DTE ELECTRIC CO, 10-Q filed on 4/25/2014
Quarterly Report
Document Entity Information Document
3 Months Ended
Mar. 31, 2014
Entity Registrant Name
DTE ELECTRIC CO 
Entity Central Index Key
0000028385 
Current Fiscal Year End Date
--12-31 
Entity Filer Category
Non-accelerated Filer 
Document Type
10-Q 
Document Period End Date
Mar. 31, 2014 
Document Fiscal Year Focus
2014 
Document Fiscal Period Focus
Q1 
Amendment Flag
false 
Entity Common Stock, Shares Outstanding
138,632,324 
Consolidated Statements of Operations (Unaudited) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Income Statement [Abstract]
 
 
Operating Revenues
$ 1,410 
$ 1,219 
Operating Expenses
 
 
Fuel, purchased power and gas
498 
372 
Operation and maintenance
342 
331 
Depreciation and amortization
228 
212 
Taxes other than income
71 
70 
Asset (gains) losses and reserves, net
0 
(1)
Total operating expenses
1,139 
984 
Operating Income
271 
235 
Other (Income) and Deductions
 
 
Interest expense
63 
66 
Other income
(13)
(15)
Other expenses
7 
6 
Total Other (Income) and Deductions
57 
57 
Income Before Income Taxes
214 
178 
Income Tax Expense
77 
62 
Net Income
$ 137 
$ 116 
Consolidated Statements of Comprehensive Income (Unaudited) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Net Income
$ 137 
$ 116 
Other comprehensive income (loss), net of tax:
 
 
Benefit obligations, net of taxes of $(1) and $—
(1)
0 
Comprehensive income
$ 136 
$ 116 
Consolidated Statements of Comprehensive Income (Parentheticals) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Tax effect on benefit obligations
$ (1)
$ 0 
Consolidated Statements of Cash Flows (Unaudited) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Operating Activities
 
 
Net Income
$ 137 
$ 116 
Adjustments to reconcile net income to net cash from operating activities:
 
 
Depreciation and amortization
228 
212 
Nuclear fuel amortization
5 
9 
Allowance for equity funds used during construction
(5)
(3)
Deferred income taxes
42 
27 
Asset (gains), losses and reserves, net
0 
(1)
Changes in assets and liabilities:
 
 
Accounts receivable, net
6 
(3)
Inventories
55 
52 
Accounts payable
73 
(17)
Regulatory assets and liabilities
(135)
163 
Accrued pension liability — affiliates
(20)
(92)
Accrued postretirement liability — affiliates
(15)
(125)
Other assets
(28)
(31)
Other liabilities
(31)
(66)
Net cash from operating activities
312 
241 
Investing Activities
 
 
Plant and equipment expenditures
(354)
(255)
Restricted cash for debt redemption, principally Securitization
65 
57 
Notes receivable from affiliate
200 
0 
Proceeds from sale of nuclear decommissioning trust fund assets
271 
136 
Investments in nuclear decommissioning trust funds
(275)
(140)
Other Investments
8 
6 
Net cash used for investing activities
(101)
(208)
Financing Activities
 
 
Issuance of long-term debt, net of issuance costs
0 
372 
Redemption of long-term debt
(113)
(139)
Short-term borrowings - other
0 
(130)
Short-term borrowings - Affiliate
5 
(29)
Dividends on common stock
(93)
(85)
Other
(3)
(3)
Net cash used for financing activities
(204)
(14)
Net Increase (Decrease) in Cash and Cash Equivalents
7 
19 
Cash and Cash Equivalents at Beginning of Period
27 
 
Cash and Cash Equivalents at End of Period
34 
 
Supplemental Disclosure of Non-Cash Investing and Financing Activities
 
 
Plant and equipment expenditures in accounts payable
$ 176 
$ 106 
Consolidated Statements of Financial Position (Unaudited) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Current Assets
 
 
Cash and cash equivalents
$ 34 
$ 27 
Restricted cash, principally Securitization
36 
100 
Accounts receivable (less allowance for doubtful accounts of $28 and $28, respectively)
 
 
Customer
724 
723 
Affiliates
1 
24 
Other
39 
24 
Inventories
 
 
Fuel
135 
188 
Materials and supplies
213 
215 
Notes receivable
 
 
Affiliates
0 
200 
Other
12 
2 
Regulatory assets
41 
13 
Prepaid property taxes
76 
41 
Other
28 
27 
Total Current Assets
1,339 
1,584 
Investments
 
 
Nuclear decommissioning trust funds
1,195 
1,191 
Other
160 
160 
Total Investments
1,355 
1,351 
Property
 
 
Property, plant and equipment
18,922 
18,730 
Less accumulated depreciation and amortization
(6,991)
(6,951)
Property, plant and equipment, net
11,931 
11,779 
Other Assets
 
 
Regulatory assets
2,237 
2,275 
Securitized regulatory assets
182 
231 
Intangible assets
39 
41 
Notes receivable
1 
8 
Other
142 
141 
Total Noncurrent Assets
2,601 
2,696 
Total Assets
17,226 
17,410 
Accounts payable
 
 
Affiliates
108 
60 
Other
395 
424 
Accrued interest
65 
61 
Current portion long-term debt, including capital leases
675 
504 
Regulatory liabilities
171 
278 
Deferred income taxes
97 
91 
Short-term borrowings
 
 
Affiliates
63 
58 
Other
150 
177 
Total Current Liabilities
1,724 
1,653 
Long-Term Debt (net of current portion)
 
 
Mortgage bonds, notes and other
4,362 
4,540 
Securitization bonds
0 
105 
Capital lease obligations
0 
4 
Total Long-Term Debt (net of current portion)
4,362 
4,649 
Other Liabilities
 
 
Deferred income taxes
2,842 
2,807 
Regulatory liabilities
354 
386 
Asset retirement obligations
1,691 
1,667 
Unamortized investment tax credit
39 
41 
Nuclear decommissioning
175 
178 
Accrued pension liability — affiliates
685 
705 
Accrued postretirement liability — affiliates
354 
369 
Other
102 
101 
Total Noncurrent Liabilities
6,242 
6,254 
Shareholder’s Equity
 
 
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding
3,596 
3,596 
Retained earnings
1,319 
1,274 
Accumulated other comprehensive income (loss)
(17)
(16)
Total Shareholder's Equity
4,898 
4,854 
Total Liabilities and Shareholder's Equity
$ 17,226 
$ 17,410 
Consolidated Statements of Financial Position (Parentheticals) (USD $)
In Millions, except Share data, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Assets, Current [Abstract]
 
 
Allowance for Doubtful Accounts Receivable
$ 28 
$ 28 
Statement of Stockholders' Equity [Abstract]
 
 
Common Stock, Par or Stated Value Per Share
$ 10 
$ 10 
Common Stock, Shares Authorized
400,000,000 
400,000,000 
Common Stock, Shares, Issued
138,632,324 
138,632,324 
Common Stock, Shares, Outstanding
138,632,324 
138,632,324 
Consolidated Statements of Changes in Equity (Unaudited) (USD $)
In Millions, except Share data
Total
Common Stock [Member]
Additional Paid-in Capital [Member]
Retained Earnings [Member]
Accumulated Other Comprehensive Loss [Member]
Accumulated Defined Benefit Plans Adjustment [Member]
Beginning Balance at Dec. 31, 2013
$ 4,854 
$ 1,386 
$ 2,210 
$ 1,274 
$ (16)
 
Beginning Balance, shares at Dec. 31, 2013
138,632,324 
138,632,000 
 
 
 
 
Net Income
137 
 
 
137 
 
 
Dividends declared on common stock
(93)
 
 
(93)
 
 
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax
(1)
 
 
 
 
(1)
Stockholders' Equity, Other
1 
 
 
1 
 
 
Ending Balance at Mar. 31, 2014
$ 4,898 
$ 1,386 
$ 2,210 
$ 1,319 
$ (17)
 
Ending Balance, shares at Mar. 31, 2014
138,632,324 
138,632,000 
 
 
 
 
Basis of Presentation (Notes)
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]
BASIS OF PRESENTATION

Corporate Structure

DTE Electric is an electric utility engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million customers in southeastern Michigan. DTE Electric is regulated by the MPSC and the FERC. In addition, we are regulated by other federal and state regulatory agencies including the NRC, the EPA and the MDEQ.

References in this report to “we,” “us,” “our” or “Company” are to DTE Electric and its subsidiaries, collectively.

Basis of Presentation

These Consolidated Financial Statements should be read in conjunction with the Notes to Consolidated Financial Statements included in the 2013 Annual Report on Form 10-K.

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.

The Consolidated Financial Statements are unaudited, but in the Company's opinion include all adjustments necessary to present a fair statement of the results for the interim periods. All adjustments are of a normal recurring nature, except as otherwise disclosed in these Consolidated Financial Statements and Notes to Consolidated Financial Statements. Financial results for this interim period are not necessarily indicative of results that may be expected for any other interim period or for the fiscal year ending December 31, 2014.

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 $124 million for the three months ended March 31, 2013. These revisions were needed to properly state the gross purchases and sales activity in the nuclear decommissioning trust fund for the quarter. The total of Net cash used in investing activities for the three months ended March 31, 2013 was 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 plants. 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.

The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of March 31, 2014, 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 related to Securitization is reflected on the Company’s Consolidated Statements of Financial Position.

The following table summarizes the major balance sheet items as of March 31, 2014 and December 31, 2013 restricted for Securitization that are either (1) assets that can be used only to settle their obligations related to Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.

 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
ASSETS
 
 
 
Restricted cash
$
36

 
$
100

Accounts receivable
40

 
34

Securitized regulatory assets
182

 
231

Other assets
3

 
4

 
$
261

 
$
369

 
 
 
 
LIABILITIES
 
 
 
Accounts payable and accrued current liabilities
$
1

 
$
7

Current portion long-term debt
202

 
196

Current regulatory liabilities
41

 
43

Securitization bonds
—

 
105

Other long-term liabilities
8

 
8

 
$
252

 
$
359

Significant Accounting Policies (Note)
Significant Accounting Policies [Text Block]
SIGNIFICANT ACCOUNTING POLICIES

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 three months ended March 31, 2014 reflected changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans.
 
Changes in Accumulated Other Comprehensive Loss by Component (a)
 
Three Months Ended March 31, 2014
 
Net Unrealized Gain/(Loss) on Investments
 
Benefit Obligations
 
Total
 
(In millions)
Beginning balance, December 31, 2013
$
1

 
$
(17
)
 
$
(16
)
Other comprehensive income before reclassifications
—

 
(1
)
 
(1
)
Amounts reclassified from Accumulated other comprehensive income
—

 
—

 
—

Net current-period other comprehensive income
—

 
(1
)
 
(1
)
Ending balance, March 31, 2014
$
1

 
$
(18
)
 
$
(17
)

_______________________________________
(a) All amounts are net of tax.

Intangible Assets

The Company has certain intangible assets relating to emission allowances and renewable energy credits as shown below:
 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
Emission allowances
$
2

 
$
2

Renewable energy credits
50

 
51

 
52

 
53

Less current intangible assets
13

 
12

 
$
39

 
$
41



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.

Income Taxes

The Company's effective tax rate for the three months ended March 31, 2014 was 36% as compared to 35% for the three months ended March 31, 2013.

DTE Electric had an income tax payable of $17 million at March 31, 2014 and an income tax receivable of $23 million at December 31, 2013 due DTE Energy.

The Company had $2 million of unrecognized tax benefits at March 31, 2014, that, if recognized, would favorably impact its effective tax rate. The Company does not anticipate any material changes to the unrecognized tax benefits in the next twelve months.

Stock-Based Compensation

The Company received an allocation of costs from DTE Energy associated with stock-based compensation of $19 million and $13 million for the three months ended March 31, 2014 and March 31, 2013, respectively.
Fair Value (Notes)
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 March 31, 2014 and December 31, 2013. 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 measured and recorded at fair value on a recurring basis as of March 31, 2014 and December 31, 2013:
 
March 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Net Balance
 
Level 1
 
Level 2
 
Level 3
 
Net Balance
 
(In millions)
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash equivalents (a)
$
5

 
$
46

 
$
—

 
$
51

 
$
2

 
$
114

 
$
—

 
$
116

Nuclear decommissioning trusts
764

 
431

 
—

 
1,195

 
779

 
412

 
—

 
1,191

Other investments (b)
88

 
49

 
—

 
137

 
91

 
44

 
—

 
135

Derivative assets — FTRs
—

 
—

 
1

 
1

 
—

 
—

 
3

 
3

Total
$
857

 
$
526

 
$
1

 
$
1,384

 
$
872

 
$
570

 
$
3

 
$
1,445

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
$
5

 
$
46

 
$
1

 
$
52

 
$
2

 
$
114

 
$
3

 
$
119

Noncurrent
852

 
480

 
—

 
1,332

 
870

 
456

 
—

 
1,326

Total Assets
$
857

 
$
526

 
$
1

 
$
1,384

 
$
872

 
$
570

 
$
3

 
$
1,445


_______________________________________
(a)
At March 31, 2014, available-for-sale securities of $51 million, included $36 million and $15 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2013, available-for-sale securities of $116 million, included $100 million and $16 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.
(b)
Available-for-sale equity securities at both March 31, 2014 and December 31, 2013 of $7 million are included in Other investments on the Consolidated Statements of Financial Position.

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.

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 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 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. The Company has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, the Company 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. The Company 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. The Company 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. The Company has obtained an understanding of how these prices are derived. Additionally, the Company 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 table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three months ended March 31, 2014 and 2013:
 
Three Months Ended
March 31,
 
2014
 
2013
 
(In millions)
Net Assets as of beginning of the period
$
3

 
$
1

Change in fair value recorded in regulatory assets/liabilities
4

 
1

Purchases, issuances and settlements:
 
 
 
Settlements
(6
)
 
(1
)
Net Assets as of March 31
$
1

 
$
1

The amount of total gains (losses) included in regulatory assets and liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at March 31, 2014 and 2013
$
—

 
$
1



No transfers between Levels 1, 2 or 3 occurred in the three months ended March 31, 2014 and 2013.

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. The Company has obtained an understanding of how the fair values are derived. The Company 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 as 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 the Company'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 March 31, 2014 and December 31, 2013:
 
March 31, 2014
 
December 31, 2013
 
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
$
13

 
$
—

 
$
—

 
$
13

 
$
10

 
$
—

 
$
—

 
$
10

Notes receivable — affiliates
$
—

 
$
—

 
$
—

 
$
—

 
$
200

 
$
—

 
$
—

 
$
200

Short-term borrowings — affiliates
$
63

 
$
—

 
$
—

 
$
63

 
$
58

 
$
—

 
$
—

 
$
58

Long-term debt
$
5,032

 
$
—

 
$
5,125

 
$
304

 
$
5,146

 
$
—

 
$
5,253

 
$
136



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.

The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
Fermi 2
$
1,174

 
$
1,172

Fermi 1
3

 
3

Low-level radioactive waste
18

 
16

Total
$
1,195

 
$
1,191



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:
 
Three Months Ended
March 31,
 
2014
 
2013
 
(In millions)
Realized gains
$
9

 
$
8

Realized losses
$
(7
)
 
$
(7
)
Proceeds from sales of securities
$
271

 
$
136



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:
 
March 31, 2014
 
December 31, 2013
 
Fair
 
Unrealized
 
Fair
 
Unrealized
 
Value
 
Gains
 
Value
 
Gains
 
(In millions)
Equity securities
$
730

 
$
197

 
$
730

 
$
201

Debt securities
452

 
16

 
442

 
12

Cash and cash equivalents
13

 
—

 
19

 
—

 
$
1,195

 
$
213

 
$
1,191

 
$
213



The debt securities at March 31, 2014 and December 31, 2013 had an average maturity of approximately 7 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 $33 million and $31 million of unrealized losses as Regulatory assets at March 31, 2014 and December 31, 2013, 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 the three months ended March 31, 2014 and 2013 for Fermi 1.

Other Securities

At March 31, 2014 and December 31, 2013, the securities were comprised primarily of money market and equity securities. During the three months ended March 31, 2014 and 2013, 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 March 31, 2014 and 2013 were $2 million and $7 million, respectively.
Financial and Other Derivative Instruments (Notes)
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 and losses from the ineffective portion of any hedge 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 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. 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.

The following table presents the fair value of derivative instruments as of March 31, 2014 and December 31, 2013:
 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
FTRs — Other current assets
$
1

 
$
3

Total derivatives not designated as hedging instrument
$
1

 
$
3



The effects of derivative instruments recoverable through the PSCR mechanism when realized on the Consolidated Statements of Financial Position were $4 million and $1 million in gains related to FTRs recognized in Regulatory liabilities for the three months ended March 31, 2014 and 2013, respectively.

The following represents the cumulative gross volume of derivative contracts outstanding as of March 31, 2014:
Commodity
Number of Units
FTRs (MWh)
16,665

Asset Retirement Obligations (Notes)
Asset Retirement Obligations
ASSET RETIREMENT OBLIGATIONS

A reconciliation of the asset retirement obligations for the three months ended March 31, 2014 follows:
 
(In millions)
Asset retirement obligations at December 31, 2013
$
1,667

Accretion
26

Revision in estimated cash flows
(5
)
Liabilities incurred
3

Asset retirement obligations at March 31, 2014
$
1,691

Regulatory Matters (Notes)
Regulatory Matters
REGULATORY MATTERS

Refundable Revenue Decoupling/ Deferred Gain Amortization

In September 2012, the MPSC approved DTE Electric's accounting application to defer for future amortization the gain resulting from the reversal of the Company's $127 million regulatory liability associated with the operation of the RDM. The approved application provided for the amortization of the regulatory liability to income, at a monthly rate of approximately $10.6 million, beginning January 2014. On April 1, 2014, the MPSC approved DTE Electric's accounting application to suspend the amortization of the RDM regulatory liability as of June 30, 2014 and to complete the amortization over the period January 2015 to June 2015. If DTE Electric's base rates are increased prior to July 1, 2015, the Company will cease amortization and refund to customers the remaining unamortized balance of the regulatory liability.

PSCR 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.

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.

2013 PSCR Year — In March 2014, DTE Electric filed the 2013 PSCR reconciliation calculating a net over-recovery of $54 million that includes an under-recovery of $87 million for the 2012 PSCR year.
Long-Term Debt (Notes)
Long-term Debt [Text Block]
LONG-TERM DEBT

Debt Issuances

In March 2014, DTE Electric agreed to issue $150 million of 4.60%, 30-year mortgage bonds and $100 million of 3.77%, 12-year mortgage bonds to a group of institutional investors in a private placement transaction. The bonds are expected to close and fund in June 2014. Proceeds will be used for the repayment of existing indebtedness and for general corporate purposes.

Debt Redemptions

In 2014, the following debt was redeemed:
Month
 
Type
 
Interest Rate
 
Maturity
 
Amount
 
 
 
 
 
 
 
 
(In millions)
March
 
Mortgage Bonds
 
Various
 
2014
 
$
13

March
 
Securitization Bonds
 
6.62%
 
2014
 
100

 
 
 
 
 
 
 
 
$
113



In April 2014, DTE Electric called $31 million of 2.35% tax exempt revenue bonds and $32 million of 4.65% tax exempt revenue bonds with final maturities of 2024 and 2028, respectively.
Short-Term Credit Arrangements and Borrowings (Notes)
Short-Term Credit Arrangements and Borrowings
SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS

DTE Electric has a $300 million unsecured revolving credit agreement with a syndicate of 19 banks that can be used for general corporate borrowings, but is intended to provide liquidity support for the Company's commercial paper program. No one bank provides more than 8.7% of the commitment in the facility. Borrowings under the facility are available at prevailing short-term interest rates. The facility will expire in April 2018. There were no amounts outstanding against the facility at March 31, 2014 and December 31, 2013.

The agreement requires the Company to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. In the agreement, “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 and nonrecourse and junior subordinated 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 March 31, 2014, the total funded debt to total capitalization ratio for DTE Electric was 0.50 to 1 and is in compliance with this financial covenant.
Commitments and Contingencies (Notes)
Commitments and Contingencies
COMMITMENTS AND CONTINGENCIES

Environmental

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, required 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 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 by the second quarter of 2014. Notwithstanding the appeal filed with the Supreme Court, the EPA and a number of states, including Michigan, 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 all relevant 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. On March 3, 2014, the U.S. District Court judge granted again DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. On April 3, 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2 and 3, Belle River Units 1 and 2, Trenton Channel Unit 9 and River Rouge Unit 3.
DTE Energy and DTE Electric believe that all the plants and generating units identified by the EPA and the Sierra Club 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.

In March 2013, the Sierra Club filed suit against DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,499 six-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin the Company 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 six-minute periods from 1,499 to 1,139. DTE Electric filed an answer to the amended complaint on March 11, 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 December 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 March 31, 2014 and at December 31, 2013, the Company had $9 million and $8 million accrued for remediation, respectively. Any significant 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 the likelihood of a material change to 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 the coal fired power plant. 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. The rules are expected to be finalized by December 2014. It is not possible to quantify the impact of those expected rulemakings at this time.

Other

In December 2012, 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). Capital costs for pollution controls and/or 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 Electric 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. The state implementation plan process is in the information gathering stage, and DTE Electric is unable to estimate any required emissions reductions at this time.

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.

As of April 1, 2014, DTE Electric has $1.5 billion in primary coverage and $1.25 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. The total limit for property damage for non-nuclear events is $2 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 $35 million per event if the loss associated with any one event at any insured 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. In March 2014, the COA denied DOE's petition for rehearing. DTE Electric continues to pay fees to the U.S. government's nuclear waste fund pending further developments in this proceeding.

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.

Labor Contracts

There are several bargaining units for the Company's approximately 2,600 represented employees. The majority of the represented employees are under contracts that expire in 2016 and 2017.

Purchase Commitments

As of March 31, 2014, 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 $2.6 billion from 2014 through 2033.

The Company also estimates that 2014 capital expenditures will be approximately $1.6 billion. The Company has made certain commitments in connection with expected capital expenditures.

Bankruptcies

The Company purchases and sells electricity from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail 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 provides 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 Note 6 for a discussion of contingencies related to Regulatory Matters.
Retirement Benefits and Trusteed Assets (Notes)
Retirement Benefits and Trusted Assets Disclosure [Text Block]
RETIREMENT BENEFITS AND TRUSTEED ASSETS

The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:
 
Pension Benefits
 
Other Postretirement Benefits
 
2014
 
2013
 
2014
 
2013
Three Months Ended March 31
(In millions)
Service cost
$
17

 
$
19

 
$
7

 
$
12

Interest cost
40

 
36

 
17

 
18

Expected return on plan assets
(48
)
 
(46
)
 
(21
)
 
(18
)
Amortization of:
 
 
 
 
 
 
 
Net actuarial loss
27

 
36

 
3

 
12

Prior service credit
—

 
—

 
(27
)
 
(17
)
Net periodic benefit cost (credit)
$
36

 
$
45

 
$
(21
)
 
$
7



Pension and Other Postretirement Contributions

During the first three months of 2014, the Company contributed $30 million to its pension plans. At the discretion of management, and depending upon financial market conditions, the Company may make up to an additional $115 million contribution to its pension plans in 2014.

At the discretion of management, the Company may make up to a $120 million contribution to its other postretirement benefit plans in 2014.
Significant Accounting Policies (Policies)
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 plants. 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.

The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of March 31, 2014, 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 related to Securitization is reflected on the Company’s Consolidated Statements of Financial Position.
Comprehensive Income, Policy [Policy Text Block] 
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 three months ended March 31, 2014 reflected changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans.
Intangible Assets, Finite-Lived, Policy [Policy Text Block] 
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.
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 March 31, 2014 and December 31, 2013. 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 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 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. The Company has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, the Company 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] 
The Company 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. The Company 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. The Company has obtained an understanding of how these prices are derived. Additionally, the Company 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 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. The Company has obtained an understanding of how the fair values are derived. The Company 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 as 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 the Company'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 and losses from the ineffective portion of any hedge 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 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. 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.
Basis of Presentation (Tables)
Schedule of Variable Interest Entities [Table Text Block]
The following table summarizes the major balance sheet items as of March 31, 2014 and December 31, 2013 restricted for Securitization that are either (1) assets that can be used only to settle their obligations related to Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.

 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
ASSETS
 
 
 
Restricted cash
$
36

 
$
100

Accounts receivable
40

 
34

Securitized regulatory assets
182

 
231

Other assets
3

 
4

 
$
261

 
$
369

 
 
 
 
LIABILITIES
 
 
 
Accounts payable and accrued current liabilities
$
1

 
$
7

Current portion long-term debt
202

 
196

Current regulatory liabilities
41

 
43

Securitization bonds
—

 
105

Other long-term liabilities
8

 
8

 
$
252

 
$
359

Significant Accounting Policies (Tables)
Schedule of Accumulated Other Comprehensive Income (Loss) [Table Text Block] 
As shown in the following tables, amounts recorded to accumulated other comprehensive loss for the three months ended March 31, 2014 reflected changes in benefit obligations, consisting of deferred actuarial losses, prior service costs and transition amounts related to pension and other postretirement benefit plans.
 
Changes in Accumulated Other Comprehensive Loss by Component (a)
 
Three Months Ended March 31, 2014
 
Net Unrealized Gain/(Loss) on Investments
 
Benefit Obligations
 
Total
 
(In millions)
Beginning balance, December 31, 2013
$
1

 
$
(17
)
 
$
(16
)
Other comprehensive income before reclassifications
—

 
(1
)
 
(1
)
Amounts reclassified from Accumulated other comprehensive income
—

 
—

 
—

Net current-period other comprehensive income
—

 
(1
)
 
(1
)
Ending balance, March 31, 2014
$
1

 
$
(18
)
 
$
(17
)

_______________________________________
(a) All amounts are net of tax.
Schedule of Finite-Lived Intangible Assets [Table Text Block] 
The Company has certain intangible assets relating to emission allowances and renewable energy credits as shown below:
 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
Emission allowances
$
2

 
$
2

Renewable energy credits
50

 
51

 
52

 
53

Less current intangible assets
13

 
12

 
$
39

 
$
41

Fair Value (Tables)
Schedule of Fair Value, Assets and liabilities measured on a recurring basis [Table Text Block] 
The following table presents assets measured and recorded at fair value on a recurring basis as of March 31, 2014 and December 31, 2013:
 
March 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Net Balance
 
Level 1
 
Level 2
 
Level 3
 
Net Balance
 
(In millions)
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash equivalents (a)
$
5

 
$
46

 
$
—

 
$
51

 
$
2

 
$
114

 
$
—

 
$
116

Nuclear decommissioning trusts
764

 
431

 
—

 
1,195

 
779

 
412

 
—

 
1,191

Other investments (b)
88

 
49

 
—

 
137

 
91

 
44

 
—

 
135

Derivative assets — FTRs
—

 
—

 
1

 
1

 
—

 
—

 
3

 
3

Total
$
857

 
$
526

 
$
1

 
$
1,384

 
$
872

 
$
570

 
$
3

 
$
1,445

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
$
5

 
$
46

 
$
1

 
$
52

 
$
2

 
$
114

 
$
3

 
$
119

Noncurrent
852

 
480

 
—

 
1,332

 
870

 
456

 
—

 
1,326

Total Assets
$
857

 
$
526

 
$
1

 
$
1,384

 
$
872

 
$
570

 
$
3

 
$
1,445


_______________________________________
(a)
At March 31, 2014, available-for-sale securities of $51 million, included $36 million and $15 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2013, available-for-sale securities of $116 million, included $100 million and $16 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.
(b)
Available-for-sale equity securities at both March 31, 2014 and December 31, 2013 of $7 million are included in Other investments on the Consolidated Statements of Financial Position.
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block] 
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the three months ended March 31, 2014 and 2013:
 
Three Months Ended
March 31,
 
2014
 
2013
 
(In millions)
Net Assets as of beginning of the period
$
3

 
$
1

Change in fair value recorded in regulatory assets/liabilities
4

 
1

Purchases, issuances and settlements:
 
 
 
Settlements
(6
)
 
(1
)
Net Assets as of March 31
$
1

 
$
1

The amount of total gains (losses) included in regulatory assets and liabilities attributed to the change in unrealized gains (losses) related to assets and liabilities held at March 31, 2014 and 2013
$
—

 
$
1

Fair Value of Financial Instruments [Table Text Block] 
The following table presents the carrying amount and fair value of financial instruments as of March 31, 2014 and December 31, 2013:
 
March 31, 2014
 
December 31, 2013
 
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
$
13

 
$
—

 
$
—

 
$
13

 
$
10

 
$
—

 
$
—

 
$
10

Notes receivable — affiliates
$
—

 
$
—

 
$
—

 
$
—

 
$
200

 
$
—

 
$
—

 
$
200

Short-term borrowings — affiliates
$
63

 
$
—

 
$
—

 
$
63

 
$
58

 
$
—

 
$
—

 
$
58

Long-term debt
$
5,032

 
$
—

 
$
5,125

 
$
304

 
$
5,146

 
$
—

 
$
5,253

 
$
136

Fair Value of Nuclear Decommissioning Trust Fund Assets [Table Text Block] 
The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
Fermi 2
$
1,174

 
$
1,172

Fermi 1
3

 
3

Low-level radioactive waste
18

 
16

Total
$
1,195

 
$
1,191

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:
 
Three Months Ended
March 31,
 
2014
 
2013
 
(In millions)
Realized gains
$
9

 
$
8

Realized losses
$
(7
)
 
$
(7
)
Proceeds from sales of securities
$
271

 
$
136

Fair Value and Unrealized Gains for Nuclear Decommissioning Trust Fund [Table Text Block] 
The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds:
 
March 31, 2014
 
December 31, 2013
 
Fair
 
Unrealized
 
Fair
 
Unrealized
 
Value
 
Gains
 
Value
 
Gains
 
(In millions)
Equity securities
$
730

 
$
197

 
$
730

 
$
201

Debt securities
452

 
16

 
442

 
12

Cash and cash equivalents
13

 
—

 
19

 
—

 
$
1,195

 
$
213

 
$
1,191

 
$
213

Financial and Other Derivative Instruments (Tables)
Fair value of derivative instruments 
The following table presents the fair value of derivative instruments as of March 31, 2014 and December 31, 2013:
 
March 31,
 
December 31,
 
2014
 
2013
 
(In millions)
FTRs — Other current assets
$
1

 
$
3

Total derivatives not designated as hedging instrument
$
1

 
$
3

Volume of Commodity Contracts [Table Text Block] 
The following represents the cumulative gross volume of derivative contracts outstanding as of March 31, 2014:
Commodity
Number of Units
FTRs (MWh)
16,665

Asset Retirement Obligations (Tables)
Schedule of Change in Asset Retirement Obligation [Table Text Block]
A reconciliation of the asset retirement obligations for the three months ended March 31, 2014 follows:
 
(In millions)
Asset retirement obligations at December 31, 2013
$
1,667

Accretion
26

Revision in estimated cash flows
(5
)
Liabilities incurred
3

Asset retirement obligations at March 31, 2014
$
1,691

Long-Term Debt (Tables)
Schedule of Issued Debt [Table Text Block] 
In March 2014, DTE Electric agreed to issue $150 million of 4.60%, 30-year mortgage bonds and $100 million of 3.77%, 12-year mortgage bonds to a group of institutional investors in a private placement transaction. The bonds are expected to close and fund in June 2014. Proceeds will be used for the repayment of existing indebtedness and for general corporate purposes.

Schedule of Extinguishment of Debt [Table Text Block] 
In 2014, the following debt was redeemed:
Month
 
Type
 
Interest Rate
 
Maturity
 
Amount
 
 
 
 
 
 
 
 
(In millions)
March
 
Mortgage Bonds
 
Various
 
2014
 
$
13

March
 
Securitization Bonds
 
6.62%
 
2014
 
100

 
 
 
 
 
 
 
 
$
113

Retirement Benefits and Trusted Assets (Tables)
Schedule of Defined Benefit Plans Disclosures [Table Text Block]
The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:
 
Pension Benefits
 
Other Postretirement Benefits
 
2014
 
2013
 
2014
 
2013
Three Months Ended March 31
(In millions)
Service cost
$
17

 
$
19

 
$
7

 
$
12

Interest cost
40

 
36

 
17

 
18

Expected return on plan assets
(48
)
 
(46
)
 
(21
)
 
(18
)
Amortization of:
 
 
 
 
 
 
 
Net actuarial loss
27

 
36

 
3

 
12

Prior service credit
—

 
—

 
(27
)
 
(17
)
Net periodic benefit cost (credit)
$
36

 
$
45

 
$
(21
)
 
$
7



Basis of Presentation (Details Textuals) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
customers
Mar. 31, 2013
Proceeds from sale of nuclear decommissioning trust funds [Member]
Mar. 31, 2013
Investment in nuclear decommissioning trust funds [Member]
Organization, Consolidation and Presentation of Financial Statements [Line Items]
 
 
 
Number of Electric Customers
2,100,000 
 
 
Prior Period Reclassification Adjustment
 
$ (124)
$ 124 
Significant Potential Exposure to Loss Due to VIE Long-Term Purchase Contracts
$ 0 
 
 
Basis of Presentation (Details) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Assets [Abstract]
 
 
Restricted cash
$ 36 
$ 100 
Accounts receivable
724 
723 
Securitized regulatory assets
182 
231 
Other assets
142 
141 
Total Assets
17,226 
17,410 
Liabilities [Abstract]
 
 
Current portion long-term debt
675 
504 
Current regulatory liabilities
171 
278 
Securitization bonds
0 
105 
Other long term liabilities
102 
101 
Variable Interest Entity Securitization [Member]
 
 
Assets [Abstract]
 
 
Restricted cash
36 
100 
Accounts receivable
40 
34 
Securitized regulatory assets
182 
231 
Other assets
3 
4 
Total Assets
261 
369 
Liabilities [Abstract]
 
 
Accounts payable and accrued current liabilities
1 
7 
Current portion long-term debt
202 
196 
Current regulatory liabilities
41 
43 
Securitization bonds
0 
105 
Other long term liabilities
8 
8 
Total Liabilities
$ 252 
$ 359 
Significant Accounting Policies (Details Textuals) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Dec. 31, 2013
Significant Accounting Policies [Line Items]
 
 
 
Effective Income Tax Rate Reconciliation, Percent
36.00% 
35.00% 
 
Unrecognized Tax Benefits
$ 2 
 
 
DTE Energy [Member]
 
 
 
Significant Accounting Policies [Line Items]
 
 
 
Income Taxes Receivable due from DTE Energy
17 
 
23 
Allocated Share-based Compensation Expense from DTE Energy
$ 19 
$ 13 
 
Significant Accounting Policies (Accumulated Other Comprehensive Income (Loss)) (Details) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Accumulated Other Comprehensive Income (Loss) [Line Items]
 
Accumulated Other Comprehensive Income (Loss), Net of Tax
$ (16)
Other Comprehensive Income Before Reclassifications
(1)
Amounts Reclassified From Accumulated Other Comprehensive Income
0 
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax
(1)
Accumulated Other Comprehensive Income (Loss), Net of Tax
(17)
Accumulated Net Unrealized Investment Gain (Loss) [Member]
 
Accumulated Other Comprehensive Income (Loss) [Line Items]
 
Accumulated Other Comprehensive Income (Loss), Net of Tax
1 
Other Comprehensive Income Before Reclassifications
0 
Amounts Reclassified From Accumulated Other Comprehensive Income
0 
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax
0 
Accumulated Other Comprehensive Income (Loss), Net of Tax
1 
Accumulated Defined Benefit Plans Adjustment [Member]
 
Accumulated Other Comprehensive Income (Loss) [Line Items]
 
Accumulated Other Comprehensive Income (Loss), Net of Tax
(17)
Other Comprehensive Income Before Reclassifications
(1)
Amounts Reclassified From Accumulated Other Comprehensive Income
0 
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax
(1)
Accumulated Other Comprehensive Income (Loss), Net of Tax
$ (18)
Significant Accounting Policies (Intangible Assets) (Details) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
 
 
Finite-Lived Intangible Assets, Gross
$ 52 
$ 53 
Less Current Intangible Assets
13 
12 
Finite-Lived Intangible Assets, Net
39 
41 
Emission Allowances [Member]
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
Finite-Lived Intangible Assets, Gross
2 
2 
Renewable Energy Credits [Member]
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
Finite-Lived Intangible Assets, Gross
$ 50 
$ 51 
Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Derivative assets - FTRs
$ 1 
$ 3 
Fair Value, Measurements, Recurring [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Cash equivalents
51 
116 
Nuclear decommissioning trusts
1,195 
1,191 
Other investments
137 
135 
Derivative assets - FTRs
1 
3 
Assets
1,384 
1,445 
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 1 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Cash equivalents
5 
2 
Nuclear decommissioning trusts
764 
779 
Other investments
88 
91 
Derivative assets - FTRs
0 
0 
Assets
857 
872 
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 2 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Cash equivalents
46 
114 
Nuclear decommissioning trusts
431 
412 
Other investments
49 
44 
Derivative assets - FTRs
0 
0 
Assets
526 
570 
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 3 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Cash equivalents
0 
0 
Nuclear decommissioning trusts
0 
0 
Other investments
0 
0 
Derivative assets - FTRs
1 
3 
Assets
1 
3 
Current Asset [Member] |
Fair Value, Measurements, Recurring [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
52 
119 
Current Asset [Member] |
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 1 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
5 
2 
Current Asset [Member] |
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 2 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
46 
114 
Current Asset [Member] |
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 3 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
1 
3 
Noncurrent Asset [Member] |
Fair Value, Measurements, Recurring [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
1,332 
1,326 
Noncurrent Asset [Member] |
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 1 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
852 
870 
Noncurrent Asset [Member] |
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 2 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
480 
456 
Noncurrent Asset [Member] |
Fair Value, Measurements, Recurring [Member] |
Fair Value, Inputs, Level 3 [Member]
 
 
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
 
 
Assets
$ 0 
$ 0 
Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis
 
 
Beginning Balance
$ 3 
$ 1 
Recorded in regulatory assets/liabilities
4 
1 
Purchases issuances and settlements [Abstract]
 
 
Settlements
(6)
(1)
Ending Balance
1 
1 
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Period Increase (Decrease)
$ 0 
$ 1 
Fair Value (Fair Value of Financial Instruments) (Details) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Fair Value of Financial Instruments [Line Items]
 
 
Notes receivable, excluding capital leases Carrying Amount
$ 13 
$ 10 
Notes receivable - affiliates Current
0 
200 
Long-term debt Carrying Amount
5,032 
5,146 
Fair Value, Inputs, Level 1 [Member]
 
 
Fair Value of Financial Instruments [Line Items]
 
 
Notes receivable, excluding capital leases Fair Value
0 
0 
Notes receivable - affiliates, fair value
0 
0 
Long-term debt Fair Value
0 
0 
Fair Value, Inputs, Level 2 [Member]
 
 
Fair Value of Financial Instruments [Line Items]
 
 
Notes receivable, excluding capital leases Fair Value
0 
0 
Notes receivable - affiliates, fair value
0 
0 
Long-term debt Fair Value
5,125 
5,253 
Fair Value, Inputs, Level 3 [Member]
 
 
Fair Value of Financial Instruments [Line Items]
 
 
Notes receivable, excluding capital leases Fair Value
13 
10 
Notes receivable - affiliates, fair value
0 
200 
Long-term debt Fair Value
304 
136 
Affiliates [Member]
 
 
Fair Value of Financial Instruments [Line Items]
 
 
Short-term borrowings - affiliates Carrying Amount
63 
58 
Affiliates [Member] |
Fair Value, Inputs, Level 1 [Member]
 
 
Fair Value of Financial Instruments [Line Items]
 
 
Short-term Debt, Fair Value
0 
0 
Affiliates [Member] |
Fair Value, Inputs, Level 2 [Member]
 
 
Fair Value of Financial Instruments [Line Items]
 
 
Short-term Debt, Fair Value
0 
0 
Affiliates [Member] |
Fair Value, Inputs, Level 3 [Member]
 
 
Fair Value of Financial Instruments [Line Items]
 
 
Short-term Debt, Fair Value
$ 63 
$ 58 
Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
Decommissioning Fund Investments
$ 1,195 
$ 1,191 
Fermi 2 [Member]
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
Decommissioning Fund Investments
1,174 
1,172 
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
18 
16 
Nuclear Decommissioning Trust Fund [Member]
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
Decommissioning Fund Investments
$ 1,195 
$ 1,191 
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 $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Nuclear Decommissioning Trust Fund [Member]
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
Realized gains
$ 9 
$ 8 
Realized losses
(7)
(7)
Proceeds from sales of securities
$ 271 
$ 136 
Fair Value (Fair Value and Unrealized Gains for the Nuclear Decommissioning Trust Funds) (Details) (Nuclear Decommissioning Trust Fund [Member], USD $)
In Millions, unless otherwise specified
3 Months Ended 12 Months Ended
Mar. 31, 2014
Dec. 31, 2013
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
Cash equivalents
$ 13 
$ 19 
Nuclear decommissioning trusts
1,195 
1,191 
Unrealized Gains
213 
213 
Equity securities [Member]
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
Equity Securities
730 
730 
Unrealized Gains
197 
201 
Debt securities [Member]
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
Debt securities
452 
442 
Unrealized Gains
16 
12 
Cash and cash equivalents [Member]
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
Unrealized Gains
$ 0 
$ 0 
Fair Value (Details Textuals) (USD $)
3 Months Ended 3 Months Ended 12 Months Ended 3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Mar. 31, 2014
Fair Value, Measurements, Recurring [Member]
Dec. 31, 2013
Fair Value, Measurements, Recurring [Member]
Mar. 31, 2014
Restricted Assets [Member]
Fair Value, Measurements, Recurring [Member]
Dec. 31, 2013
Restricted Assets [Member]
Fair Value, Measurements, Recurring [Member]
Mar. 31, 2014
Other Investments [Member]
Fair Value, Measurements, Recurring [Member]
Dec. 31, 2013
Other Investments [Member]
Fair Value, Measurements, Recurring [Member]
Mar. 31, 2014
Other Investments [Member]
Fair Value, Measurements, Recurring [Member]
Equity [Member]
Dec. 31, 2013
Other Investments [Member]
Fair Value, Measurements, Recurring [Member]
Equity [Member]
Mar. 31, 2014
Nuclear Decommissioning Trust Fund [Member]
Dec. 31, 2013
Nuclear Decommissioning Trust Fund [Member]
Mar. 31, 2014
Fermi 2 [Member]
Dec. 31, 2013
Fermi 2 [Member]
Mar. 31, 2014
Fermi 1 [Member]
Mar. 31, 2013
Fermi 1 [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash equivalents
 
 
$ 51,000,000 
$ 116,000,000 
$ 36,000,000 
$ 100,000,000 
$ 15,000,000 
$ 16,000,000 
 
 
$ 13,000,000 
$ 19,000,000 
 
 
 
 
Available-for-sale Securities, Fair Value Disclosure
 
 
 
 
 
 
 
 
7,000,000 
7,000,000 
 
 
 
 
 
 
Transfers Between Levels 1, 2 and 3
0 
0 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Average Maturity of Debt Securities
 
 
 
 
 
 
 
 
 
 
7 years 
7 years 
 
 
 
 
Unrealized losses recognized as regulatory assets
 
 
 
 
 
 
 
 
 
 
 
 
33,000,000 
31,000,000 
 
 
Other than Temporary Impairment Losses, Investments, Portion Recognized in Earnings, Net
 
 
 
 
 
 
 
 
 
 
 
 
 
 
0 
0 
Unrealized Losses on Available for Sale Securities
0 
0 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Trading Securities, Change in Unrealized Holding Gain (Loss)
$ 2,000,000 
$ 7,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
Derivatives not designated as hedging instruments:
 
 
Derivative Asset Fair Value Gross Asset
$ 1 
$ 3 
Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts) (Details) (FTR [Member])
Mar. 31, 2014
dte.volumes
FTR [Member]
 
Derivative [Line Items]
 
Investment Contract Volume
16,665 
Financial and Other Derivative Instruments (Details Textuals) (FTR [Member], USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
FTR [Member]
 
 
Derivative [Line Items]
 
 
Effect of Derivative Instruments Recoverable Through PSCR Mechanism
$ 4 
$ 1 
Asset Retirement Obligations (Details) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
 
Asset retirement obligations beginning of period
$ 1,667 
Accretion
26 
Revision in estimated cash flows
(5)
Liabilities Incurred
3 
Asset retirement obligations end of period
$ 1,691 
Regulatory Matters (Details Textuals) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Jan. 2, 2014
Sep. 30, 2012
Jul. 30, 2012
Public Utilities, General Disclosures [Abstract]
 
 
 
 
 
Defer the Reversal of RDM Liability
 
 
 
$ 127 
 
Monthly Amount to Amortize from Liability to Income
 
 
10.6 
 
 
PSCR Under-Recovery from Two Plan Years Prior
 
87 
 
 
 
PSCR under-recovery from Three Plan Years Prior
 
148 
 
 
 
Fermi 2 Production Level of Full Capacity
 
 
 
 
68.00% 
Maximum of challenged Fermi 2 outage charges
32 
 
 
 
 
PSCR over-recovery from One Plan Year Prior
$ 54 
 
 
 
 
Long-Term Debt (Debt Redemptions) (Details) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Extinguishment of Debt [Line Items]
 
Extinguishment of Debt, Amount
$ 113 
Securitization Bonds [Member]
 
Extinguishment of Debt [Line Items]
 
Debt Instrument, Interest Rate, Stated Percentage
6.62% 
Extinguishment of Debt, Amount
100 
Mortgages [Member]
 
Extinguishment of Debt [Line Items]
 
Extinguishment of Debt, Amount
$ 13 
Long-Term Debt Long-Term Debt (Detail Textuals) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Thirty Years [Member]
 
Debt Instrument [Line Items]
 
Debt Instrument, Face Amount, Future Issuance
$ 150 
Future Debt Instrument, Interest Rate, Stated Percentage
4.60% 
Twelve Years [Member]
 
Debt Instrument [Line Items]
 
Debt Instrument, Face Amount, Future Issuance
100 
Future Debt Instrument, Interest Rate, Stated Percentage
3.77% 
Final Maturity of 2024 [Member]
 
Debt Instrument [Line Items]
 
Future Extinguishment of Debt, Amount
31 
Debt Instrument, Interest Rate, Stated Percentage
2.35% 
Final Maturity of 2028 [Member]
 
Debt Instrument [Line Items]
 
Future Extinguishment of Debt, Amount
$ 32 
Debt Instrument, Interest Rate, Stated Percentage
4.65% 
Short-Term Credit Arrangements and Borrowings (Details Textuals) (USD $)
In Millions, unless otherwise specified
Mar. 31, 2014
Dec. 31, 2013
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 
 
Total Funded Debt to Total Capitalization Ratio
0.50 
 
Commercial Paper [Member]
 
 
Short-term Debt [Line Items]
 
 
Line of Credit Facility, Amount Outstanding
$ 0 
$ 0 
Unsecured revolving credit facility expiring April 2018 [Member] |
Revolving Credit Facility [Member]
 
 
Short-term Debt [Line Items]
 
 
Line of Credit Facility, Maximum Borrowing Capacity
$ 300 
 
Commitments and Contingencies (Details Textuals) (USD $)
3 Months Ended 12 Months Ended
Mar. 31, 2014
facilities
dte_instances
employees
Dec. 31, 2013
Mar. 31, 2013
dte_instances
Dec. 31, 2013
Jul. 18, 2013
Commitments and Contingencies Disclosure [Abstract]
 
 
 
 
 
Environmental Capital Expenditures Through Prior Year End
 
 
 
$ 2,000,000,000 
 
Environmental Capital Expenditures in Current Year
280,000,000 
 
 
 
 
Environmental Capital Expenditures In Future Years
1,200,000,000 
 
 
 
 
EPA is Alleging DTE Electric Power Plants Violated New Source Performance Standards
5 
 
 
 
 
Number of NOVs/FOVs currently being discussed with the EPA
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 
 
 
Period of excess opacity of air emissions at alleged facilities
 
 
6 minutes 
 
 
Number of Former MGP Sites
3 
 
 
 
 
Accrual for Environmental Loss Contingencies
9,000,000 
8,000,000 
 
8,000,000 
 
Number of Options to Regulate Coal Ash Residue
2 
 
 
 
 
EPA Sulfur Dioxide Ambient AIr Quality Standard
1 hour 
 
 
 
 
Waiting Period of Policy
P12W 
 
 
 
 
Insurance Coverage for Extra Expense When to Necessitate Power Plant when Unavailable
490,000,000 
 
 
 
 
Period of Coverage of Policy for Extra Expenses
P3Y 
 
 
 
 
Primary Coverage
1,500,000,000 
 
 
 
 
Coverage for Stabilization Decontamination Debris Removal Repair and Replacement of Property and Decommissioning
1,250,000,000 
 
 
 
 
Combined Coverage Limit for Total Property Damage
2,750,000,000 
 
 
 
 
Insurance Deductible for Nuclear Power Plant
1,000,000 
 
 
 
 
Total Limit for Property Damage for Non-Nuclear Event
2,000,000,000 
 
 
 
 
Limit for Property Damage for Non-Nuclear Events Aggregate of Extra Expenses
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 Terrorism Loss
3,200,000,000 
 
 
 
 
Amount per Event Loss Associated with Nuclear Power Plants
35,000,000 
 
 
 
 
Maintenance of Public Liability Insurance for Nuclear Power Plants
375,000,000 
 
 
 
 
Aggregate Limit of Liabilities Arises From Terrorist Act Outside Scope of Trials Subject to One Industry
300,000,000 
 
 
 
 
Maximum Deferred premium charges levied 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 
 
 
 
 
Payment from the DOE for Delaying Acceptance of Spent Nuclear Fuel
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 
 
90 days 
 
Number of Represented Employees
2,600 
 
 
 
 
Long-term Purchase Commitment, Amount
2,600,000,000 
 
 
 
 
Estimated future capital expenditures for remainder of the year
1,600,000,000 
 
 
 
 
Bankruptcy Claims, Amount of Claims under Review by Management
 
 
 
 
$ 20,000,000 
Retirement Benefits and Trusteed Assets Retirement Benefits and Trusted Assets (Details) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Mar. 31, 2013
Pension Plans, Defined Benefit [Member]
 
 
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
 
 
Service Cost
$ 17 
$ 19 
Interest Cost
40 
36 
Expected Return on Plan Assets
(48)
(46)
Amortization of Net Acutuarial Losses
27 
36 
Amortization of Prior Service Cost (Credit)
0 
0 
Net Periodic Benefit Cost
36 
45 
Other Postretirement Benefit Plans, Defined Benefit [Member]
 
 
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
 
 
Service Cost
7 
12 
Interest Cost
17 
18 
Expected Return on Plan Assets
(21)
(18)
Amortization of Net Acutuarial Losses
3 
12 
Amortization of Prior Service Cost (Credit)
(27)
(17)
Net Periodic Benefit Cost
$ (21)
$ 7 
Retirement Benefits and Trusteed Assets Retirement Benefits and Trusteed Assets (Details Textuals) (USD $)
In Millions, unless otherwise specified
3 Months Ended
Mar. 31, 2014
Pension Plans, Defined Benefit [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Estimated Future Employer Contributions in Current Fiscal Year
$ 115 
Other Postretirement Benefit Plans, Defined Benefit [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Estimated Future Employer Contributions in Current Fiscal Year
120 
Qualified Plans [Member] |
Pension Plans, Defined Benefit [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Contributions by Employer
$ 30