 1 |
Total distributed earnings | ' | ' | ' | ' | ' | ' | ' | ' | 454 | 414 | 393 |
Undistributed | ' | ' | ' | ' | ' | ' | ' | ' | $207 | $196 | $318 |
Distributed (dividends per common share) | ' | ' | ' | ' | ' | ' | ' | ' | $2.59 | $2.42 | $2.32 |
Earnings Per Share, Diluted, Undistributed | ' | ' | ' | ' | ' | ' | ' | ' | $1.17 | $1.13 | $1.86 |
Total Diluted Earnings per Common Share | $0.70 | $1.13 | $0.60 | $1.34 | $0.47 | $1.31 | $0.86 | $0.91 | $3.76 | $3.55 | $4.18 |
LongTerm_Debt_Long_Term_Debt_O
Long-Term Debt (Long Term Debt Outstanding and Weighted Average Interest Rates) (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Debt Instrument [Line Items] | ' | ' |
Long-term Debt, Total | $8,094 | $7,813 |
Long Term Debt excluding Securitization, Debentures and Capital Leases | 7,312 | 6,854 |
Less Amount of Long-term Debt due within one year | -694 | -634 |
Long-term Debt, Excluding Current Maturities | 6,618 | 6,220 |
Long-term Securitization Bond | 302 | 479 |
Less Amount of Securitization Bonds due within one year | -197 | -177 |
Securitization bonds, Excluding Current Maturities | 105 | 302 |
Junior Subordinated Notes, Noncurrent | 480 | 480 |
Securitization Bonds [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 6.60% | ' |
Debt Instrument, Maturity Date | 15-Mar-15 | ' |
Junior Subordinated Debentures [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 6.50% | ' |
Debt Instrument, Maturity Date | 1-Dec-61 | ' |
Junior Subordinated Notes, Noncurrent | 280 | 280 |
Junior Subordinated Debentures 1 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 5.25% | ' |
Debt Instrument, Maturity Date | 1-Dec-62 | ' |
Junior Subordinated Notes, Noncurrent | 200 | 200 |
DTE Energy [Member] | Unsecured Debt [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 6.10% | ' |
Debt Instrument, Maturity Date Range, Start | 15-May-14 | ' |
Debt Instrument, Maturity Date Range, End | 15-Apr-33 | ' |
Long-term Debt, Total | 1,297 | 1,298 |
DTE Electric [Member] | Secured Debt [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 4.70% | ' |
Debt Instrument, Maturity Date Range, Start | 31-Mar-14 | ' |
Debt Instrument, Maturity Date Range, End | 1-Apr-43 | ' |
Long-term Debt, Total | 4,286 | 3,777 |
DTE Electric [Member] | Tax Exempt Revenue Bonds [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 5.10% | ' |
Debt Instrument, Maturity Date Range, Start | 1-Apr-14 | ' |
Debt Instrument, Maturity Date Range, End | 1-Dec-36 | ' |
Long-term Debt, Total | 558 | 707 |
DTE Gas [Member] | Secured Debt [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 5.60% | ' |
Debt Instrument, Maturity Date Range, Start | 1-May-14 | ' |
Debt Instrument, Maturity Date Range, End | 15-Dec-42 | ' |
Long-term Debt, Total | 1,029 | 919 |
DTE Gas [Member] | Long Term Debt, Other [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Long-term Debt, Total | $142 | $153 |
LongTerm_Debt_Debt_Issuances_D
Long-Term Debt (Debt Issuances) (Details) (USD $) | Dec. 31, 2013 | Sep. 30, 2013 | Apr. 30, 2013 | Mar. 31, 2013 | Aug. 31, 2013 | Nov. 30, 2013 | Sep. 30, 2013 | Sep. 30, 2013 | Sep. 30, 2013 |
In Millions, unless otherwise specified | Electric [Member] | Gas [Member] | Thirty Years [Member] | Eleven Years [Member] | Ten Years [Member] | Ten Years [Member] | Twelve Years [Member] | Fifteen Years [Member] | |
Senior Notes [Member] | Senior Notes [Member] | Electric [Member] | Electric [Member] | DTE Energy [Member] | Gas [Member] | Gas [Member] | Gas [Member] | ||
Mortgages [Member] | Mortgages [Member] | Senior Notes [Member] | Mortgages [Member] | Mortgages [Member] | Mortgages [Member] | ||||
Debt Instrument [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | ' | 6.40% | 5.26% | 4.00% | 3.65% | 3.85% | 3.64% | 3.74% | 3.94% |
Debt Instrument, Face Amount | $1,245 | ' | ' | $375 | $400 | $300 | $50 | $70 | $50 |
LongTerm_Debt_Debt_Redemptions
Long-Term Debt (Debt Redemptions) (Details) (USD $) | 12 Months Ended | 1 Months Ended | 9 Months Ended | 1 Months Ended | |||||||
In Millions, unless otherwise specified | Dec. 31, 2013 | Sep. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2013 | Mar. 31, 2013 | Apr. 30, 2013 | Sep. 30, 2013 | Dec. 31, 2013 | Apr. 30, 2013 | Sep. 30, 2013 | Jun. 30, 2013 |
Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Gas [Member] | DTE Energy [Member] | DTE Energy [Member] | ||
Securitization Bonds [Member] | Securitization Bonds [Member] | Tax Exempt Revenue Bonds [Member] | Tax Exempt Revenue Bonds [Member] | Long Term Debt, Other [Member] | Senior Notes [Member] | Tax-Exempt Revenue Bonds 1 [Member] | Senior Notes [Member] | Long Term Debt, Other [Member] | Senior Notes [Member] | ||
Extinguishment of Debt [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Debt Instrument, Interest Rate, Stated Percentage | ' | 6.62% | 6.42% | 5.50% | 5.30% | ' | 6.40% | 6.75% | 5.26% | ' | ' |
Extinguishment of Debt, Amount | $961 | $89 | $88 | $49 | $51 | $13 | $250 | $50 | $60 | $11 | $300 |
LongTerm_Debt_Scheduled_Debt_M
Long-Term Debt (Scheduled Debt Maturities) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Maturities of Long-term Debt [Abstract] | ' | ' |
Long-term Debt, Maturities, Repayments of Principal in Next Twelve Months | $891 | ' |
Long-term Debt, Maturities, Repayments of Principal in Year Two | 476 | ' |
Long-term Debt, Maturities, Repayments of Principal in Year Three | 465 | ' |
Long-term Debt, Maturities, Repayments of Principal in Year Four | 9 | ' |
Long-term Debt, Maturities, Repayments of Principal in Year Five | 407 | ' |
Long-term Debt, Maturities, Repayments of Principal after Year Five | 5,846 | ' |
Long-term Debt, Total | $8,094 | $7,813 |
LongTerm_Debt_Details_Textuals
Long-Term Debt (Details Textuals) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Debt Instrument [Line Items] | ' | ' |
Junior Subordinated Notes, Noncurrent | $480 | $480 |
Junior Subordinated Debentures [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 6.50% | ' |
Junior Subordinated Notes, Noncurrent | 280 | 280 |
Junior Subordinated Debentures 1 [Member] | ' | ' |
Debt Instrument [Line Items] | ' | ' |
Debt, Weighted Average Interest Rate | 5.25% | ' |
Junior Subordinated Notes, Noncurrent | $200 | $200 |
Preferred_and_Preferenced_Secu2
Preferred and Preferenced Securities (Details) (USD $) | Dec. 31, 2013 |
DTE Energy [Member] | ' |
Preferred and Preferenced Securities [Line Items] | ' |
Preferred Stock, Par Value Per Share | $0 |
Preferred Stock, Shares Authorized | 5,000,000 |
DTE Electric [Member] | ' |
Preferred and Preferenced Securities [Line Items] | ' |
Preferred Stock, Par Value Per Share | $100 |
Preferred Stock, Shares Authorized | 6,747,484 |
Preference Stock, Par Value Per Share | $1 |
Preference Stock, Shares Authorized | 30,000,000 |
DTE Gas [Member] | ' |
Preferred and Preferenced Securities [Line Items] | ' |
Preferred Stock, Par Value Per Share | $1 |
Preferred Stock, Shares Authorized | 7,000,000 |
Preference Stock, Par Value Per Share | $1 |
Preference Stock, Shares Authorized | 4,000,000 |
ShortTerm_Credit_Arrangements_2
Short-Term Credit Arrangements and Borrowings (Details) (USD $) | Dec. 31, 2013 |
In Millions, unless otherwise specified | |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | $1,975 |
Amounts outstanding | 375 |
Net availability | 1,600 |
DTE Energy [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 1,375 |
Amounts outstanding | 279 |
Net availability | 1,096 |
DTE Electric [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 300 |
Amounts outstanding | 0 |
Net availability | 300 |
DTE Gas [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 300 |
Amounts outstanding | 96 |
Net availability | 204 |
Letter of Credit [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | 244 |
Letter of Credit [Member] | DTE Energy [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | 244 |
Letter of Credit [Member] | DTE Electric [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | 0 |
Letter of Credit [Member] | DTE Gas [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | 0 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 50 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member] | DTE Energy [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 50 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member] | DTE Electric [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 0 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in May 2014 [Member] | DTE Gas [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 0 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 125 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member] | DTE Energy [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 125 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member] | DTE Electric [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 0 |
Letter of Credit [Member] | Unsecured letter of credit, expiring in August 2015 [Member] | DTE Gas [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 0 |
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 1,800 |
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member] | DTE Energy [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 1,200 |
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member] | DTE Electric [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 300 |
Revolving Credit Facility [Member] | Unsecured revolving credit facility, expiring April 2018 [Member] | DTE Gas [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Line of Credit Facility, Maximum Borrowing Capacity | 300 |
Commercial Paper [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | 131 |
Commercial Paper [Member] | DTE Energy [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | 35 |
Commercial Paper [Member] | DTE Electric [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | 0 |
Commercial Paper [Member] | DTE Gas [Member] | ' |
Line Of Credit Facility [Line Items] | ' |
Amounts outstanding | $96 |
ShortTerm_Credit_Arrangements_3
Short-Term Credit Arrangements and Borrowings (Details Textuals) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | banks | |
Short-term Debt [Line Items] | ' | ' |
Revolving Credit Facilities with a Syndicate Number of Banks | 19 | ' |
Number of Banks that Provide Percentage of Commitment in any Facility | 1 | ' |
Maximum Percentage of Commitment to Bank in any Facility | 8.70% | ' |
Maximum Total Funded Debt to Total Capitalization Ratio | 0.65 | ' |
Letters of Credit Outstanding, Amount | $375 | ' |
Short-term Debt, Weighted Average Interest Rate | 0.20% | 0.40% |
DTE Energy [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Total Funded Debt to Total Capitalization Ratio | 0.48 | ' |
Letters of Credit Outstanding, Amount | 279 | ' |
DTE Electric [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Total Funded Debt to Total Capitalization Ratio | 0.5 | ' |
Letters of Credit Outstanding, Amount | 0 | ' |
DTE Gas [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Total Funded Debt to Total Capitalization Ratio | 0.48 | ' |
Letters of Credit Outstanding, Amount | 96 | ' |
Letter of Credit [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Letters of Credit Outstanding, Amount | 244 | ' |
Letter of Credit [Member] | DTE Energy [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Letters of Credit Outstanding, Amount | 244 | ' |
Letter of Credit [Member] | DTE Electric [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Letters of Credit Outstanding, Amount | 0 | ' |
Letter of Credit [Member] | DTE Gas [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Letters of Credit Outstanding, Amount | 0 | ' |
Letter of Credit [Member] | Other outstanding letters of credit [Member] | DTE Energy [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Letters of Credit Outstanding, Amount | 53 | ' |
Letter of Credit [Member] | Demand Financing Agreement with Newedge letter of credit to raise capacity [Member] | DTE Energy [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Borrowing Capacity Under Financing Agreement With iss Clearing Agent | 50 | ' |
Demand Financing Agreement with Newedge plus letter of credit [Member] | DTE Energy [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Borrowing Capacity Under Financing Agreement With iss Clearing Agent | 150 | ' |
Demand Financing Agreement with Newedge [Member] | DTE Energy [Member] | ' | ' |
Short-term Debt [Line Items] | ' | ' |
Borrowing Capacity Under Financing Agreement With iss Clearing Agent | 100 | ' |
Maximum Additional Margin Financing | 50 | ' |
Financing Agreement, Amount Outstanding | $138 | 65 |
Capital_and_Operating_Leases_F
Capital and Operating Leases (Future Minimum Lease Payments under Non-Cancelable Leases) (Details) (USD $) | Dec. 31, 2013 | Dec. 31, 2012 |
In Millions, unless otherwise specified | ||
Capital Leases of Lessee [Abstract] | ' | ' |
Capital Leases, Future Minimum Payments Due, Next Twelve Months | $8 | ' |
Capital Leases, Future Minimum Payments Due in Two Years | 8 | ' |
Capital Leases, Future Minimum Payments Due in Three Years | 3 | ' |
Capital Leases, Future Minimum Payments Due in Four Years | 0 | ' |
Capital Leases, Future Minimum Payments Due in Five Years | 0 | ' |
Capital Leases, Future Minimum Payments Due Thereafter | 0 | ' |
Capital Leases, Future Minimum Payments Due | 19 | ' |
Capital Leases, Less imputed interest | 1 | ' |
Capital Leases, Present value of net minimum lease payments | 18 | ' |
Capital Leases, Less current portion | 7 | ' |
Capital lease obligations | 11 | 12 |
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract] | ' | ' |
Operating Leases, Future Minimum Payments Due, Next Twelve Months | 35 | ' |
Operating Leases, Future Minimum Payments Due in Two Years | 31 | ' |
Operating Leases, Future Minimum Payments, Due in Two Years | 27 | ' |
Operating Leases, Future Minimum Payments, Due in Four Years | 25 | ' |
Operating Leases, Future Minimum Payments, Due in Five Years | 20 | ' |
Operating Leases, Future Minimum Payments, Due Thereafter | 92 | ' |
Operating Leases, Future Minimum Payments Due | $230 | ' |
Capital_and_Operating_Componen
Capital and Operating (Components of the Net Investment in the Capital Leases) (Details) (USD $) | Dec. 31, 2013 |
In Millions, unless otherwise specified | |
Capital Leases of Lessor [Abstract] | ' |
Capital Leases, Future Minimum Payments Receivable, Next Twelve Months | $12 |
Capital Leases, Future Minimum Payments, Receivable in Two Years | 12 |
Capital Leases, Future Minimum Payments, Receivable in Three Years | 12 |
Capital Leases, Future Minimum Payments, Receivable in Four Years | 12 |
Capital Leases, Future Minimum Payments, Receivable in Five Years | 12 |
Capital Leases, Future Minimum Payments, Receivable Due Thereafter | 19 |
Capital Leases, Future Minimum Payments Receivable, Total | 79 |
Capital Leases, Residual value of leased pipeline | 40 |
Capital Leases, Less unearned income | -40 |
Net Investment in Capital lease | 79 |
Capital Leases, Less current portion | -5 |
Capital Leases, Lessor Balance Sheet, Net Investment in Direct Financing Leases, Noncurrent | $74 |
Capital_and_Operating_Leases_D
Capital and Operating Leases (Details Textuals) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Capital and Operating Leases [Abstract] | ' | ' | ' |
Operating Leases, Rent Expense | $34 | $36 | $40 |
Description of Lessor Leasing Arrangements, Capital Leases | 'The Company leases a portion of its pipeline system to the Vector Pipeline through a capital lease contract that expires in 2020, with renewal options extending for five years. The Company owns a 40% interest in the Vector Pipeline. In addition, the Company has an energy services agreement, a portion of which is accounted for as a capital lease. The agreement expires in 2019, with a three or five year renewal option. | ' | ' |
Commitments_and_Contingencies_2
Commitments and Contingencies (Details Textuals) (USD $) | 12 Months Ended | 12 Months Ended | 12 Months Ended | 3 Months Ended | 9 Months Ended | 12 Months Ended | 12 Months Ended | |||||||
Dec. 31, 2013 | Aug. 31, 2013 | Dec. 31, 2010 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2013 | Mar. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
employees | dte_instances | Gas [Member] | Gas [Member] | Synthetic Fuel [Member] | Emissions [Member] | Other Guarantees [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Electric [Member] | Eight Year [Member] | ||
facilities | facilities | dte_instances | facilities | facilities | Electric [Member] | |||||||||
dte_instances | facilities | dte_instances | kWh | |||||||||||
dte_instances | ||||||||||||||
Loss Contingencies [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Environmental Capital Expenditures Through Current Year | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | $2,000,000,000 | ' | ' |
Estimated capital expenditures in next fiscal year | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 280,000,000 | ' | ' |
Environmental Capital Expenditures In Future Years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 1,200,000,000 | ' | ' |
EPA is Alleging Power Plants Violated New Source Performance Standards | ' | ' | ' | ' | ' | ' | ' | ' | 5 | ' | 5 | 5 | ' | ' |
Number of NOVs/FOVs currently being discussed with the EPA | ' | ' | ' | ' | ' | ' | ' | ' | 2 | ' | 2 | 2 | ' | ' |
Sierra Club is Alleging DTE Electric Coal Fired Power Plants Violated the Clean Air Act | ' | ' | ' | ' | ' | ' | ' | ' | ' | 4 | ' | ' | ' | ' |
Exceedances of Opacity Standard | ' | ' | ' | ' | ' | ' | ' | ' | 1,139 | 1,499 | 1,139 | 1,139 | ' | ' |
Period of excess opacity of air emissions at alleged facilities | ' | ' | ' | ' | ' | ' | ' | ' | ' | '6 minutes | ' | ' | ' | ' |
2004 EPA proposed compliance timeline in years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '8 years |
Number of Former MGP Sites | ' | ' | ' | 15 | ' | ' | ' | ' | ' | ' | ' | 3 | ' | ' |
Accrued for remediation related to the sites | ' | ' | ' | 28,000,000 | 29,000,000 | ' | ' | ' | 8,000,000 | ' | 8,000,000 | 8,000,000 | 9,000,000 | ' |
Number of Options to Regulate Coal Ash Residue | ' | ' | ' | ' | ' | ' | ' | ' | 2 | ' | 2 | 2 | ' | ' |
Period Gas Utility Can Amortize MGP Costs | ' | ' | ' | '10 years | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Number of NOVs | ' | ' | 2 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Possible Environmental Capital Expenditures to Comply with Requirements | 3,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
EPA Sulfur Dioxide Ambient Air Quality Standard | '1 hour | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Waiting Period of Policy | 'P12W | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Insurance Coverage for Extra Expense when Power Plant Unavailable | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 490,000,000 | ' | ' |
Period of Coverage of Policy for Extra Expenses | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '3 years | ' | ' |
Primary Coverage | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 500,000,000 | ' | ' |
Coverage for Stabilization Decontamination Debris Removal Repair and Replacement of Property and Decommissioning | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 2,250,000,000 | ' | ' |
Combined Coverage Limit for Total Property Damage | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 2,750,000,000 | ' | ' |
Insurance Deductible for Nuclear Power Plant | ' | ' | ' | ' | ' | ' | ' | ' | 1,000,000 | ' | 1,000,000 | 1,000,000 | ' | ' |
Total Limit for Property Damage for Non-Nuclear Events | ' | ' | ' | ' | ' | ' | ' | ' | 1,800,000,000 | ' | 1,800,000,000 | 1,800,000,000 | ' | ' |
Limit of Coverage for Aggregate Extra Expenses for Non-Nuclear Events | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 327,000,000 | ' | ' | ' |
Limit for Property Damage for Non-Nuclear Events Aggregate of Extra Expenses of Period | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '2 years | ' | ' | ' |
Time Period for TRIA Insurance After the First Loss from Terrorism | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | '1 year | ' | ' |
NEIL Policies Against Terroism Loss | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 3,200,000,000 | ' | ' |
Amount per Event Loss Associated with Nuclear Power Plants | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 34,000,000 | ' | ' |
Maintenance of Public Liability Insurance for Nuclear Power Plants | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 375,000,000 | ' | ' |
Aggregate Limit of Liabilities Arises From Terroist Act Outside Scope of Trials Subject to One Industry | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 300,000,000 | ' | ' |
Deferred Premium Charged Leviied Against Each Licensed Nuclear Facility | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 127,300,000 | ' | ' |
Limit Deferred Premium Charges Per Year | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 19,000,000 | ' | ' |
Company Obligated to Pay DOE Fee of Fermi 2 Electricity Generated and Sold | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | 1 | ' | ' |
Settlement Provided for Delay-Related Costs | ' | ' | ' | ' | ' | ' | ' | ' | 48,000,000 | ' | 48,000,000 | 48,000,000 | ' | ' |
Court of Appeals proposal to congress to reduce nuclear waste fee, amount | ' | ' | ' | ' | ' | ' | ' | ' | 0 | ' | ' | ' | ' | ' |
Time period after which the Court of Appeals proposal to Congress for nuclear waste fee reduction will take effect | '90 days | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Days Obligations will Survive After Expiration of All Applicable Statutes of Limiations | ' | ' | ' | ' | ' | '90 years | '90 days | ' | ' | ' | ' | ' | ' | ' |
Guarantor Obligations, Maximum Exposure, Undiscounted | ' | ' | ' | ' | ' | 1,100,000,000 | 144,000,000 | 60,000,000 | ' | ' | ' | ' | ' | ' |
Performance Bonds Outstanding | 41,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Number of Represented Employees | 4,900 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Long-term Purchase Commitment, Amount | 8,598,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Estimated future capital expenditures for next year | 2,300,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Bankruptcy Claims, Accounts Receivable under Review by Management | ' | $20,000,000 | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Commitments_and_Contingencies_3
Commitments and Contingencies (Purchase Commitments) (Details) (USD $) | Dec. 31, 2013 |
In Millions, unless otherwise specified | |
Purchase Obligation, Fiscal Year Maturity [Abstract] | ' |
Purchase Obligation, Due in Next Twelve Months | $2,617 |
Purchase Obligation, Due in Second Year | 1,195 |
Purchase Obligation, Due in Third Year | 643 |
Purchase Obligation, Due in Fourth Year | 345 |
Purchase Obligation, Due in Fifth Year | 311 |
Purchase Obligation, Due after Fifth Year | 3,487 |
Long-term Purchase Commitment, Amount | $8,598 |
Retirement_Benefits_and_Truste2
Retirement Benefits and Trusteed Assets (Pension Plan - Pension Cost Inclusions) (Details) (Pension Plan, Defined Benefit [Member], USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Pension Plan, Defined Benefit [Member] | ' | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' | ' |
Service cost | $94 | $82 | $69 |
Interest cost | 192 | 204 | 202 |
Expected return on plan assets | -266 | -244 | -246 |
Amortization of Net Loss | 208 | 176 | 142 |
Amortization of Prior Service Cost (Credit) | 0 | 0 | 3 |
Special termination benefits | 0 | 2 | 2 |
Net pension or postretirement cost (benefit) | $228 | $220 | $172 |
Retirement_Benefits_and_Truste3
Retirement Benefits and Trusteed Assets (Pension Plan - Other Changes in Plan Assets and Benefit Obligations recognized in Reg Assets and OCI) (Details) (Pension Plan, Defined Benefit [Member], USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Pension Plan, Defined Benefit [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Net actuarial loss | ($581) | $395 |
Amortization of net actuarial loss | -208 | -178 |
Total recognized Regulatory assets and Other comprehensive income | -789 | 217 |
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income | -561 | 437 |
Future amortization of net actuarial loss into net periodic benefit cost | $151 | $202 |
Retirement_Benefits_and_Truste4
Retirement Benefits and Trusteed Assets (Pension Plan - Reconciliation of Obligations, Assets and Funded Status of Plans) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items] | ' | ' | ' |
Regulatory Assets | $2,863 | $4,417 | ' |
Pension Plan, Defined Benefit [Member] | ' | ' | ' |
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items] | ' | ' | ' |
Accumulated benefit obligation, end of year | 4,068 | 4,349 | ' |
Benefit obligation, beginning of year | 4,729 | 4,195 | ' |
Service cost | 94 | 82 | 69 |
Interest cost | 192 | 204 | 202 |
Plan amendments | -3 | 0 | ' |
Actuarial loss | -400 | 474 | ' |
Special termination benefits | 0 | 2 | 2 |
Benefits paid | -232 | -228 | ' |
Benefit obligation, end of year | 4,380 | 4,729 | 4,195 |
Plan assets at fair value, beginning of the year | 3,223 | 2,886 | ' |
Actual return on plan assets | 445 | 325 | ' |
Company contributions | 284 | 240 | ' |
Plan assets at fair value, end of the year | 3,720 | 3,223 | 2,886 |
Funded status of the plans | -660 | -1,506 | ' |
Current liabilities | -7 | -8 | ' |
Noncurrent liabilities | -653 | -1,498 | ' |
Pension and Other Postretirement Defined Benefit Plans, Liabilities | -660 | -1,506 | ' |
Net actuarial loss recognized in other comprehensive loss | 174 | 205 | ' |
Prior service cost (credit) recognized in other comprehensive income | -1 | -2 | ' |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | 173 | 203 | ' |
Net actuarial loss recognized in regulatory assets | 1,654 | 2,413 | ' |
Prior service cost recognized in regulatory assets | 6 | 7 | ' |
Regulatory Assets | $1,660 | $2,420 | ' |
Retirement_Benefits_and_Truste5
Retirement Benefits and Trusteed Assets (Pension Plan - Benefits related to Qualified and Nonqualified Pension Plans Expected to be paid in the Next Ten Years) (Details) (Pension Plan, Defined Benefit [Member], USD $) | Dec. 31, 2013 |
In Millions, unless otherwise specified | |
Pension Plan, Defined Benefit [Member] | ' |
Pension Benefits to be Paid Over the Next 5 Years and Thereafter [Line Items] | ' |
Defined Benefit Plan, Expected Future Benefit Payments in next twelve months | $242 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Two | 250 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Three | 258 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Four | 268 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Five | 280 |
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter | 1,529 |
Total Defined Benefit Pension Plan Expected Future Payments | $2,827 |
Retirement_Benefits_and_Truste6
Retirement Benefits and Trusteed Assets (Pension Plan - Assumptions used in Determining the PBO and Net Pension Costs) (Details) (Pension Plan, Defined Benefit [Member]) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Pension Plan, Defined Benefit [Member] | ' | ' | ' |
Assumptions Used to Determin Projected Benefit Obligations and Net Pension Costs [Line Items] | ' | ' | ' |
Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.95% | 4.15% | 5.00% |
Assumptions Used Calculating Benefit Obligation, Rate of compensation increase | 4.20% | 4.20% | 4.20% |
Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 4.15% | 5.00% | 5.50% |
Assumptions Used Calculating Net Periodic Benefit Cost, Rate of compensation increase | 4.20% | 4.20% | 4.00% |
Assumptions Used Calculating Net Periodic Benefit Cost, Expected long-term rate of return on plan assets | 8.25% | 8.25% | 8.50% |
Retirement_Benefits_and_Truste7
Retirement Benefits and Trusteed Assets (Pension Plan - Target Allocations of Plan Assets) (Details) (Pension Plan, Defined Benefit [Member]) | 12 Months Ended |
Dec. 31, 2013 | |
Pension Plan Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '1 |
US Large Cap Equity Securities [Member] | ' |
Pension Plan Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.22 |
US Small Cap and Mid Cap Equity Securities [Member] | ' |
Pension Plan Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.05 |
Non US Equity Securities [Member] | ' |
Pension Plan Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.2 |
Fixed Income Securities [Member] | ' |
Pension Plan Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.25 |
Hedge Funds and Similar Investments [Member] | ' |
Pension Plan Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.2 |
Private Equity and Other [Member] | ' |
Pension Plan Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.08 |
Retirement_Benefits_and_Truste8
Retirement Benefits and Trusteed Assets (Pension Plan - Fair Value Measurements) (Details) (Pension Plan, Defined Benefit [Member], USD $) | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
In Millions, unless otherwise specified | |||
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | $3,720 | $3,223 | $2,886 |
Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 2,034 | 1,667 | ' |
Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 1,121 | 1,038 | ' |
Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 565 | 518 | ' |
Short-term investments [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 22 | 24 | ' |
Short-term investments [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 22 | 0 | ' |
Short-term investments [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 24 | ' |
Short-term investments [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
US Large Cap Equity Securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 896 | 732 | ' |
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 896 | 688 | ' |
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 44 | ' |
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 221 | 158 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 221 | 153 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 5 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Non US Equity Securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 741 | 650 | ' |
Non US Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 611 | 530 | ' |
Non US Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 130 | 120 | ' |
Non US Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Fixed income securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 937 | 852 | ' |
Fixed income securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 16 | 87 | ' |
Fixed income securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 921 | 765 | ' |
Fixed income securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Hedge Funds and Similar Investments [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 733 | 628 | ' |
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 268 | 209 | ' |
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 70 | 80 | ' |
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 395 | 339 | ' |
Private Equity and Other [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 170 | 179 | ' |
Private Equity and Other [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Private Equity and Other [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Private Equity and Other [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | $170 | $179 | ' |
Retirement_Benefits_and_Truste9
Retirement Benefits and Trusteed Assets (Pension Plan - Fair Value Measurement using Level 3 Inputs) (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | ($1) | $58 |
Pension Plan, Defined Benefit [Member] | ' | ' |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
Beginning Balance | 518 | 464 |
Realized gains (losses) | 18 | 12 |
Unrealized gains (losses) | 26 | 7 |
Purchases | 31 | 283 |
Sales | -28 | -248 |
Ending Balance | 565 | 518 |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | 41 | 22 |
Pension Plan, Defined Benefit [Member] | Hedge Funds and Similar Investments [Member] | ' | ' |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
Beginning Balance | 339 | 296 |
Realized gains (losses) | 0 | 18 |
Unrealized gains (losses) | 40 | -5 |
Purchases | 16 | 250 |
Sales | 0 | -220 |
Ending Balance | 395 | 339 |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | 38 | 16 |
Pension Plan, Defined Benefit [Member] | Private Equity and Other [Member] | ' | ' |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
Beginning Balance | 179 | 168 |
Realized gains (losses) | 18 | -6 |
Unrealized gains (losses) | -14 | 12 |
Purchases | 15 | 33 |
Sales | -28 | -28 |
Ending Balance | 170 | 179 |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | $3 | $6 |
Recovered_Sheet1
Retirement Benefits and Trusteed Assets (OPEB - Postretirement Cost Inclusions) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' | ' |
Other Postretirement Costs [Line Items] | ' | ' | ' |
Service cost | $47 | $68 | $64 |
Interest cost | 88 | 120 | 121 |
Expected return on plan assets | -110 | -92 | -94 |
Amortization of Net Loss | 64 | 80 | 55 |
Amortization of Prior Service Cost (Credit) | -131 | -27 | -26 |
Amortization of net transition asset | 0 | 2 | 2 |
Net pension or postretirement cost (benefit) | ($42) | $151 | $122 |
Recovered_Sheet2
Retirement Benefits and Trusteed Assets (OPEB - Other Changes in Plan Assets and APBO Recognized in Regulatory Assets and OCI) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' |
Defined Benefit Plan Disclosure [Line Items] | ' | ' |
Net actuarial loss | ($353) | ($34) |
Amortization of net actuarial loss | -64 | -80 |
Prior service credit | -218 | -264 |
Amortization of prior service cost | 131 | 27 |
Amortization of transition asset | 0 | -2 |
Total recognized Regulatory assets and Other comprehensive income | -504 | -353 |
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive icnome | -546 | -202 |
Future amortization of net actuarial loss into net periodic benefit cost | 21 | 69 |
Future amortization of prior service credit into net periodic benefit cost | ($144) | ($91) |
Recovered_Sheet3
Retirement Benefits and Trusteed Assets (OPEB - Reconciliation of Obligations, Assets and Funded Status of Plans) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Change in Accumulated PostRetirement Benefit Obligation [Line Items] | ' | ' | ' |
Regulatory Liabilities | ($1,164) | ($1,120) | ' |
Regulatory Assets | 2,863 | 4,417 | ' |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' | ' |
Change in Accumulated PostRetirement Benefit Obligation [Line Items] | ' | ' | ' |
Benefit obligation, beginning of year | 2,315 | 2,470 | ' |
Service cost | 47 | 68 | 64 |
Interest cost | 88 | 120 | 121 |
Plan amendments | -218 | -264 | ' |
Actuarial loss | -267 | 5 | ' |
Medicare Part D subsidy | 1 | 6 | ' |
Benefits paid | -88 | -90 | ' |
Benefit obligation, end of year | 1,878 | 2,315 | 2,470 |
Defined Benefit Plan, Fair Value of Plan Assets | 1,527 | 1,153 | 985 |
Actual return on plan assets | 196 | 131 | ' |
Company contributions | 264 | 140 | ' |
Benefits paid | -86 | -103 | ' |
Funded status of the plans | -351 | -1,162 | ' |
Pension and Other Postretirement Defined Benefit Plans, Current Liabilities | -1 | -2 | ' |
Noncurrent liabilities | -350 | -1,160 | ' |
Pension and Other Postretirement Defined Benefit Plans, Liabilities | -351 | -1,162 | ' |
Net actuarial loss recognized in other comprehensive loss | 29 | 40 | ' |
Prior service cost (credit) recognized in other comprehensive income | -10 | -14 | ' |
Net transition obligation | 0 | -1 | ' |
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax | 19 | 25 | ' |
Net actuarial loss recognized in regulatory assets | 321 | 727 | ' |
Prior service cost recognized in regulatory assets | -393 | -302 | ' |
Net transition obligation | 0 | 1 | ' |
Regulatory Liabilities | -72 | ' | ' |
Regulatory Assets | ' | $426 | ' |
Recovered_Sheet4
Retirement Benefits and Trusteed Assets (OPEB - Benefits related to Qualified and Nonqualified Pension Plans Expected to be paid in the Next Ten Years) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $) | Dec. 31, 2013 |
In Millions, unless otherwise specified | |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' |
Benefits Expected to be Paid Over the Next Five Years and Thereafter [Line Items] | ' |
Defined Benefit Plan, Expected Future Benefit Payments in next twelve months | $103 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Two | 110 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Three | 115 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Four | 123 |
Defined Benefit Plan, Expected Future Benefit Payments, Year Five | 130 |
Defined Benefit Plan, Expected Future Benefit Payments, Five Fiscal Years Thereafter | 724 |
Total Expected Future Benefit Payments | $1,305 |
Recovered_Sheet5
Retirement Benefits and Trusteed Assets (OPEB - Assumptions used in Determining the PBO and Net Pension Costs) (Details) | 12 Months Ended | |||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | Mar. 31, 2013 | |
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items] | ' | ' | ' | ' |
Health care trend rate pre and post 65 | ' | ' | 7.00% | ' |
Ultimate health care trend rate | ' | ' | 5.00% | ' |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' | ' | ' |
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items] | ' | ' | ' | ' |
Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.95% | 4.15% | 5.00% | 4.30% |
Defined Benefit Plan Health Care Trend Rate Pre Sixty Five | 7.50% | ' | ' | ' |
Defined Benefit Plan Health Care Trend Rate Post Sixty Five | 6.50% | ' | ' | ' |
Health care trend rate pre and post 65 | 7.00% | 7.00% | 7.00% | ' |
Ultimate health care trend rate | ' | 5.00% | 5.00% | ' |
Assumptions Used Calculating Net Periodic Benefit Cost, Discount Rate | 4.15% | ' | ' | ' |
Defined Benefit Plan Assumptions Used Calculating Other Postretirement Benefit Cost Discount Rate | ' | 5.00% | 5.50% | ' |
Defined Benefit Plan Assumptions Used Calculating Other Postretirement Benefit Cost Discount Rate, post remeasurement | 4.30% | ' | ' | ' |
Expected long-term rate of return on plan assets | 8.25% | 8.25% | 8.75% | ' |
Accumulated postretirement benefit obligation [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' | ' | ' |
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items] | ' | ' | ' | ' |
Ultimate health care trend rate | 4.50% | ' | ' | ' |
Other postretirement benefit costs [Member] | Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' | ' | ' |
Assumptions Used to Determine Projected Benefit Obligation and Benefit Costs [Line Items] | ' | ' | ' | ' |
Ultimate health care trend rate | 5.00% | ' | ' | ' |
Recovered_Sheet6
Retirement Benefits and Trusteed Assets (OPEB - Target Allocations of Plan Assets) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member]) | 12 Months Ended |
Dec. 31, 2013 | |
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '1 |
US Large Cap Equity Securities [Member] | ' |
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.17 |
US Small Cap and Mid Cap Equity Securities [Member] | ' |
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.04 |
Non US Equity Securities [Member] | ' |
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.2 |
Fixed Income Securities [Member] | ' |
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.25 |
Hedge Funds and Similar Investments [Member] | ' |
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.2 |
Private Equity and Other [Member] | ' |
Other Postretirement Benefits Target Allocations of Plan Assets [Line Items] | ' |
Target Allocation Percentage of Assets | '0.14 |
Recovered_Sheet7
Retirement Benefits and Trusteed Assets (OPEB - Fair Value Measurements) (Details) (Other Postretirement Benefit Plan, Defined Benefit [Member], USD $) | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
In Millions, unless otherwise specified | |||
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | $1,527 | $1,153 | $985 |
Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 883 | 665 | ' |
Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 384 | 283 | ' |
Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 260 | 205 | ' |
Short-term investments [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 5 | 3 | ' |
Short-term investments [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 5 | 1 | ' |
Short-term investments [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 2 | ' |
Short-term investments [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
US Large Cap Equity Securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 302 | 192 | ' |
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 302 | 189 | ' |
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 3 | ' |
US Large Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 147 | 105 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 147 | 105 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
US Small Cap and Mid Cap Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Non US Equity Securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 291 | 237 | ' |
Non US Equity Securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 282 | 230 | ' |
Non US Equity Securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 9 | 7 | ' |
Non US Equity Securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Fixed income securities [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 367 | 285 | ' |
Fixed income securities [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 17 | 38 | ' |
Fixed income securities [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 350 | 247 | ' |
Fixed income securities [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Hedge Funds and Similar Investments [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 314 | 245 | ' |
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 130 | 102 | ' |
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 25 | 24 | ' |
Hedge Funds and Similar Investments [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 159 | 119 | ' |
Private Equity and Other [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 101 | 86 | ' |
Private Equity and Other [Member] | Fair Value, Inputs, Level 1 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Private Equity and Other [Member] | Fair Value, Inputs, Level 2 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | 0 | 0 | ' |
Private Equity and Other [Member] | Fair Value, Inputs, Level 3 [Member] | ' | ' | ' |
Schedule of Defined Benefit Plans Fair Value Hierachy Level Assets [Line Items] | ' | ' | ' |
Defined Benefit Plan, Fair Value of Plan Assets | $101 | $86 | ' |
Recovered_Sheet8
Retirement Benefits and Trusteed Assets (OPEB - Fair Value Measurements using Level 3 Inputs) (Details) (USD $) | 12 Months Ended | |
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | ($1) | $58 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
Beginning Balance | 205 | 155 |
Realized gains (losses) | 2 | -5 |
Unrealized gains (losses) | 21 | 14 |
Purchases | 41 | 122 |
Sales | -9 | -81 |
Ending Balance | 260 | 205 |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | 23 | 8 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | Hedge Funds and Similar Investments [Member] | ' | ' |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
Beginning Balance | 119 | 95 |
Realized gains (losses) | 0 | 6 |
Unrealized gains (losses) | 14 | 0 |
Purchases | 26 | 86 |
Sales | 0 | -68 |
Ending Balance | 159 | 119 |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | 14 | 6 |
Other Postretirement Benefit Plan, Defined Benefit [Member] | Private Equity and Other [Member] | ' | ' |
Defined Benefit Plans Fair Value Measurements Using Significant Unobservale Inputs [Line Items] | ' | ' |
Beginning Balance | 86 | 60 |
Realized gains (losses) | 2 | -11 |
Unrealized gains (losses) | 7 | 14 |
Purchases | 15 | 36 |
Sales | -9 | -13 |
Ending Balance | 101 | 86 |
The amount of total gains (losses) included in net income attributed to the change in unrealized gains or losses related to assets still held at the end of the period | $9 | $2 |
Recovered_Sheet9
Retirement Benefits and Trusteed Assets (Details Textuals) (USD $) | 3 Months Ended | 12 Months Ended | ||
Mar. 31, 2013 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | ' | ' | ' |
Company Contribution to Employee Savings Plan | ' | 4.00% | ' | ' |
Company Retiree New Coverage Minimum | ' | $3,250 | ' | ' |
Company Retiree New Coverage Maximum | ' | 3,500 | ' | ' |
Retiree Health Care Allowance will increase at lower of the rate of medical inflation or a set percentage | ' | 2.00% | ' | ' |
Retiree Health Care Allowance | 3,250 | ' | ' | ' |
Prescription Drug Benefit, Effect of Subsidy on Net Periodic Postretirement Benefit Cost | ' | 1,000,000 | 6,000,000 | 6,000,000 |
Grantor Trust Balance | ' | 17,000,000 | 14,000,000 | ' |
Defined Contribution Plan, Cost Recognized | ' | 41,000,000 | 37,000,000 | 35,000,000 |
Pension Plan, Defined Benefit [Member] | ' | ' | ' | ' |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | ' | ' | ' |
Company contributions | ' | 284,000,000 | 240,000,000 | ' |
Estimated Future Employer Contributions in Next Fiscal Year | ' | 345,000,000 | ' | ' |
Defined Benefit Plan, Expected Return on Plan Assets | ' | 7.75% | ' | ' |
Transfers between Level 3 and Level 2 | ' | 0 | 0 | ' |
Transfers between Level 2 and Level 1 | ' | 0 | 0 | ' |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | ' | 4.95% | 4.15% | 5.00% |
Other Postretirement Benefit Plan, Defined Benefit [Member] | ' | ' | ' | ' |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | ' | ' | ' |
Company contributions | ' | 264,000,000 | 140,000,000 | ' |
Estimated Future Employer Contributions in Next Fiscal Year | ' | 145,000,000 | ' | ' |
Defined Benefit Plan, Expected Return on Plan Assets | ' | 8.00% | ' | ' |
Transfers between Level 3 and Level 2 | ' | 0 | 0 | ' |
Transfers between Level 2 and Level 1 | ' | 0 | 0 | ' |
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components | ' | 9,000,000 | ' | ' |
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation | ' | 124,000,000 | ' | ' |
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components | ' | 8,000,000 | ' | ' |
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation | ' | 108,000,000 | ' | ' |
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate | 4.30% | 4.95% | 4.15% | 5.00% |
Retiree Healthcare Plan [Member] | ' | ' | ' | ' |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | ' | ' | ' |
Defined Contribution Plan, Cost Recognized | ' | 2,000,000 | 0 | ' |
DTE Gas Represented Employees [Member] | ' | ' | ' | ' |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | ' | ' | ' |
Company Contribution to Employee Savings Plan | ' | 8.00% | ' | ' |
Qualified Plans [Member] | Pension Plan, Defined Benefit [Member] | ' | ' | ' | ' |
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items] | ' | ' | ' | ' |
Company contributions | ' | $277,000,000 | ' | ' |
StockBased_Compensation_Stock_
Stock-Based Compensation (Stock based compensation by period) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Line Items] | ' | ' | ' |
Stock-based compensation expense | $99 | $83 | $66 |
Tax benefit | 38 | 33 | 25 |
Stock-based compensation cost capitalized in property, plant and equipment | $15 | $5 | $4 |
StockBased_Compensation_Stock_1
Stock-Based Compensation (Stock Option Activity) (Details) (USD $) | 12 Months Ended |
In Millions, except Share data, unless otherwise specified | Dec. 31, 2013 |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items] | ' |
Options outstanding at beginning of period | 1,192,670 |
Granted | 0 |
Exercised | -458,603 |
Forfeitured and expired | -10,370 |
Options outstanding and exercisable at end of period | 723,697 |
Weighted Average Exercise Price Per Share - Options outstanding at beginning of period | $41.86 |
Weighted Average Exercise Price Per Share - Granted | $0 |
Weighted Average Exercise Price Per Share - Exercised | $40.71 |
Weighted Average Exercise Price Per Share - Forfeitured or expired | $41.46 |
Weighted Average Exercise Price Per Share - Options outstanding and exercisable at end of period | $42.60 |
Aggregate Intrinsic Value - Options outstanding and exercisable at end of period | $18 |
StockBased_Compensation_Number
Stock-Based Compensation (Number, Weighted Average Exercise Price and Weighted Average Remaining Contractual Life of Options Outstanding) (Details) (USD $) | 12 Months Ended |
Dec. 31, 2013 | |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items] | ' |
Number of Options | 723,697 |
Weighted Average Exercise Price | $42.60 |
Weighted Average Remaining Contractual Life (Years) | '3 years 10 months |
Exercise Price Range One [Member] | ' |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items] | ' |
Range of Exercise Prices Lower Limit | $27 |
Range of Exercise Prices Upper Limit | $38 |
Number of Options | 67,257 |
Weighted Average Exercise Price | $28.30 |
Weighted Average Remaining Contractual Life (Years) | '5 years 1 month 23 days |
Exercise Price Range Two [Member] | ' |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items] | ' |
Range of Exercise Prices Lower Limit | $38.01 |
Range of Exercise Prices Upper Limit | $42 |
Number of Options | 167,447 |
Weighted Average Exercise Price | $41.23 |
Weighted Average Remaining Contractual Life (Years) | '3 years 2 months 15 days |
Exercise Price Range Three [Member] | ' |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items] | ' |
Range of Exercise Prices Lower Limit | $42.01 |
Range of Exercise Prices Upper Limit | $45 |
Number of Options | 351,893 |
Weighted Average Exercise Price | $44.02 |
Weighted Average Remaining Contractual Life (Years) | '4 years 1 month 27 days |
Exercise Price Range Four [Member] | ' |
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items] | ' |
Range of Exercise Prices Lower Limit | $45.01 |
Range of Exercise Prices Upper Limit | $50 |
Number of Options | 137,100 |
Weighted Average Exercise Price | $47.67 |
Weighted Average Remaining Contractual Life (Years) | '3 years 1 month |
StockBased_Compensation_Stock_2
Stock-Based Compensation (Stock Award Activity) (Details) (USD $) | 12 Months Ended | ||
In Millions, except Share data, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Stock Award Activity [Line Items] | ' | ' | ' |
Compensation cost charged against income (in millions) | $99 | $83 | $66 |
Restricted Stock [Member] | ' | ' | ' |
Stock Award Activity [Line Items] | ' | ' | ' |
Fair value of awards vested (in millions) | 8 | 9 | 13 |
Restricted common shares awarded | 127,785 | 167,320 | 381,840 |
Weighted average market price of shares awarded | $64.72 | $53.71 | $47.98 |
Compensation cost charged against income (in millions) | $23 | $12 | $12 |
Stock_BasedCompensation_Stock_
Stock Based-Compensation (Stock Awards Activity Rollforward) (Details) (USD $) | 12 Months Ended | ||
Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ' | ' | ' |
Forfeitures | -10,370 | ' | ' |
Restricted Stock [Member] | ' | ' | ' |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ' | ' | ' |
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number | 597,648 | ' | ' |
Grants | 127,785 | 167,320 | 381,840 |
Forfeitures | -7,155 | ' | ' |
Vested and Issued | -225,949 | ' | ' |
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number | 492,329 | 597,648 | ' |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $48.33 | ' | ' |
Weighted Average Grant Date Fair Value Per Share - Grants | $64.72 | $53.71 | $47.98 |
Weighted Average Grant Date Fair Value Per Share - Foreitures | $54.61 | ' | ' |
Weighted Average Grant Date Fair Value Per Share - Vested and issued | $45.54 | ' | ' |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $53.76 | $48.33 | ' |
StockBased_Compensation_Perfor
Stock-Based Compensation (Performance Share Awards Compensation Expense) (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Compensation Expense Recorded [Line Items] | ' | ' | ' |
Compensation expense | $99 | $83 | $66 |
Performance Shares [Member] | ' | ' | ' |
Compensation Expense Recorded [Line Items] | ' | ' | ' |
Compensation expense | 77 | 71 | 53 |
Cash settlements | 9 | 4 | 3 |
Stock settlements | $56 | $41 | $25 |
StockBased_Compensation_Perfor1
Stock-Based Compensation (Performance Share Awards Activity) (Details) | 12 Months Ended |
Dec. 31, 2013 | |
Performance Share Awards [Line Items] | ' |
Forfeitures | -10,370 |
Performance Shares [Member] | ' |
Performance Share Awards [Line Items] | ' |
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number | 1,634,364 |
Grants | 564,561 |
Forfeitures | -41,512 |
Performance Shares - Payouts | -548,624 |
Share-based Compensation Arrangement by Share-based Payment Award, Non-Option Equity Instruments, Outstanding, Number | 1,608,789 |
StockBased_Compensation_Unreco
Stock-Based Compensation (Unrecognized Compensation Costs) (Details) (USD $) | 12 Months Ended |
In Millions, unless otherwise specified | Dec. 31, 2013 |
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items] | ' |
Unrecognized Compensation Cost | $55 |
Weighted Average to be Recognized | '11 months 5 days |
Restricted Stock [Member] | ' |
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items] | ' |
Unrecognized Compensation Cost | 10 |
Weighted Average to be Recognized | '11 months 5 days |
Performance Shares [Member] | ' |
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items] | ' |
Unrecognized Compensation Cost | $45 |
Weighted Average to be Recognized | '11 months 5 days |
StockBased_Compensation_Detail
Stock-Based Compensation (Details Textuals) (USD $) | 12 Months Ended | ||
In Millions, except Share data, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Schedule of Stock Based Compensation [Line Items] | ' | ' | ' |
Authorized limit of common stock shares | 11,500,000 | ' | ' |
Performance Units Price per Unit | 1 | ' | ' |
Expiration Period After Date of Grant | '10 years | ' | ' |
Award Vesting Period | '3 years | ' | ' |
Weighted Average Remaining Contractual Term | '3 years 9 months 30 days | ' | ' |
Options, Vested, Number of Shares | 200,844 | ' | ' |
Options, Grants in Period, Weighted Average Grant Date Fair Value | $0 | ' | ' |
Options, Exercises in Period, Total Intrinsic Value | $12 | $25 | $20 |
Stock or Unit Option Plan Expense | 0 | 0.7 | 2 |
Unrecognized Compensation Cost | 55 | ' | ' |
Weighted Average to be Recognized | '11 months 5 days | ' | ' |
Employee Stock Option [Member] | ' | ' | ' |
Schedule of Stock Based Compensation [Line Items] | ' | ' | ' |
Maximum Award Per Employee | 500,000 | ' | ' |
Restricted Stock [Member] | ' | ' | ' |
Schedule of Stock Based Compensation [Line Items] | ' | ' | ' |
Maximum Award Per Employee | 150,000 | ' | ' |
Unrecognized Compensation Cost | 10 | ' | ' |
Weighted Average to be Recognized | '11 months 5 days | ' | ' |
Performance Shares [Member] | ' | ' | ' |
Schedule of Stock Based Compensation [Line Items] | ' | ' | ' |
Maximum Award Per Employee | 300,000 | ' | ' |
Unrecognized Compensation Cost | $45 | ' | ' |
Weighted Average to be Recognized | '11 months 5 days | ' | ' |
Performance Unit [Member] | ' | ' | ' |
Schedule of Stock Based Compensation [Line Items] | ' | ' | ' |
Maximum Award Per Employee | 1,000,000 | ' | ' |
Segment_Information_Details_Te
Segment Information (Details Textuals) | Dec. 31, 2013 |
customers | |
Segment Reporting [Abstract] | ' |
Number of Electric Utility Customers | 2,100,000 |
Number of Gas Utility Customers | 1,200,000 |
Number of Citizens Gas Customers | 17,000 |
Segment_Information_Intersegme
Segment Information (Inter-segment billing) (Details) (Intersegment Eliminations [Member], USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | $868 | $848 | $301 |
Electric [Member] | ' | ' | ' |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | 26 | 29 | 33 |
Gas [Member] | ' | ' | ' |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | 4 | 4 | 2 |
Gas Storage and Pipelines [Member] | ' | ' | ' |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | 3 | 6 | 8 |
Power and Industrial Projects [Member] | ' | ' | ' |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | 816 | 801 | 238 |
Energy Trading [Member] | ' | ' | ' |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | 43 | 43 | 70 |
Corporate and Other [Member] | ' | ' | ' |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | -24 | -37 | -50 |
Discontinued Operations [Member] | ' | ' | ' |
Inter-Segment Revenue [Line Items] | ' | ' | ' |
Revenue, Net | $0 | $2 | $0 |
Segment_Information_Financial_
Segment Information (Financial Data) (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||||||
In Millions, unless otherwise specified | Dec. 31, 2013 | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2012 | Jun. 30, 2012 | Mar. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | $2,533 | $2,387 | $2,225 | $2,516 | $2,349 | $2,190 | $2,013 | $2,239 | $9,661 | $8,791 | $8,858 |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 1,094 | 1,018 | 995 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | -9 | ' | ' |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | 436 | 440 | 488 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | 254 | 286 | 268 |
Net Income Attributable to DTE Energy Company | 124 | 198 | 105 | 234 | 81 | 227 | 146 | 156 | 661 | 610 | 711 |
Total Assets | 25,935 | ' | ' | ' | 26,339 | ' | ' | ' | 25,935 | 26,339 | 26,009 |
Goodwill | 2,018 | ' | ' | ' | 2,018 | ' | ' | ' | 2,018 | 2,018 | 2,020 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 1,876 | 1,820 | 1,484 |
Electric [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 902 | 827 | 818 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | -1 | -1 | -1 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | 268 | 272 | 289 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | 252 | 280 | 265 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | 484 | 483 | 434 |
Total Assets | 17,508 | ' | ' | ' | 17,755 | ' | ' | ' | 17,508 | 17,755 | 17,567 |
Goodwill | 1,208 | ' | ' | ' | 1,208 | ' | ' | ' | 1,208 | 1,208 | 1,208 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 1,325 | 1,230 | 1,203 |
Gas [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 95 | 92 | 89 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | -7 | -7 | -7 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | 58 | 59 | 64 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | 77 | 50 | 60 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | 143 | 115 | 110 |
Total Assets | 3,938 | ' | ' | ' | 4,059 | ' | ' | ' | 3,938 | 4,059 | 4,065 |
Goodwill | 743 | ' | ' | ' | 745 | ' | ' | ' | 743 | 745 | 745 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 209 | 221 | 179 |
Gas Storage and Pipelines [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 23 | 8 | 6 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | -7 | -8 | -5 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | 18 | 8 | 7 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | 45 | 39 | 35 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | 70 | 61 | 57 |
Total Assets | 824 | ' | ' | ' | 668 | ' | ' | ' | 824 | 668 | 538 |
Goodwill | 24 | ' | ' | ' | 22 | ' | ' | ' | 24 | 22 | 22 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 245 | 233 | 16 |
Power and Industrial Projects [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 72 | 65 | 60 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | -6 | -7 | -8 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | 27 | 37 | 32 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | -45 | -44 | 11 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | 66 | 42 | 38 |
Total Assets | 1,067 | ' | ' | ' | 991 | ' | ' | ' | 1,067 | 991 | 789 |
Goodwill | 26 | ' | ' | ' | 26 | ' | ' | ' | 26 | 26 | 26 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 93 | 83 | 56 |
Energy Trading [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 1 | 2 | 3 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | 8 | 8 | 9 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | -38 | 7 | 34 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | -58 | 12 | 52 |
Total Assets | 623 | ' | ' | ' | 629 | ' | ' | ' | 623 | 629 | 612 |
Goodwill | 17 | ' | ' | ' | 17 | ' | ' | ' | 17 | 17 | 17 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 3 | 1 | 1 |
Corporate and Other [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 1 | 1 | 1 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | -51 | -52 | -47 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | 120 | 121 | 145 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | -37 | -46 | -136 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | -44 | -47 | 23 |
Total Assets | 2,945 | ' | ' | ' | 3,074 | ' | ' | ' | 2,945 | 3,074 | 2,605 |
Goodwill | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 1 | 3 | 0 |
Intersegment Eliminations [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | 63 | 65 | 58 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | -63 | -65 | -58 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | -1 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Total Assets | -970 | ' | ' | ' | -837 | ' | ' | ' | -970 | -837 | -485 |
Goodwill | 0 | ' | ' | ' | 0 | ' | ' | ' | 0 | 0 | 0 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | 0 | 0 | 0 |
Segment, Continuing Operations [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Depreciation, Depletion and Amortization | ' | ' | ' | ' | ' | ' | ' | ' | ' | 995 | 977 |
Interest Income | ' | ' | ' | ' | ' | ' | ' | ' | ' | -10 | -10 |
Interest Expense | ' | ' | ' | ' | ' | ' | ' | ' | ' | 440 | 488 |
Income Taxes | ' | ' | ' | ' | ' | ' | ' | ' | ' | 286 | 268 |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | ' | 666 | 714 |
Total Assets | ' | ' | ' | ' | 26,339 | ' | ' | ' | ' | 26,339 | 25,691 |
Goodwill | ' | ' | ' | ' | 2,018 | ' | ' | ' | ' | 2,018 | 2,018 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | ' | 1,771 | 1,455 |
Segment, Discontinued Operations [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Net Income Attributable to DTE Energy Company | ' | ' | ' | ' | ' | ' | ' | ' | ' | -56 | -3 |
Total Assets | ' | ' | ' | ' | 0 | ' | ' | ' | ' | 0 | 318 |
Goodwill | ' | ' | ' | ' | 0 | ' | ' | ' | ' | 0 | 2 |
Capital Expenditures | ' | ' | ' | ' | ' | ' | ' | ' | ' | 49 | 29 |
Operating Segments [Member] | Electric [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | ' | ' | ' | ' | ' | ' | ' | ' | 5,199 | 5,293 | 5,154 |
Operating Segments [Member] | Gas [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | ' | ' | ' | ' | ' | ' | ' | ' | 1,474 | 1,315 | 1,505 |
Operating Segments [Member] | Gas Storage and Pipelines [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | ' | ' | ' | ' | ' | ' | ' | ' | 132 | 96 | 91 |
Operating Segments [Member] | Power and Industrial Projects [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | ' | ' | ' | ' | ' | ' | ' | ' | 1,950 | 1,823 | 1,129 |
Operating Segments [Member] | Energy Trading [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | ' | ' | ' | ' | ' | ' | ' | ' | 1,771 | 1,109 | 1,276 |
Operating Segments [Member] | Corporate and Other [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | ' | ' | ' | ' | ' | ' | ' | ' | 3 | 3 | 4 |
Intersegment Eliminations [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | -868 | -848 | -301 |
Intersegment Eliminations [Member] | Electric [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | -26 | -29 | -33 |
Intersegment Eliminations [Member] | Gas [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | -4 | -4 | -2 |
Intersegment Eliminations [Member] | Gas Storage and Pipelines [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | -3 | -6 | -8 |
Intersegment Eliminations [Member] | Power and Industrial Projects [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | -816 | -801 | -238 |
Intersegment Eliminations [Member] | Energy Trading [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | -43 | -43 | -70 |
Intersegment Eliminations [Member] | Corporate and Other [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | 24 | 37 | 50 |
Intersegment Eliminations [Member] | Segment, Discontinued Operations [Member] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Segment Reporting Information [Line Items] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Revenue, Net | ' | ' | ' | ' | ' | ' | ' | ' | $0 | ($2) | $0 |
Supplementary_Quarterly_Financ2
Supplementary Quarterly Financial Information (Unaudited) (Details) (USD $) | 3 Months Ended | 12 Months Ended | |||||||||
In Millions, except Per Share data, unless otherwise specified | Dec. 31, 2013 | Sep. 30, 2013 | Jun. 30, 2013 | Mar. 31, 2013 | Dec. 31, 2012 | Sep. 30, 2012 | Jun. 30, 2012 | Mar. 31, 2012 | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Quarterly Financial Information Disclosure [Abstract] | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' | ' |
Operating Revenue | $2,533 | $2,387 | $2,225 | $2,516 | $2,349 | $2,190 | $2,013 | $2,239 | $9,661 | $8,791 | $8,858 |
Operating Income (Loss) | 241 | 329 | 223 | 410 | 267 | 406 | 294 | 312 | 1,203 | 1,279 | 1,421 |
Income (Loss) from Continuing Operations Attributable to Parent | ' | ' | ' | ' | 137 | 226 | 147 | 156 | ' | 666 | ' |
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | ' | ' | ' | ' | -56 | 1 | -1 | 0 | 0 | -56 | -3 |
Net Income Attributable to DTE Energy Company | $124 | $198 | $105 | $234 | $81 | $227 | $146 | $156 | $661 | $610 | $711 |
Income (Loss) from Continuing Operations, Per Basic Share | ' | ' | ' | ' | $0.79 | $1.31 | $0.87 | $0.91 | $3.76 | $3.89 | $4.21 |
Income (Loss) from Discontinued Operations, Net of Tax, Per Basic Share | ' | ' | ' | ' | ($0.32) | $0.01 | ($0.01) | $0 | $0 | ($0.33) | ($0.02) |
Total Basic Earnings per Common Share | $0.70 | $1.13 | $0.60 | $1.35 | $0.47 | $1.32 | $0.86 | $0.91 | $3.76 | $3.56 | $4.19 |
Income (Loss) from Continuing Operations, Per Diluted Share | ' | ' | ' | ' | $0.79 | $1.30 | $0.87 | $0.91 | $3.76 | $3.88 | $4.20 |
Income (Loss) from Discontinued Operations, Net of Tax, Per Diluted Share | ' | ' | ' | ' | ($0.32) | $0.01 | ($0.01) | $0 | $0 | ($0.33) | ($0.02) |
Total Diluted Earnings per Common Share | $0.70 | $1.13 | $0.60 | $1.34 | $0.47 | $1.31 | $0.86 | $0.91 | $3.76 | $3.55 | $4.18 |
Valuation_and_Qualifying_Accou2
Valuation and Qualifying Accounts Valuation and Qualifying Accounts (Details) (USD $) | 12 Months Ended | ||
In Millions, unless otherwise specified | Dec. 31, 2013 | Dec. 31, 2012 | Dec. 31, 2011 |
Valuation and Qualifying Accounts [Abstract] | ' | ' | ' |
Balance at Beginning of Period | $62 | $162 | $196 |
Charged to cost and expenses | 94 | 79 | 94 |
Charged to other accounts | 23 | 16 | 18 |
Deductions | -124 | -195 | -146 |
Balance at End of Period | $55 | $62 | $162 |