10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

__________________

FORM 10-Q

QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period ended September 30, 2013

Commission file number 1-2198

The DTE Electric Company meets the conditions set forth in GeneralInstruction H (1) (a) and (b) of Form 10-Q and is, therefore, filing this Formwith the reduced disclosure format.

DTE ELECTRIC COMPANY

(Exact name of registrant as specified in its charter)

Michigan	38-0478650
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)
One Energy Plaza, Detroit, Michigan	48226-1279
(Address of principal executive offices)	(Zip Code)

313-235-4000

(Registrant's telephone number, including area code)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes x No o

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).

Yes x No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer o	Accelerated filer o	Non-acceleratedfiler x	Smaller reportingcompany o
		(Do not check if a smaller reporting company)

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes o No x

All of the registrant's 138,632,324 outstanding shares of common stock are owned by DTE Energy Company.

DTE Electric Company

Quarterly Report on Form 10-Q

Quarter Ended September 30, 2013

Table of Contents

	Page
Definitions	1
Forward-Looking Statements	2
Part I - Financial Information	3
Items 1. Financial Statements	3
Consolidated Statements of Operations (Unaudited)	3
Consolidated Statements of Comprehensive Income (Unaudited)	4
Consolidated Statements of Cash Flows (Unaudited)	5
Consolidated Statements of Financial Position (Unaudited)	6
Consolidated Statements of Changes in Shareholder's Equity (Unaudited)	8
Notes to Consolidated Financial Statements (Unaudited)	9
Item 2. Management's Narrative Analysis of Results of Operations	23
Item 4. Controls and Procedures	26
Part II - Other Information	27
Item 1. Legal Proceedings	27
Item 1A. Risk Factors	27
Item 6. Exhibits	28
Signature	29
EX-4-281
EX-12-47
EX-31-85
EX-31-86
EX-32-85
EX-32-86
EX-101.INS XBRL INSTANCE DOCUMENT
EX-101.SCH XBRL TAXONOMY EXTENSION SCHEMA
EX-101.CAL XBRL TAXONOMY EXTENSION CALCULATION LINKBASE
EX-101.DEF XBRL TAXONOMY EXTENSION DEFINITION DATABASE
EX-101.LAB XBRL TAXONOMY EXTENSION LABEL LINKBASE
EX-101.PRE XBRL TAXONOMY EXTENSION PRESENTATION LINKBASE

DEFINITIONS

ASC	Accounting Standards Codification
ASU	Accounting Standards Update
Customer Choice	Michigan legislation giving customers the option to choose alternative suppliers for electricity.
DTE Electric	DTE Electric Company (a direct wholly owned subsidiary of DTE Energy) and subsidiary companies. Formerly known as The Detroit Edison Company.
DTE Energy	DTE Energy Company, directly or indirectly the parent of DTE Electric, DTE Gas Company and numerous non-utility subsidiaries
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FTRs	Financial transmission rights are financial instruments that entitle the holder to receive payments related to costs incurred for congestion on the transmission grid.
MCIT	Michigan Corporate Income Tax
MDEQ	Michigan Department of Environmental Quality
MISO	Midwest Independent System Operator is an Independent System Operator and the Regional Transmission Organization serving the Midwest United States and Manitoba, Canada.
MPSC	Michigan Public Service Commission
NRC	United States Nuclear Regulatory Commission
Production tax credits	Tax credits as authorized under Sections 45K and 45 of the Internal Revenue Code that are designed to stimulate investment in and development of alternate fuel sources. The amount of a production tax credit can vary each year as determined by the Internal Revenue Service.
PSCR	A Power Supply Cost Recovery mechanism authorized by the MPSC that allows DTE Electric to recover through rates its fuel, fuel-related and purchased power costs.
RDM	A Revenue Decoupling Mechanism authorized by the MPSC that is designed to minimize the impact on revenues of changes in average customer usage of electricity
Securitization	DTE Electric financed specific stranded costs at lower interest rates through the sale of rate reduction bonds by a wholly-owned special purpose entity, The Detroit Edison Securitization Funding LLC.
VIE	Variable Interest Entity

Units of Measurement
kWh	Kilowatthour of electricity
MW	Megawatt of electricity
MWh	Megawatthour of electricity

1

FORWARD-LOOKING STATEMENTS

Certain information presented herein includes “forward-looking statements” within the meaning of the Private Securities Litigation Reform Act of 1995 with respect to the financial condition, results of operations and business of DTE Electric. Words such as "anticipate," "believe," "expect," "projected" and "goals" signify forward-looking statements. Forward-looking statements are not guarantees of future results and conditions, but rather are subject to numerous assumptions, risks and uncertainties that may cause actual future results to be materially different from those contemplated, projected, estimated or budgeted. Many factors may impact forward-looking statements including, but not limited to, the following:

• impact of regulation by the FERC, MPSC, NRC and other applicable governmental proceedings and regulations, including any associated impact on rate structures;

• the amount and timing of cost recovery allowed as a result of regulatory proceedings, related appeals or new legislation;

• impact of electric utility restructuring in Michigan, including legislative amendments and Customer Choice programs;

• economic conditions and population changes in our geographic area resulting in changes in demand, customer conservation, thefts of electricity and high levels of uncollectible accounts receivable;

• environmental issues, laws, regulations, and the increasing costs of remediation and compliance, including actual and potential new federal and state requirements;

• health, safety, financial, environmental and regulatory risks associated with ownership and operation of nuclear facilities;

• changes in the cost and availability of coal and other raw materials and purchased power;

• the potential for losses on investments, including nuclear decommissioning and benefit plan assets and the related increases in future expense and contributions;

• access to capital markets and the results of other financing efforts which can be affected by credit agency ratings;

• instability in capital markets which could impact availability of short and long-term financing;

• the timing and extent of changes in interest rates;

• the level of borrowings;

• the potential for increased costs or delays in completion of significant construction projects;

• changes in and application of federal, state and local tax laws and their interpretations, including the Internal Revenue Code, regulations, rulings, court proceedings and audits;

• the effects of weather and other natural phenomena on operations and sales to customers, and purchases from suppliers;

• unplanned outages;

• the cost of protecting assets against, or damage due to, terrorism or cyber attacks;

• employee relations and the impact of collective bargaining agreements;

• the availability, cost, coverage and terms of insurance and stability of insurance providers;

• cost reduction efforts and the maximization of plant and distribution system performance;

• the effects of competition;

• changes in and application of accounting standards and financial reporting regulations;

• changes in federal or state laws and their interpretation with respect to regulation, energy policy and other business issues;

• binding arbitration, litigation and related appeals; and

• the risks discussed in our public filings with the Securities and Exchange Commission.

New factors emerge from time to time. We cannot predict what factors may arise or how such factors may cause our results to differ materially from those contained in any forward-looking statement. Any forward-looking statements speak only as of the date on which such statements are made. We undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which such statement is made or to reflect the occurrence of unanticipated events.

2

Part I - Financial Information

Item 1. Financial Statements

DTE Electric Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating Revenues	$	1,457		$	1,542		$	3,941		$	4,029
Operating Expenses
Fuel and purchased power	487			543			1,294			1,348
Operation and maintenance	335			337			1,009			1,026
Depreciation and amortization	233			219			666			607
Taxes other than income	67			65			200			193
Asset (gains) losses and reserves, net	(3		)	—			(3		)	(1		)
	1,119			1,164			3,166			3,173
Operating Income	338			378			775			856
Other (Income) and Deductions
Interest expense	68			70			202			204
Other income	(14		)	(14		)	(38		)	(41		)
Other expenses	7			12			19			27
	61			68			183			190
Income Before Income Taxes	277			310			592			666
Income Tax Expense	97			115			206			247
Net Income	$	180		$	195		$	386		$	419

See Notes to Consolidated Financial Statements (Unaudited)

3

DTE Electric Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended September 30,				Nine Months Ended September 30,
	2013		2012		2013		2012
	(In millions)
Net income	$	180	$	195	$	386	$	419
Other comprehensive income:
Benefit obligations, net of taxes of $—, $—, $1 and $1	1		—		2		2
Comprehensive income	$	181	$	195	$	388	$	421

See Notes to Consolidated Financial Statements (Unaudited)

4

DTE Electric Company

Consolidated Statements of Cash Flows (Unaudited)

	Nine Months Ended
	September 30,
	2013			2012
	(In millions)
Operating Activities
Net income	$	386		$	419
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	666			607
Nuclear fuel amortization	25			25
Allowance for equity funds used during construction	(10		)	(9		)
Deferred income taxes	104			(48		)
Asset (gains) losses and reserves, net	(3		)	(1		)
Changes in assets and liabilities:
Accounts receivable, net	(40		)	(13		)
Inventories	53			4
Accounts payable	15			(55		)
Regulatory assets and liabilities	302			280
Accrued pension liability — affiliates	(229		)	(43		)
Accrued postretirement liability — affiliates	(148		)	(91		)
Other assets	(42		)	(24		)
Other liabilities	(15		)	171
Net cash from operating activities	1,064			1,222
Investing Activities
Plant and equipment expenditures	(946		)	(855		)
Restricted cash for debt redemption, principally Securitization	58			57
Notes receivable from affiliate	(4		)	(252		)
Proceeds from sale of nuclear decommissioning trust fund assets	40			48
Investment in nuclear decommissioning trust funds	(52		)	(61		)
Other Investments	(21		)	(13		)
Net cash used for investing activities	(925		)	(1,076		)
Financing Activities
Issuance of long-term debt	768			496
Redemption of long-term debt	(491		)	(401		)
Short-term borrowings — other	(119		)	—
Short-term borrowings — affiliate	(25		)	1
Dividends on common stock	(257		)	(229		)
Other	(2		)	(3		)
Net cash used for financing activities	(126		)	(136		)
Net Increase in Cash and Cash Equivalents	13			10
Cash and Cash Equivalents at Beginning of the Period	30			13
Cash and Cash Equivalents at End of the Period	$	43		$	23
Supplemental Disclosure of Non-Cash Investing and Financing Activities
Plant and equipment expenditures in accounts payable	$	155		$	120

See Notes to Consolidated Financial Statements (Unaudited)

5

DTE Electric Company

Consolidated Statements of Financial Position (Unaudited)

	September 30,			December 31,
	2013			2012
	(In millions)
ASSETS
Current Assets
Cash and cash equivalents	$	43		$	30
Restricted cash, principally Securitization	44			102
Accounts receivable (less allowance for doubtful accounts of $35 and $35, respectively)
Customer	766			697
Affiliates	1			5
Other	19			63
Inventories
Fuel	178			246
Materials and supplies	207			193
Notes receivable	2			2
Regulatory assets	42			162
Prepaid property taxes	89			43
Other	29			34
	1,420			1,577
Investments
Nuclear decommissioning trust funds	1,139			1,037
Other	148			133
	1,287			1,170
Property
Property, plant and equipment	18,479			17,689
Less accumulated depreciation and amortization	(6,971		)	(6,717		)
	11,508			10,972
Other Assets
Regulatory assets	2,919			3,348
Securitized regulatory assets	280			413
Intangible assets	37			30
Notes receivable	6			3
Other	145			138
	3,387			3,932
Total Assets	$	17,602		$	17,651

See Notes to Consolidated Financial Statements (Unaudited)

6

DTE Electric Company

Consolidated Statements of Financial Position (Unaudited) - (Continued)

	September 30,			December 31,
	2013			2012
	(In millions, except shares)
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Liabilities
Accounts payable
Affiliates	$	89		$	65
Other	352			350
Accrued interest	69			61
Current portion long-term debt, including capital leases	501			443
Regulatory liabilities	192			66
Short-term borrowings
Affiliates	55			80
Other	11			130
Other	180			153
	1,449			1,348
Long-Term Debt (net of current portion)
Mortgage bonds, notes and other	4,639			4,221
Securitization bonds	105			302
Capital lease obligations	1			1
	4,745			4,524
Other Liabilities
Deferred income taxes	2,832			2,761
Regulatory liabilities	408			483
Asset retirement obligations	1,640			1,557
Unamortized investment tax credit	43			49
Nuclear decommissioning	172			159
Accrued pension liability — affiliates	1,138			1,368
Accrued postretirement liability — affiliates	638			996
Other	103			103
	6,974			7,476
Commitments and Contingencies (Notes 6 and 9)
Shareholder’s Equity
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	3,196			3,196
Retained earnings	1,258			1,129
Accumulated other comprehensive income (loss)	(20		)	(22		)
	4,434			4,303
Total Liabilities and Shareholder’s Equity	$	17,602		$	17,651

See Notes to Consolidated Financial Statements (Unaudited)

7

DTE Electric Company

Consolidated Statements of Changes in Shareholder’s Equity (Unaudited)

				Additional					Accumulated Other
	Common Stock			Paid-in		Retained			Comprehensive
	Shares	Amount		Capital		Earnings			Loss			Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2012	138,632	$	1,386	$	1,810	$	1,129		$	(22	)	$	4,303
Net income	—	—		—		386			—			386
Dividends declared on common stock	—	—		—		(257		)	—			(257		)
Benefit obligations, net of tax	—	—		—		—			2			2
Balance, September 30, 2013	138,632	$	1,386	$	1,810	$	1,258		$	(20	)	$	4,434

See Notes to Consolidated Financial Statements (Unaudited)

8

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited)

NOTE 1 — 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 2012 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, 2013.

Certain prior year balances were reclassified to match the current year's financial statement presentation.

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 September 30, 2013, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of its variable interests through these long-term purchase contracts.

9

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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 September 30, 2013 and December 31, 2012 restricted for Securitization that are either (1) assets that can be used only to settle obligations related to the Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.

	September 30,		December 31,
	2013		2012
	(In millions)
ASSETS
Restricted cash	$	44	$	102
Accounts receivable	39		34
Securitized regulatory assets	280		413
Other assets	5		7
	$	368	$	556
LIABILITIES
Accounts payable and accrued current liabilities	$	2	$	11
Current portion long-term debt, including capital leases	196		177
Current regulatory liabilities	48		50
Securitization bonds	105		302
Other long-term liabilities	8		7
	$	359	$	547

As of September 30, 2013 DTE Electric had no balance in Notes receivable, related to non-consolidated VIEs and at December 31, 2012 the Company had $3 million in Notes receivable, related to non-consolidated VIEs.

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

Comprehensive Income

Comprehensive income is the change in common shareholder’s 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 and nine months ended September 30, 2013 reflected changes in benefit obligations.

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Three Months Ended September 30, 2013
	Benefit Obligations (b)			Total
	(In millions)
Beginning balance, June 30, 2013	$	(21	)	$	(21	)
Other comprehensive income before reclassifications	—			—
Amounts reclassified from accumulated other comprehensive income	1			1
Net current-period other comprehensive income	1			1
Ending balance, September 30, 2013	$	(20	)	$	(20	)

10

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Nine Months Ended September 30, 2013
	Benefit Obligations (b)			Total
	(In millions)
Beginning balance, December 31, 2012	$	(22	)	$	(22	)
Other comprehensive income before reclassifications	—			—
Amounts reclassified from accumulated other comprehensive income	2			2
Net current-period other comprehensive income	2			2
Ending balance, September 30, 2013	$	(20	)	$	(20	)

_______________________________________

(a) All amounts are net of tax.

(b) The amounts reclassified from accumulated other comprehensive income are included in the computation of the net periodic pension cost (see Retirement Benefits and Trusteed Assets Note 10).

Intangible Assets

The Company has certain intangible assets relating to emission allowances and renewable energy credits as shown below:

	September 30,		December 31,
	2013		2012
	(In millions)
Emission allowances	$	3	$	6
Renewable energy credits	48		44
	51		50
Less current intangible assets	14		20
	$	37	$	30

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 from continuing operations for the three months ended September 30, 2013 was 35 percent as compared to 37 percent for the three months ended September 30, 2012. The Company's effective tax rate from continuing operations for the nine months ended September 30, 2013 was 35 percent as compared to 37 percent for the nine months ended September 30, 2012. The decrease in the effective tax rate in 2013 is due primarily to higher production tax credits. DTE Electric had an income tax payable of $34 million at September 30, 2013 and $13 million at December 31, 2012 due to DTE Energy.

The Company had $3 million of unrecognized tax benefits at September 30, 2013, 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 $10 million and $12 million for the three months ended September 30, 2013 and September 30, 2012, respectively, while such allocation was $43 million and $32 million for the nine months ended September 30, 2013 and September 30, 2012, respectively.

11

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

NOTE 3 — 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 September 30, 2013 and December 31, 2012. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Company classifies fair value balances based on the fair value hierarchy defined as follows:

• Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date.

• Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

• Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.

The following table presents assets measured and recorded at fair value on a recurring basis as of September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)
Assets:
Cash equivalents (a)	$	—	$	61	$	—	$	61	$	—	$	116	$	—	$	116
Nuclear decommissioning trusts	757		382		—		1,139		694		343		—		1,037
Other investments (b)	74		48		—		122		64		44		—		108
Derivative assets — FTRs	—		—		5		5		—		—		1		1
Total	$	831	$	491	$	5	$	1,327	$	758	$	503	$	1	$	1,262
Assets:
Current	$	—	$	61	$	5	$	66	$	—	$	116	$	1	$	117
Noncurrent	831		430		—		1,261		758		387		—		1,145
Total Assets	$	831	$	491	$	5	$	1,327	$	758	$	503	$	1	$	1,262

_______________________________________

(a) At September 30, 2013, available-for-sale securities of $61 million, included $44 million and $17 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2012, available-for-sale securities of $116 million, included $102 million and $14 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 September 30, 2013 and December 31, 2012 of $6 million and $5 million, respectively, are included in Other investments on the Consolidated Statements of Financial Position.

12

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Cash Equivalents

Cash equivalents include investments with maturities of three months or less when purchased. The cash equivalents shown in the fair value table are comprised of short-term investments and money market funds. The fair values of the shares in these investments are based upon observable market prices for similar securities and, therefore, have been categorized as Level 2 in the fair value hierarchy.

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds which hold exchange-traded equity or debt securities are valued based on the underlying securities, using quoted prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered to be preferable. 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 and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013		2012			2013			2012
	(In millions)
Net Assets as of beginning of the period	$	2	$	2		$	1		$	1
Change in fair value recorded in regulatory assets/liabilities	3		7			7			12
Purchases, issuances and settlements:
Settlements	—		(7		)	(3		)	(11		)
Net Assets as of September 30	$	5	$	2		$	5		$	2
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 September 30, 2013 and September 30, 2012	$	3	$	1		$	5		$	2

No transfers between Levels 1, 2 or 3 occurred in the three and nine months ended September 30, 2013 and September 30, 2012.

13

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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 September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	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	$	8	$	—	$	—	$	8	$	5	$	—	$	—	$	5
Short-term borrowings — affiliates	55		—		—		55		80		—		—		80
Short-term borrowings — other	11		—		11		—		130		—		130		—
Long-term debt	5,245		—		5,163		426		4,963		—		5,021		620

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:

	September 30,		December 31,
	2013		2012
	(In millions)
Fermi 2	$	1,120	$	1,021
Fermi 1	3		3
Low-level radioactive waste	16		13
Total	$	1,139	$	1,037

The costs of securities sold are determined on the basis of specific identification. The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
	(In millions)
Realized gains	$	11		$	7		$	30		$	21
Realized losses	(11		)	(6		)	(25		)	(17		)
Proceeds from sales of securities	13			12			40			48

14

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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:

	September 30, 2013				December 31, 2012
	Fair		Unrealized		Fair		Unrealized
	Value		Gains		Value		Gains
	(In millions)
Equity securities	$	732	$	195	$	631	$	122
Debt securities	395		17		399		27
Cash and cash equivalents	12		—		7		—
	$	1,139	$	212	$	1,037	$	149

The debt securities at both September 30, 2013 and December 31, 2012 had an average maturity of approximately 7 and 6 years, respectively. Securities held in the nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.

Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset. DTE Electric recognized $38 million and $44 million of unrealized losses as Regulatory assets at September 30, 2013 and December 31, 2012, respectively. Since the decommissioning of Fermi 1 is funded by DTE Electric rather than through a regulatory recovery mechanism, there is no corresponding regulatory asset treatment. Therefore, unrealized losses incurred by the Fermi 1 trust are recognized in earnings immediately. There were no unrealized losses recognized in the three and nine months ended September 30, 2013 and September 30, 2012 for Fermi 1.

Other Securities

At September 30, 2013 and December 31, 2012, the securities were comprised primarily of money market and equity securities. During the quarter ended September 30, 2013 and the year ended December 31, 2012 no amounts of unrealized losses on available-for-sale securities were reclassified out of other comprehensive income and realized into net income for the periods. Gains related to trading securities held at September 30, 2013 and September 30, 2012 were $12 million and $9 million, respectively.

NOTE 4 — 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.

15

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

The following table presents the fair value of derivative instruments as of September 30, 2013 and December 31, 2012:

	September 30,		December 31,
	2013		2012
	(In millions)
FTRs — Other current assets	$	5	$	1
Total derivatives not designated as hedging instrument	$	5	$	1

The effects of derivative instruments recoverable through the PSCR mechanism when realized on the Consolidated Statements of Financial Position were $3 million and $7 million in gains related to FTRs recognized in Regulatory liabilities for the three and nine months ended September 30, 2013, respectively.

The following represents the cumulative gross volume of derivative contracts outstanding as of September 30, 2013:

Commodity	Number of Units
FTRs (MWh)	72,875

NOTE 5 — ASSET RETIREMENT OBLIGATIONS

A reconciliation of the asset retirement obligations for the nine months ended September 30, 2013 follows:

	(In millions)
Asset retirement obligations at December 31, 2012	$	1,557
Accretion	72
Revision in estimated cash flows	13
Liabilities settled	(2		)
Asset retirement obligations at September 30, 2013	$	1,640

NOTE 6 — REGULATORY MATTERS

Transition of the City of Detroit's Public Lighting Department's (PLD) Customers to DTE Electric's Distribution System

Accounting Authority

On June 28, 2013, DTE Electric filed an application for accounting authority to defer certain costs associated with the transition of the City of Detroit's PLD customers to the DTE Electric distribution system over a five to seven year system conversion period. The Company requested authority to defer as a regulatory asset, all net incremental revenue requirement associated with the transition. The net incremental revenue requirement includes costs to install meters and attach customers; system and customer facility upgrades and repairs; and the difference between DTE Electric's tariff rates and any transitional rates approved in the future. On July 11, 2013, the MPSC approved DTE Electric's request to defer, for accounting purposes, the net incremental revenue requirement.

The approval excludes the request to defer the difference between DTE Electric's tariff rates and any transitional rates that might be approved by the MPSC in the future. The MPSC will address proposed rates and recovery matters in a future contested proceeding. As the accounting order did not provide a regulatory recovery mechanism, a regulatory asset will not be recognized until a regulatory recovery mechanism is put into place and the recovery of the regulatory asset becomes probable.

Transitional Reconciliation Mechanism (TRM)

On July 19, 2013, DTE Electric filed its TRM application proposing a transitional tariff option for certain former PLD customers and a modified line extension provision. The application also proposes a recovery mechanism for the deferred incremental revenue requirement described above. The application further discusses that DTE Electric will be requesting recovery, in subsequent PSCR cases, of PLD transmission delivery service costs incurred while DTE Electric is temporarily relying upon PLD to operate and maintain PLD's system during the conversion period. If the MPSC determines that the transmission costs are not recoverable in the PSCR, the Company requested recovery as part of the TRM.

16

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

2009 Electric Rate Case Filing - Court of Appeals Remand to MPSC

In April 2012, the Michigan Court of Appeals (COA) issued a decision relating to an appeal of the January 2010 MPSC rate order in DTE Electric's January 2009 rate case filing. The COA found that the record of evidence in the January 2010 rate order was insufficient to support the MPSC's authorization to recover costs for the advanced metering infrastructure (AMI) program and remanded this matter to the MPSC. On October 17, 2013, the MPSC issued an order affirming the approximately $8 million rate increase authorized in the MPSC's January 2010 rate order for the AMI program and further concluded that the evidence presented after remand supports the authorized cost recovery.

2010 Electric Rate Case Filing - Court of Appeals Decision

In July 2013, the COA issued a decision relating to an appeal of the October 2011 MPSC order in DTE Electric's October 2010 rate case filing. The COA found that the record of evidence in the 2010 rate case order was insufficient to support the MPSC's authorization to recover costs for the AMI program and remanded this matter to the MPSC. The MPSC had approved $55 million of the average rate base related to the AMI program in the October 2011 order. DTE Electric is currently operating its AMI program pursuant to the MPSC's approval set forth in its October 20, 2011 order. On August 29, 2013, the MPSC reopened the 2010 electric rate case for the limited purpose of addressing the COA's opinion on AMI. The Company is unable to predict the outcome of this matter or the timing of its resolution.

Power Supply Cost Recovery Proceedings

The PSCR process is designed to allow DTE Electric to recover all of its power supply costs if incurred under reasonable and prudent policies and practices. DTE Electric's power supply costs include fuel and related transportation costs, purchased and net interchange power costs, nitrogen oxide and sulfur dioxide emission allowances costs, urea costs, transmission costs and MISO costs. The MPSC reviews these costs, policies and practices for prudence in annual plan and reconciliation filings.

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 approximately $30 million of 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. We were 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 some or all of the Fermi-related purchased power costs. Resolution of this matter is expected in 2014.

Low Income Energy Assistance Fund (LIEAF)

On July 1, 2013, Michigan Public Act 95 was signed into law and created the LIEAF. The legislation allows the use of a LIEAF funding factor to be determined by the MPSC and assessed on all customer classes of Michigan electric utilities to fund the LIEAF. On July 29, 2013, the MPSC adopted a funding factor of $0.99 per meter per month for all Michigan electric utilities that are participating in the program, including DTE Electric, effective with the September 2013 billing month. The surcharge billed by DTE Electric is remitted to the State of Michigan for subsequent distribution through a grant process to social service agencies and utilities to assist low income customers.

NOTE 7 — LONG-TERM DEBT

Debt Issuances

In 2013, the following debt was issued:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
March	Mortgage Bonds (a)	4.00%	2043	$	375
August	Mortgage Bonds (a)	3.65%	2024	400
				$	775

_______________________________________

(a) Proceeds were used for the redemption of DTE Electric long-term debt, for the repayment of short-term borrowings, and for general corporate purposes.

17

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Debt Redemptions

In 2013, the following debt was redeemed:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
March	Securitization Bonds	6.42%	2013	$	88
March	Tax Exempt Revenue Bonds (a)	5.30%	2030	51
April	Other Long-Term Debt	Various	2013	13
September	Securitization Bonds	6.62%	2015	89
September	Senior Notes	6.40%	2013	250
				$	491

_____________________________

(a) DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.

NOTE 8 — 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. At September 30, 2013, there was $11 million outstanding against the facility, while there was $130 million outstanding against the facility at December 31, 2012.

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 consolidatedsubsidiaries, 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 September 30, 2013, the total funded debt to total capitalization ratio for DTE Electric was 0.53 to 1 and is in compliance with this financial covenant.

NOTE 9 — 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 $1.9 billion through 2012. The Company estimates DTE Electric will make capital expenditures of approximately $190 million in 2013 and up to approximately $1.8 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 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 not expected before 2014. Notwithstanding the appeal filed with the Supreme Court, the EPA and a number of states have started working on the framework of revised CSAPR regulations which we anticipate to be proposed in the next few years.

18

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

The Mercury and Air Toxics Standard (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized on December 16, 2011. The MATS rule requires reductions of mercury and other hazardous air pollutants beginning in April 2015, with a potential extension to April 2016. DTE Electric has requested and been granted compliance date extensions for some units to April 2016. DTE Electric has tested technologies to determine technological and economic feasibility as MATS compliance alternatives to Flue Gas Desulfurization (FGD) systems. Implementation of Dry Sorbent Injection (DSI) and Activated Carbon Injection (ACI) technologies will allow several units that would not have been economical for FGD installations to continue operation in compliance with MATS.

In July 2009, DTE Energy received a Notice of Violation/Finding of Violation (NOV/FOV) from the EPA alleging, among other things, that five DTE Electric power plants violated New Source Performance standards, Prevention of Significant Deterioration requirements, and operating permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations related to a project and outage at Unit 2 of the Monroe Power Plant. In March 2013, DTE Energy received a supplemental NOV from the EPA relating to the July 2009 NOV/FOV. The supplemental NOV alleged additional violations relating to the New Source Review provisions under the Clean Air Act, among other things.

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant, but not relating to the July 2009 NOV/FOV. Among other relief, the EPA requested the court to require DTE Electric to install and operate the best available control technology at Unit 2 of the Monroe Power Plant. Further, the EPA requested the court to issue a preliminary injunction to require DTE Electric to (i) begin the process of obtaining the necessary permits for the Monroe Unit 2 modification and (ii) offset the pollution from Monroe Unit 2 through emissions reductions from DTE Electric's fleet of coal-fired power plants until the new control equipment is operating. On August 23, 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. The EPA and Sierra Club motions are currently pending with the U. S. District Court Judge.

DTE Electric believes that the plants identified by the EPA, including Unit 2 of the Monroe Power Plant, have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

On March 13, 2013, the Sierra Club filed suit against DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,4996-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. 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. In July 2012, the EPA announced that a notice of its final action on the rule will be issued in June 2013. On June 27, 2013, the EPA announced an agreement to extend the deadline for issuance of the final rule until November 4, 2013. On April 19, 2013, the EPA proposed revised steam electric effluent guidelines regulating wastewater streams from coal-fired power plants including multiple possible options for compliance. The rules are expected to be finalized by May 2014. DTE Electric has provided comments to the EPA. However, it is not possible at this time to quantify the impacts of these developing requirements.

19

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

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 September 30, 2013 and at December 31, 2012, the Company had $9 million accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company believes that the likelihood of a materially greater liability than the accrued amount is remote based on current knowledge of the conditions at each site.

DTE Electric owns and operates a permitted engineered ash storage facility at the Monroe Power Plant 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. It is not possible to quantify the impact of those expected rulemakings at this time.

Other

In March 2011, the EPA finalized a new set of regulations regarding the identification of non-hazardous secondary materials that are considered solid waste, industrial boiler and process heater maximum achievable control technologies (IBMACT) for major and area sources, and commercial/industrial solid waste incinerator new source performance standard and emission guidelines (CISWI). The effective dates of the major source IBMACT and CISWI regulations were stayed anda re-proposal was issued by the EPA in December 2011. Final IBMACT and CISWI were issued by the EPA in December 2012. The Company is developing compliance plans to upgrade or convert existing industrial boilers to natural gas and to perform required energy assessments in compliance with the applicable new standards. Capital costs for the boiler conversions and the expenses for the one-time energy assessments are not expected to be material.

In 2010, the EPA finalized a new 1-hour sulfur dioxide ambient air quality standard that requires states to submit plans for non-attainment areas to be in compliance by 2017. Michigan's non-attainment area includes DTE 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 any required emission reductions for DTE Electric sources to meet the standard cannot be estimated currently.

Nuclear Operations

Property Insurance

DTE Electric maintains property insurance policies specifically for the Fermi 2 plant. These policies cover such items as replacement power and property damage. The Nuclear Electric Insurance Limited (NEIL) is the primary supplier of the insurance policies.

DTE Electric maintains a policy for extra expenses, including replacement power costs necessitated by Fermi 2's unavailability due to an insured event. This policy has a 12-week waiting period and provides an aggregate $490 million of coverage over a three-year period.

20

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

DTE Electric has $500 million in primary coverage and $2.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property and decommissioning. The combined coverage limit for total property damage is $2.75 billion, subject to a $1 million deductible. As of April 1, 2013, the total limit for property damage for non-nuclear events is $1.8 billion and an aggregate of $327 million of coverage for extra expenses over a two-year period.

In 2007, the Terrorism Risk Insurance Extension Act of 2005 (TRIA) was extended through December 31, 2014. A major change in the extension is the inclusion of “domestic” acts of terrorism in the definition of covered or “certified” acts. For multiple terrorism losses caused by acts of terrorism not covered under the TRIA occurring within one year after the first loss from terrorism, the NEIL policies would make available to all insured entities up to $3.2 billion, plus any amounts recovered from reinsurance, government indemnity, or other sources to cover losses.

Under the NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $34 million per event if the loss associated with any one event at any 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 anticipates 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 all claims submitted have been accepted. The settlement proceeds reduced the cost of the dry cask storage facility assets. In February 2013, the U.S. Court of Appeals for the District of Columbia granted a motion to reopen the fee adequacy litigation to review the DOE's latest fee adequacy report which was released in January 2013. DTE Electric will continue to pay fees to the U.S. government's nuclear waste fund pending further action by the D.C. Circuit. 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.

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.

21

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

Labor Contracts

Our contract with a bargaining unit for the majority of our represented employees was due to expire in June 2013. Early negotiations resulted in a new contract that became effective in March 2013. The new contract will expire in June 2017.

Purchase Commitments

As of September 30, 2013, the Company was party to numerous long-term purchase commitments relating to a variety of goods and services required for the Company’s business. These agreements primarily consist of fuel supply commitments, renewable energy contracts and energy trading contracts. The Company estimates that these commitments will be approximately $2.6 billion from 2013 through 2034.

The Company also estimates that 2013 capital expenditures will be approximately $1.5 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.

NOTE 10 — 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
	2013			2012			2013			2012
Three Months Ended September 30	(In millions)
Service cost	$	17		$	15		$	6		$	11
Interest cost	36			38			16			23
Expected return on plan assets	(45		)	(41		)	(18		)	(15		)
Amortization of:
Net actuarial loss	39			33			12			16
Prior service cost (credit)	1			—			(27		)	(4		)
Net periodic benefit cost (credit)	$	48		$	45		$	(11	)	$	31

22

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited) — (Continued)

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Nine Months Ended September 30	(In millions)
Service cost	$	55		$	48		$	27		$	38
Interest cost	109			116			50			69
Expected return on plan assets	(138		)	(124		)	(55		)	(46		)
Amortization of:
Net actuarial loss	111			93			36			44
Prior service cost (credit)	1			—			(72		)	(12		)
Net transition liability	—			—			—			1
Settlements	—			2			—			—
Net periodic benefit cost (credit)	$	138		$	135		$	(14	)	$	94

Pension and Other Postretirement Contributions

During the first nine months of 2013, the Company contributed $250 million to its pension plans, including contributions of DTE Energy common stock of $200 million. At the discretion of management, and depending upon financial market conditions, the Company may make up to an additional $25 million contribution to its pension plans in 2013.

In January 2013, the Company contributed $120 million to its other postretirement benefit plans. At the discretion of management, the Company may make up to an additional $120 million contribution to its other postretirement benefit plans in 2013.

Re-Measurement of Other Postretirement Benefit Obligation

In March 2013, the Company reached an agreement on a new four-year labor contract with certain represented employees. As a term of the agreement, the Company replaced sponsored retiree medical, prescription drug and dental coverage for future Medicare eligible retirees with a Retiree Health Care Allowance (RHCA) account of $3,250 per year. The modification in retiree health coverage will reduce future postretirement benefit costs.

Based on the impact of such benefit cost savings on the financial statements, the Company re-measured its retiree health plan as of March 31, 2013. In performing the re-measurement, the Company updated its significant actuarial assumptions, including an adjustment to the discount rate from 4.15% at December 31, 2012 to 4.30% at March 31, 2013. Plan assets were also updated to reflect fair value as of the re-measurement date. As a result of the re-measurement, the accumulated postretirement benefit obligation (APBO) was reduced by $192 million. The Company's Accrued postretirement benefit liability - affiliates at March 31, 2013 was $661 million as compared to $996 million at December 31, 2012, a reduction of $335 million. The reduction reflects the impact of the re-measurement of the plan, January 2013 plan contributions and recognition of first quarter 2013 postretirement benefit costs and benefit payments.

Beginning April 2013, net postretirement benefit costs were recorded based on the updated actuarial assumptions and benefit changes resulting from the new labor contracts. As a result of the re-measurement, fiscal year 2013 postretirement benefit costs are expected to decrease by approximately $51 million to an annual net benefit of approximately $23 million.

Item 2. Management’s Narrative Analysis of Results of Operations

The Management’s Narrative Analysis of Results of Operations discussion for DTE Electric is presented in accordance with General Instruction H (2) (a) of Form 10-Q.

DTE Electric's results for the three and nine months ended September 30, 2013 as compared to the comparable 2012 period are discussed below:

23

	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2013			2012			2013			2012
	(In millions)
Operating revenues	$	1,457		$	1,542		$	3,941		$	4,029
Fuel and purchased power	487			543			1,294			1,348
Gross margin	970			999			2,647			2,681
Operation and maintenance	335			337			1,009			1,026
Depreciation and amortization	233			219			666			607
Taxes other than income	67			65			200			193
Asset (gains) losses and reserves, net	(3		)	—			(3		)	(1		)
Operating Income	338			378			775			856
Other (Income) and Deductions	61			68			183			190
Income Tax Expense	97			115			206			247
Net Income	$	180		$	195		$	386		$	419
Operating Income as a Percentage of Operating Revenues	23		%	25		%	20		%	21		%

Gross margin decreased $29 million and $34 million in the three and nine months ended September 30, 2013, respectively. Revenues associated with certain tracking mechanisms and surcharges are offset by related expenses elsewhere in the Consolidated Statement of Operations.

The following table details changes in various gross margin components relative to the comparable prior period:

	Three Months			Nine Months
	(In millions)
Base sales, inclusive of weather effect	$	(46	)	$	(58	)
Securitization bond and tax surcharge	5			29
Renewable energy program	12			20
Low income energy assistance surcharge	—			(20		)
Regulatory mechanisms and other	—			(5		)
Decrease in gross margin	$	(29	)	$	(34	)

	Three Months Ended		Nine Months Ended
	September 30,		September 30,
	2013	2012	2013	2012
	(In thousands of MWh)
Electric Sales
Residential	4,401	4,894	11,600	12,180
Commercial	4,504	4,602	12,585	12,734
Industrial	2,635	2,707	7,746	7,645
Other	233	238	701	717
	11,773	12,441	32,632	33,276
Interconnection sales (a)	711	441	2,276	1,827
Total Electric Sales	12,484	12,882	34,908	35,103
Electric Deliveries
Retail and Wholesale	11,773	12,441	32,632	33,276
Electric Customer Choice, including self generators (b)	1,393	1,372	3,940	3,938
Total Electric Sales and Deliveries	13,166	13,813	36,572	37,214

_______________________________________

(a) Represents power that is not distributed by DTE Electric.

(b) Represents deliveries for self generators who have purchased power from alternative energy suppliers to supplement their power requirements.

24

Operation and maintenance expense decreased $2 million and $17 million in the three and nine months ended September 30, 2013, respectively. The decrease in the third quarter was due primarily to lower employee benefit expenses of $21 million and lower distribution operations expenses of $4 million, partially offset by higher corporate administrative expenses of $11 million, higher restoration and line clearance expenses of $4 million, increased energy optimization and renewable energy expenses of $4 million, increased uncollectible expenses of $2 million and increased low income energy assistance expenses of $2 million. The decrease in the nine-month period was primarily due to lower employee benefit expenses of $52 million, decreased low income energy assistance expenses of $18 million and lower power plant generation expenses of $2 million, partially offset by higher corporate administrative expenses of $22 million, higher energy optimization and renewable energy expenses of $12 million, increased uncollectible expenses of $11 million, higher restoration and line clearance expenses of $7 million and increased distribution operations expenses of $4 million.

Depreciation and amortization expense increased $14 million and $59 million in the three and nine months ended September 30, 2013, respectively. The increase in the third quarter was due to higher amortization of regulatory assets of $11 million and $3 million of increased expense due to a higher depreciable base. The increase in the nine-month period was due to $45 million of higher amortization of regulatory assets and $14 million of increased expense due to a higher depreciable base.

Income tax expense decreased $18 million and $41 million in the three and nine months ended September 30, 2013, respectively, due to lower pre-tax income and a decrease in the effective income tax rate primarily due to higher production tax credits.

Outlook— We continue to move forward in our efforts to achieve operational excellence, sustained strong cash flows and earn our authorized return on equity. We expect that our planned significant environmental and renewable expenditures will result in earnings growth. Looking forward, additional factors may impact earnings such as weather, the outcome of regulatory proceedings, benefit plan design changes, investment returns and changes in discount rate assumptions in benefit plans and health care costs, and uncertainty of legislative or regulatory actions regarding climate change and electric choice. We expect to continue our efforts to improve productivity and decrease our costs while improving customer satisfaction with consideration of customer rate affordability.

In June 2013, the City of Detroit announced a transition of its Public Lighting Department's customers to the DTE Electric distribution system over a five to seven year system conversion period. See Note 6 of the Notes to Consolidated Financial Statements.

Climate regulation and/or legislation has been proposed and discussed within the U.S. Congress and the EPA. The EPA is implementing regulatory actions under the Clean Air Act to address emissions of greenhouse gases (GHGs). EPA regulation of GHGs requires the best available control technology (BACT) for new major sources or modifications to existing major sources that cause significant increases in GHG emissions. In June 2012, the EPA proposed new source performance standards for carbon dioxide emissions from new fossil-fueled power plants. These new source performance standards were re-proposed on September 20, 2013, under a presidential directive issued on June 25, 2013. Under the same presidential directive, the EPA is expected to propose performance standards for carbon dioxide emissions from existing and modified plants by June 1, 2014 and issue final standards by June 1, 2015. DTE Energy will be an active participant in working with the EPA and other stakeholders to shape the final performance standards for new and existing power plants. The standards for new sources are not expected to have a material impact on the Company. It is not possible to determine the potential impact of future regulations on existing sources at this time. Pending or future legislation or other regulatory actions could have a material impact on our operations and financial position and the rates we charge our customers. Impacts include expenditures for environmental equipment beyond what is currently planned, financing costs related to additional capital expenditures, the purchase of emission offsets from market sources and the retirement of facilities where control equipment is not economical. We would seek to recover these incremental costs through increased rates charged to our utility customers. Increased costs for energy produced from traditional sources could also increase the economic viability of energy produced from renewable and/or nuclear sources and energy efficiency initiatives and the development of market-based trading of carbon offsets providing business opportunities for our utility and non-utility segments. It is not possible to quantify these impacts on DTE Electric or its customers at this time.

25

Item 4. Controls and Procedures

(a) Evaluation of disclosure controls and procedures

Management of the Company carried out an evaluation, under the supervision and with the participation of DTE Electric's Chief Executive Officer (CEO) and Chief Financial Officer (CFO), of the effectiveness of the design and operation of the Company's disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) as of September 30, 2013, which is the end of the period covered by this report. Based on this evaluation, the Company's CEO and CFO have concluded that such disclosure controls and procedures are effective in providing reasonable assurance that information required to be disclosed by the Company in reports that it files or submits under the Exchange Act (i) is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms and (ii) is accumulated and communicated to the Company's management, including its CEO and CFO, as appropriate to allow timely decisions regarding required disclosure. Due to the inherent limitations in the effectiveness of any disclosure controls and procedures, management cannot provide absolute assurance that the objectives of its disclosure controls and procedures will be attained.

(b) Changes in internal control over financial reporting

There have been no changes in the Company's internal control over financial reporting during the quarter ended September 30, 2013 that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.

26

Part II - Other Information

Item 1. Legal Proceedings

In July 2009, DTE Energy received a Notice of Violation/Finding of Violation (NOV/FOV) from the EPA alleging, among other things, that five DTE Electric power plants violated New Source Performance standards, Prevention of Significant Deterioration requirements, and operating permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations related to a project and outage at Unit 2 of the Monroe Power Plant. In March 2013, DTE Energy received a supplemental NOV from the EPA relating to the July 2009 NOV/FOV. The supplemental NOV alleged additional violations relating to the New Source Review provisions under the Clean Air Act, among other things.

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant, but not relating to the July 2009 NOV/FOV. Among other relief, the EPA requested the court to require DTE Electric to install and operate the best available control technology at Unit 2 of the Monroe Power Plant. Further, the EPA requested the court to issue a preliminary injunction to require DTE Electric to (i) begin the process of obtaining the necessary permits for the Monroe Unit 2 modification and (ii) offset the pollution from Monroe Unit 2 through emissions reductions from DTE Electric's fleet of coal-fired power plants until the new control equipment is operating. On August 23, 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. The EPA and Sierra Club motions are currently pending with the U. S. District Court Judge.

DTE Energy and DTE Electric believe that the plants identified by the EPA, including Unit 2 of the Monroe Power Plant, have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

On March 13, 2013, the Sierra Club filed suit against DTE Energy and DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,499 6-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin DTE Energy and DTE Electric from operating the power plants except in complete compliance with applicable laws and permit requirements, pay civil penalties, conduct beneficial environmental mitigation projects, pay attorney fees and require the installation of any necessary pollution controls or to convert and/or operate the plants' boilers on natural gas to avoid additional violations and to off-set historic unlawful emissions. The resolution of this matter is not expected to have a material effect on the Company's operations or financial statements.

For additional discussion on legal matters, see Notes 6 and 9 of the Notes to Consolidated Financial Statements.

Item 1A.  Risk Factors

There are various risks associated with the operations of DTE Electric. To provide a framework to understand the operating environment of DTE Electric, we have provided a brief explanation of the more significant risks associated with our businesses in Part 1, Item 1A. Risk Factors in the Company's 2012 Form 10-K. Although we have tried to identify and discuss key risk factors, others could emerge in the future. In addition to the risk factors set forth in our 10-K, the following updated risk could affect our performance.

27

A work interruption may adversely affect us. Unions represent approximately 2,700 of our employees. The labor contract that covers the majority of our represented employees was due to expire in June 2013. Early negotiations resulted in a new contract that became effective in March 2013. The new contract will expire in June 2017. A union choosing to strike would have an impact on our business. We are unable to predict the effect a work stoppage would have on our costs of operation and financial performance.

Item 6. Exhibits

	(i) Exhibits filed herewith:
4-281	Supplemental Indenture, dated as of August 1, 2013, to the Mortgage and Deed of Trust, dated as of October 1, 1924, between DTE Electric Company and The Bank of New York Mellon Trust Company, N.A., as successor trustee (2013 Series B)
12-47	Computation of Ratio of Earnings to Fixed Charges
31-85	Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report
31-86	Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Database
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase

	(ii) Exhibits furnished herewith:
32-85	Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report
32-86	Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report

28

Signature

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the date indicated.

		DTE ELECTRIC COMPANY
		(Registrant)
Date: October 25, 2013	By	/s/ DONNA M. ENGLAND
		Donna M. England Chief Accounting Officer (Principal Accounting Officer)

29

EX-4.281

EXHIBIT 4-281

INDENTURE

DATED AS OF AUGUST 1, 2013

_______________

DTE ELECTRIC COMPANY

formerly known as

The Detroit Edison Company

(One Energy Plaza, Detroit, Michigan 48226)

TO

THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A.

(719 Griswold Street, Suite 930, Detroit, Michigan 48226)

AS TRUSTEE

_______________

SUPPLEMENTAL TO MORTGAGE AND DEED OF TRUST

DATED AS OF OCTOBER 1, 1924

PROVIDING FOR

(A) GENERAL AND REFUNDING MORTGAGE BONDS,

2013 SERIES B

AND

(B) RECORDING AND FILING DATA

TABLE OF CONTENTS*

1

TABLE OF CONTENTS*

	PAGE
PARTIES	3
RECITALS	3
Original Indenture and Supplemental Indentures	3
Issue of Bonds Under Indenture	4
Bonds Heretofore Issued	4
Reason for Creation of New Series	11
Bonds to be 2013 Series B	11
Further Assurance	11
Authorization of Supplemental Indenture	11
Consideration for Supplemental Indenture	11
PART I. CREATION OF THREE HUNDRED SEVENTIETH SERIES OF BONDS, GENERAL AND REFUNDING MORTGAGE BONDS, 2013 SERIES B	12
Sec. 1.Terms of Bonds of 2013 Series B	12
Sec. 2.Redemption of Bonds of 2013 Series B	14
Sec. 3.Exchange and Transfer	15
Sec. 4.Form of Bonds of 2013 Series B	16
Form of Trustee's Certificate	20
PART III. RECORDING AND FILING DATA	20
Recording and Filing of Original Indenture	20
Recording and Filing of Supplemental Indentures	21
Recording and Filing of Supplemental Indenture Dated as of March 15, 2013	26
Recording of Affidavit of Facts Affecting Real Property	26
Recording of Certificates of Provision for Payment	26
PART IV. THE TRUSTEE	27
Terms and Conditions of Acceptance of Trust by Trustee	27
PART V. MISCELLANEOUS	27
Confirmation of Section 318(c) of Trust Indenture Act	27
Execution in Counterparts	27
EXECUTION	27
Testimonium	27
Execution by Company	28
Acknowledgment of Execution by Company	29
Execution by Trustee	30
Acknowledgment of Execution by Trustee	31
Affidavit as to Consideration and Good Faith	32

---------

* This Table of Contents shall not have any bearing upon the interpretation of any of the terms or provisions of this Indenture.

2

2

PARTIES.

SUPPLEMENTAL INDENTURE, dated as of the 1st day of August, in the year 2013, between DTE ELECTRIC COMPANY, formerly known as The Detroit Edison Company, a corporation organized and existing under the laws of the State of Michigan and a public utility (hereinafter called the “Company”), party of the first part, and The Bank of New York Mellon Trust Company, N.A., a trust company organized and existing under the laws of the United States, having a corporate trust agency office at 719 Griswold Street, Suite 930, Detroit, Michigan 48226, as successor Trustee under the Mortgage and Deed of Trust hereinafter mentioned (hereinafter called the “Trustee”), party of the second part.

ORIGINAL INDENTURE AND SUPPLEMENTAL INDENTURES.

WHEREAS, the Company has heretofore executed and delivered its Mortgage and Deed of Trust (hereinafter referred to as the “Original Indenture”), dated as of October 1, 1924, to the Trustee, for the security of all bonds of the Company outstanding thereunder, and pursuant to the terms and provisions of the Original Indenture, indentures dated as of, respectively, June 1, 1925, August 1, 1927, February 1, 1931, June 1, 1931, October 1, 1932, September 25, 1935, September 1, 1936, November 1, 1936, February 1, 1940, December 1, 1940, September 1, 1947, March 1, 1950, November 15, 1951, January 15, 1953, May 1, 1953, March 15, 1954, May 15, 1955, August 15, 1957, June 1, 1959, December 1, 1966, October 1, 1968, December 1, 1969, July 1, 1970, December 15, 1970, June 15, 1971, November 15, 1971, January 15, 1973, May 1, 1974, October 1, 1974, January 15, 1975, November 1, 1975, December 15, 1975, February 1, 1976, June 15, 1976, July 15, 1976, February 15, 1977, March 1, 1977, June 15, 1977, July 1, 1977, October 1, 1977, June 1, 1978, October 15, 1978, March 15, 1979, July 1, 1979, September 1, 1979, September 15, 1979, January 1, 1980, April 1, 1980, August 15, 1980, August 1, 1981, November 1, 1981, June 30, 1982, August 15, 1982, June 1, 1983, October 1, 1984, May 1, 1985, May 15, 1985, October 15, 1985, April 1, 1986, August 15, 1986, November 30, 1986, January 31, 1987, April 1, 1987, August 15, 1987, November 30, 1987, June 15, 1989, July 15, 1989, December 1, 1989, February 15, 1990, November 1, 1990, April 1, 1991, May 1, 1991, May 15, 1991, September 1, 1991, November 1, 1991, January 15, 1992, February 29, 1992, April 15, 1992, July 15, 1992, July 31, 1992, November 30, 1992, December 15, 1992, January 1, 1993, March 1, 1993, March 15, 1993, April 1, 1993, April 26, 1993, May 31, 1993, June 30, 1993, June 30, 1993, September 15, 1993, March 1, 1994, June 15, 1994, August 15, 1994, December 1, 1994, August 1, 1995, August 1, 1999, August 15, 1999, January 1, 2000, April 15, 2000, August 1, 2000, March 15, 2001, May 1, 2001, August 15, 2001, September 15, 2001, September 17, 2002, October 15, 2002, December 1, 2002, August 1, 2003, March 15, 2004, July 1, 2004, February 1, 2005, April 1, 2005, August 1, 2005, September 15, 2005, September 30, 2005, May 15, 2006, December 1, 2006, December 1, 2007, April 1, 2008, May 1, 2008, June 1, 2008, July 1, 2008, October 1, 2008, December 1, 2008, March 15, 2009, November 1, 2009, August 1, 2010, September 1, 2010, December 1, 2010, March 1, 2011, May 15, 2011, August 1, 2011, August 15, 2011, September 1, 2011, June 20, 2012 and March 15, 2013 supplemental to the Original Indenture, have heretofore been entered into between the Company and the Trustee (the Original Indenture and all indentures supplemental thereto together being hereinafter sometimes referred to as the “Indenture”); and

3

ISSUE OF BONDS UNDER INDENTURE.

WHEREAS, the Indenture provides that said bonds shall be issuable in one or more series, and makes provision that the rates of interest and dates for the payment thereof, the date of maturity or dates of maturity, if of serial maturity, the terms and rates of optional redemption (if redeemable), the forms of registered bonds without coupons of any series and any other provisions and agreements in respect thereof, in the Indenture provided and permitted, as the Board of Directors may determine, may be expressed in a supplemental indenture to be made by the Company to the Trustee thereunder; and

BONDS HERETOFORE ISSUED.

WHEREAS, bonds in the principal amount of Fifteen billion, six hundred thirty-eight million, fifty-seven thousand dollars ($15,638,057,000) have heretofore been issued under the indenture as follows, viz:

(1)	Bonds of Series A	#NAME!
(2)	Bonds of Series B	-- Principal Amount $23,000,000,
(3)	Bonds of Series C	-- Principal Amount $20,000,000,
(4)	Bonds of Series D	-- Principal Amount $50,000,000,
(5)	Bonds of Series E	-- Principal Amount $15,000,000,
(6)	Bonds of Series F	-- Principal Amount $49,000,000,
(7)	Bonds of Series G	-- Principal Amount $35,000,000,
(8)	Bonds of Series H	-- Principal Amount $50,000,000,
(9)	Bonds of Series I	-- Principal Amount $60,000,000,
(10)	Bonds of Series J	-- Principal Amount $35,000,000,
(11)	Bonds of Series K	-- Principal Amount $40,000,000,
(12)	Bonds of Series L	-- Principal Amount $24,000,000,
(13)	Bonds of Series M	-- Principal Amount $40,000,000,
(14)	Bonds of Series N	-- Principal Amount $40,000,000,
(15)	Bonds of Series O	-- Principal Amount $60,000,000,
(16)	Bonds of Series P	-- Principal Amount $70,000,000,
(17)	Bonds of Series Q	-- Principal Amount $40,000,000,
(18)	Bonds of Series W	-- Principal Amount $50,000,000,
(19)	Bonds of Series AA	-- Principal Amount $100,000,000,
(20)	Bonds of Series BB	-- Principal Amount $50,000,000,

4

(21)	Bonds of Series CC	- Principal Amount $50,000,000,
(22)	Bonds of Series UU	- Principal Amount $100,000,000,
(23-31)	Bonds of Series DDP Nos. 1-9	- Principal Amount $14,305,000,
(32-45)	Bonds of Series FFR Nos. 1-14	- Principal Amount $45,600,000,
(46-67)	Bonds of Series GGP Nos. 1-22	- Principal Amount $42,300,000,
(68)	Bonds of Series HH	- Principal Amount $50,000,000,
(69-90)	Bonds of Series IIP Nos. 1-22	- Principal Amount $3,750,000,
(91-98)	Bonds of Series JJP Nos. 1-8	- Principal Amount $6,850,000,
(99-107)	Bonds of Series KKP Nos. 1-9	- Principal Amount $34,890,000,
(108-122)	Bonds of Series LLP Nos. 1-15	- Principal Amount $8,850,000,
(123-143)	Bonds of Series NNP Nos. 1-21	- Principal Amount $47,950,000,
(144-161)	Bonds of Series OOP Nos. 1-18	- Principal Amount $18,880,000,
(162-180)	Bonds of Series QQP Nos. 1-19	- Principal Amount $13,650,000,
(181-195)	Bonds of Series TTP Nos. 1-15	- Principal Amount $3,800,000,
(196)	Bonds of 1980 Series A	- Principal Amount $50,000,000,
(197-221)	Bonds of 1980 Series CP Nos. 1-25	- Principal Amount $35,000,000,
(222-232)	Bonds of 1980 Series DP Nos. 1-11	- Principal Amount $10,750,000,
(233-248)	Bonds of 1981 Series AP Nos. 1-16	- Principal Amount $124,000,000,
(249)	Bonds of 1985 Series A	- Principal Amount $35,000,000,
(250)	Bonds of 1985 Series B	- Principal Amount $50,000,000,
(251)	Bonds of Series PP	- Principal Amount $70,000,000,
(252)	Bonds of Series RR	- Principal Amount $70,000,000,
(253)	Bonds of Series EE	- Principal Amount $50,000,000,
(254-255)	Bonds of Series MMP and MMP No. 2	- Principal Amount $5,430,000,

5

(256)	Bonds of Series T	- Principal Amount $75,000,000,
(257)	Bonds of Series U	- Principal Amount $75,000,000,
(258)	Bonds of 1986 Series B	- Principal Amount $100,000,000,
(259)	Bonds of 1987 Series D	- Principal Amount $250,000,000,
(260)	Bonds of 1987 Series E	- Principal Amount $150,000,000,
(261)	Bonds of 1987 Series C	- Principal Amount $225,000,000,
(262)	Bonds of Series V	- Principal Amount $100,000,000,
(263)	Bonds of Series SS	- Principal Amount $150,000,000,
(264)	Bonds of 1980 Series B	- Principal Amount $100,000,000,
(265)	Bonds of 1986 Series C	- Principal Amount $200,000,000,
(266)	Bonds of 1986 Series A	- Principal Amount $200,000,000,
(267)	Bonds of 1987 Series B	- Principal Amount $175,000,000,
(268)	Bonds of Series X	- Principal Amount $100,000,000,
(269)	Bonds of 1987 Series F	- Principal Amount $200,000,000,
(270)	Bonds of 1987 Series A	- Principal Amount $300,000,000,
(271)	Bonds of Series Y	- Principal Amount $60,000,000,
(272)	Bonds of Series Z	- Principal Amount $100,000,000,
(273)	Bonds of 1989 Series A	- Principal Amount $300,000,000,
(274)	Bonds of 1984 Series AP	- Principal Amount $2,400,000,
(275)	Bonds of 1984 Series BP	- Principal Amount $7,750,000,
(276)	Bonds of Series R	- Principal Amount $100,000,000,
(277)	Bonds of Series S	- Principal Amount $150,000,000,
(278)	Bonds of 1993 Series D	- Principal Amount $100,000,000,
(279)	Bonds of 1992 Series E	- Principal Amount $50,000,000,
(280)	Bonds of 1993 Series B	- Principal Amount $50,000,000,
(281)	Bonds of 1989 Series BP	- Principal Amount $66,565,000,

6

(282)	Bonds of 1990 Series A	- Principal Amount $194,649,000,
(283)	Bonds of 1990 Series D	- Principal Amount $0,
(284)	Bonds of 1993 Series G	- Principal Amount $225,000,000,
(285)	Bonds of 1993 Series K	- Principal Amount $160,000,000,
(286)	Bonds of 1991 Series EP	- Principal Amount $41,480,000,
(287)	Bonds of 1993 Series H	- Principal Amount $50,000,000,
(288)	Bonds of 1999 Series D	- Principal Amount $40,000,000,
(289)	Bonds of 1991 Series FP	- Principal Amount $98,375,000,
(290)	Bonds of 1992 Series BP	- Principal Amount $20,975,000,
(291)	Bonds of 1992 Series D	- Principal Amount $300,000,000,
(292)	Bonds of 1992 Series CP	- Principal Amount $35,000,000,
(293)	Bonds of 1993 Series C	- Principal Amount $225,000,000,
(294)	Bonds of 1993 Series E	- Principal Amount $400,000,000,
(295)	Bonds of 1993 Series J	- Principal Amount $300,000,000,
(296-301)	Bonds of Series KKP Nos. 10-15	- Principal Amount $179,590,000,
(302)	Bonds of 1989 Series BP No. 2	- Principal Amount $36,000,000,
(303)	Bonds of 1993 Series FP	- Principal Amount $5,685,000,
(304)	Bonds of 1993 Series IP	- Principal Amount $5,825,000,
(305)	Bonds of 1994 Series AP	- Principal Amount $7,535,000,
(306)	Bonds of 1994 Series BP	- Principal Amount $12,935,000,
(307)	Bonds of 1994 Series DP	- Principal Amount $23,700,000,
(308)	Bonds of 1994 Series C	- Principal Amount $200,000,000,
(309)	Bonds of 2000 Series A	- Principal Amount $220,000,000,
(310)	Bonds of 2005 Series A	- Principal Amount $200,000,000,
(311)	Bonds of 1995 Series AP	- Principal Amount $97,000,000,
(312)	Bonds of 1995 Series BP	- Principal Amount $22,175,000,

7

(313)	Bonds of 2001 Series D	- Principal Amount $200,000,000,
(314)	Bonds of 2005 Series B	- Principal Amount $200,000,000,
(315)	Bonds of 2006 Series CT	- Principal Amount $68,500,000,
(316)	Bonds of 2005 Series DT	- Principal Amount $119,175,000,
(317)	Bonds of 1991 Series AP	- Principal Amount $32,375,000,
(318)	Bonds of 2008 Series DT	- Principal Amount $68,500,000,
(319)	Bonds of 1993 Series AP	- Principal Amount $65,000,000,
(320)	Bonds of 2001 Series E	- Principal Amount $500,000,000,
(321)	Bonds of 2001 Series AP	- Principal Amount $31,000,000,
(322)	Bonds of 1991 Series BP	- Principal Amount $25,910,000,
(323)	Bonds of 2001 Series BP	- Principal Amount $82,350,000,
(324)	Bonds of 1999 Series AP	- Principal Amount $118,360,000,
(325)	Bonds of 1999 Series CP	- Principal Amount $66,565,000,
(326)	Bonds of 1999 Series BP	- Principal Amount $39,745,000,
(327)	Bonds of 2001 Series CP	- Principal Amount $139,855,000,
(328)	Bonds of 2000 Series B	- Principal Amount $50,745,000,
(329)	Bonds of 2002 Series A	- Principal Amount $225,000,000,
(330)	Bonds of 2002 Series C	- Principal Amount $64,300,000,
(331)	Bonds of 2002 Series D	- Principal Amount $55,975,000, and
(332)	Bonds of 2009 Series CT	- Principal Amount $65,000,000,
	all of which have either been retired and cancelled, or no longer represent obligations of the Company, having matured or having been called for redemption and funds necessary to effect the payment, redemption and retirement thereof having been deposited with the Trustee as a special trust fund to be applied for such purpose;
(333)	Bonds of 1990 Series B in the principal amount of Two hundred fifty-six million nine hundred thirty-two thousand dollars ($256,932,000) of which Two hundred twenty-eight million three hundred eighty-four thousand dollars ($228,384,000) principal amount have heretofore been retired;
(334)	Bonds of 1990 Series C in the principal amount of Eighty-five million four hundred seventy-five thousand dollars ($85,475,000) of which Eighty-two million fifty-six thousand dollars ($82,056,000) principal amount have heretofore been retired;

8

(335)	INTENTIONALLY RESERVED FOR 1990 SERIES E;
(336)	INTENTIONALLY RESERVED FOR 1990 SERIES F;
(337)	Bonds of 1991 Series CP in the principal amount of Thirty-two million eight hundred thousand dollars ($32,800,000), all of which are outstanding at the date hereof;
(338)	Bonds of 1991 Series DP in the principal amount of Thirty-seven million six hundred thousand dollars ($37,600,000), all of which are outstanding at the date hereof;
(339)	Bonds of 1992 Series AP in the principal amount of Sixty-six million dollars ($66,000,000), all of which are outstanding at the date hereof;
(340)	Bonds of 2002 Series B in the principal amount of Two hundred twenty-five million dollars ($225,000,000), all of which are outstanding at the date hereof;
(341)	Bonds of 2003 Series A in the principal amount of Forty-nine million dollars ($49,000,000), all of which are outstanding at the date hereof;
(342)	Bonds of 2004 Series A in the principal amount of Thirty-six million dollars ($36,000,000), all of which are outstanding at the date hereof;
(343)	Bonds of 2004 Series B in the principal amount of Thirty-one million nine hundred eighty thousand dollars ($31,980,000), all of which are outstanding at the date hereof;
(344)	Bonds of 2004 Series D in the principal amount of Two hundred million dollars ($200,000,000), all of which are outstanding at the date hereof;
(345)	Bonds of 2005 Series AR in the principal amount of Two hundred million dollars ($200,000,000), all of which are outstanding at the date hereof;
(346)	Bonds of 2005 Series BR in the principal amount of Two hundred million dollars ($200,000,000), all of which are outstanding at the date hereof;
(347)	Bonds of 2005 Series C in the principal amount of One hundred million dollars ($100,000,000), all of which are outstanding at the date hereof;
(348)	Bonds of 2005 Series E in the principal amount of Two hundred fifty million dollars ($250,000,000), all of which are outstanding at the date hereof;
(349)	Bonds of 2006 Series A in the principal amount of Two hundred fifty million dollars ($250,000,000), all of which are outstanding at the date hereof;
(350)	Bonds of 2007 Series A in the principal amount of Fifty million dollars ($50,000,000), all of which are outstanding at the date hereof;
(351)	Bonds of 2008 Series ET in the principal amount of One hundred nineteen million one hundred seventy-five thousand dollars ($119,175,000), all of which are outstanding at the date hereof;
(352)	Bonds of 2008 Series G in the principal amount of Three hundred million dollars ($300,000,000), all of which are outstanding at the date hereof;

9

(353)	Bonds of 2008 Series KT in the principal amount of Thirty-two million three hundred seventy-five thousand dollars ($32,375,000), all of which are outstanding at the date hereof;
(354)	Bonds of 2008 Series J in the principal amount of Two hundred fifty million dollars ($250,000,000), all of which are outstanding at the date hereof;
(355)	Bonds of 2008 Series LT in the principal amount of Fifty million dollars ($50,000,000), all of which are outstanding at the date hereof;
(356)	Bonds of 2009 Series BT in the principal amount of Sixty-eight million five hundred thousand dollars ($68,500,000), all of which are outstanding at the date hereof;
(357)	Bonds of 2010 Series B in the principal amount of Three hundred million dollars ($300,000,000), all of which are outstanding at the date hereof;
(358)	Bonds of 2010 Series A in the principal amount of Three hundred million dollars ($300,000,000), all of which are outstanding at the date hereof;
(359)	Bonds of 2010 Series CT in the principal amount of Nineteen million eight hundred fifty-five thousand dollars ($19,855,000), all of which are outstanding at the date hereof;
(360)	Bonds of 2011 Series AT in the principal amount of Thirty-one million dollars ($31,000,000), all of which are outstanding at the date hereof;
(361)	Bonds of 2011 Series B in the principal amount of Two hundred fifty million dollars ($250,000,000), all of which are outstanding at the date hereof;
(362)	Bonds of 2011 Series GT in the principal amount of Eight-two million three hundred fifty thousand dollars ($82,350,000), all of which are outstanding at the date hereof;
(363)	Bonds of 2011 Series D in the principal amount of One hundred two million dollars ($102,000,000), all of which are outstanding at the date hereof;
(364)	Bonds of 2011 Series E in the principal amount of Seventy-seven million dollars ($77,000,000), all of which are outstanding at the date hereof;
(365)	Bonds of 2011 Series F in the principal amount of Forty-six million dollars ($46,000,000), all of which are outstanding at the date hereof;
(366)	Bonds of 2011 Series H in the principal amount of One hundred forty million dollars ($140,000,000), all of which are outstanding at the date hereof;
(367)	Bonds of 2012 Series A in the principal amount of Two hundred fifty million dollars ($250,000,000), all of which are outstanding at the date hereof; and
(368)	Bonds of 2012 Series B in the principal amount of Two hundred fifty million dollars ($250,000,000), all of which are outstanding at the date hereof;
(369)	Bonds of 2013 Series A in the principal amount of Three hundred seventy-five million dollars ($375,000,000), all of which are outstanding at the date hereof;

10

	accordingly, the Company has issued and has presently outstanding Four billion, eight hundred three million, six hundred two thousand dollars ($4,803,602,000) aggregate principal amount of its General and Refunding Mortgage Bonds (the “Bonds”) at the date hereof.
REASON FOR CREATION OF NEW SERIES.	WHEREAS, the Company desires to issue a new series of bonds pursuant to the Indenture; and
BONDS TO BE 2013 SERIES B.	WHEREAS, the Company desires by this Supplemental Indenture to create a new series of bonds, to be designated “General and Refunding Mortgage Bonds, 2013 Series B,” in the aggregate principal amount of Four hundred million dollars ($400,000,000), to be authenticated and delivered pursuant to Section 8 of Article III of the Indenture; and
FURTHER ASSURANCE.	WHEREAS, the Original Indenture, by its terms, includes in the property subject to the lien thereof all of the estates and properties, real, personal and mixed, rights, privileges and franchises of every nature and kind and wheresoever situate, then or thereafter owned or possessed by or belonging to the Company or to which it was then or at any time thereafter might be entitled in law or in equity (saving and excepting, however, the property therein specifically excepted or released from the lien thereof), and the Company therein covenanted that it would, upon reasonable request, execute and deliver such further instruments as may be necessary or proper for the better assuring and confirming unto the Trustee all or any part of the trust estate, whether then or thereafter owned or acquired by the Company (saving and excepting, however, property specifically excepted or released from the lien thereof); and
AUTHORIZATION OF SUPPLEMENTAL INDENTURE.	WHEREAS, the Company in the exercise of the powers and authority conferred upon and reserved to it under and by virtue of the provisions of the Indenture, and pursuant to resolutions of its Board of Directors, has duly resolved and determined to make, execute and deliver to the Trustee a supplemental indenture in the form hereof for the purposes herein provided; and
	WHEREAS, all conditions and requirements necessary to make this Supplemental Indenture a valid and legally binding instrument in accordance with its terms have been done, performed and fulfilled, and the execution and delivery hereof have been in all respects duly authorized;
CONSIDERATION FOR SUPPLEMENTAL INDENTURE.	NOW, THEREFORE, THIS INDENTURE WITNESSETH: That DTE Electric Company, in consideration of the premises and of the covenants contained in the Indenture and of the sum of One Dollar ($1.00) and other good and valuable consideration to it duly paid by the Trustee at or before the ensealing and delivery of these presents, the receipt whereof is hereby acknowledged, hereby covenants and agrees to and with the Trustee and its successors in the trusts under the Original Indenture and in said indentures supplemental thereto as follows:

11

	PART I. CREATION OF THREE HUNDRED SEVENTIETH SERIES OF BONDS, GENERAL AND REFUNDING MORTGAGE BONDS, 2013 SERIES B
TERMS OF BONDS OF 2013 SERIES B.	SECTION 1. The Company hereby creates the three hundred seventieth series of bonds to be issued under and secured by the Original Indenture as amended to date and as further amended by this Supplemental Indenture, to be designated, and to be distinguished from the bonds of all other series, by the title “General and Refunding Mortgage Bonds, 2013 Series B” (elsewhere herein referred to as the “bonds of 2013 Series B”). The aggregate principal amount of bonds of 2013 Series B shall be limited to Four hundred million dollars ($400,000,000), except as provided in Sections 7 and 13 of Article II of the Original Indenture with respect to exchanges and replacements of bonds, and except further that the Company may, without the consent of any holder of the bonds of 2013 Series B, “reopen” the bonds of 2013 Series B, so long as any additional bonds of 2013 Series B have the same tenor and terms as the bonds of 2013 Series B established hereby.
	The bonds of 2013 Series B shall be issued as registered bonds without coupons in denominations of a multiple of $1,000. The bonds of 2013 Series B shall be issued in the aggregate principal amount of $400,000,000, shall mature on March 15, 2024 (subject to earlier redemption or release) and shall bear interest, payable semi-annually on March 15 and September 15 of each year (commencing March 15, 2014), at the rate of three and sixty-five hundredths percent (3.65%) per annum until the principal thereof shall have become due and payable and thereafter until the Company's obligation with respect to the payment of said principal shall have been discharged as provided in the Indenture. The bonds of 2013 Series B will be issued in book-entry form through the facilities of The Depository Trust Company. Except as otherwise specifically provided in this Supplemental Indenture, the bonds of 2013 Series B shall be payable, as to principal, premium, if any, and interest, at the office or agency of the Company in the Borough of Manhattan, the City and State of New York, in any coin or currency of the United States of America which at the time of payment is legal tender for public and private debts.
	Except as provided herein, each bond of 2013 Series B shall be dated the date of its authentication and interest shall be payable on the principal represented thereby from the March 15 or September 15 next preceding the date to which interest has been paid on bonds of 2013 Series B, unless the bond is authenticated on a date prior to March 15, 2014 in which case interest shall be payable from August 27, 2013.

12

The bonds of 2013 Series B in definitive form shall be, at the election of the Company, fully engraved or shall be lithographed or printed in authorized denominations as aforesaid and numbered R-1 and upwards (with such further designation as may be appropriate and desirable to indicate by such designation the form, series and denomination of bonds of 2013 Series B). Until bonds of 2013 Series B in definitive form are ready for delivery, the Company may execute, and upon its request in writing the Trustee shall authenticate and deliver in lieu thereof, bonds of 2013 Series B in temporary form, as provided in Section 10 of Article II of the Indenture. Temporary bonds of 2013 Series B if any, may be printed and may be issued in authorized denominations in substantially the form of definitive bonds of 2013 Series B, but without a recital of redemption prices and with such omissions, insertions and variations as may be appropriate for temporary bonds, all as may be determined by the Company.

Interest on any bond of 2013 Series B that is payable on any interest payment date and is punctually paid or duly provided for shall be paid to the person in whose name that bond, or any previous bond to the extent evidencing the same debt as that evidenced by that bond, is registered at the close of business on the regular record date for such interest, which regular record date shall be the fifteenth calendar day (whether or not such day is a business day) immediately preceding the applicable interest payment date. If the Company shall default in the payment of the interest due on any interest payment date on the principal represented by any bond of 2013 Series B, such defaulted interest shall forthwith cease to be payable to the registered holder of that bond on the relevant regular record date by virtue of his having been such holder, and such defaulted interest may be paid to the registered holder of that bond (or any bond or bonds of 2013 Series B issued upon transfer or exchange thereof) on the date of payment of such defaulted interest or, at the election of the Company, to the person in whose name that bond (or any bond or bonds of 2013 Series B issued upon transfer or exchange thereof) is registered on a subsequent record date established by notice given by mail by or on behalf of the Company to the holders of bonds of 2013 Series B not less than ten (10) days preceding such subsequent record date, which subsequent record date shall be at least five (5) days prior to the payment date of such defaulted interest. Interest will be computed on the basis of a 360-day year of twelve 30-day months.

Bonds of 2013 Series B, in definitive and temporary form, may bear such legends as may be necessary to comply with any law or with any rules or regulations made pursuant thereto.

If any interest payment date, date of redemption or the stated maturity for the bonds of 2013 Series B would otherwise be a day that is not a business day, payment of principal and/or interest or premium, if any, with respect to the bonds of 2013 Series B will be paid on the next succeeding business day with the same force and effect as if made on such date and no interest on such payment will accrue from and after such date.

“Business day” means any day other than a day on which banking institutions in The State of New York or the State of Michigan are authorized or obligated pursuant to law or executive order to close.

13

REDEMPTION OF BONDS OF 2013 SERIES B.	SECTION 2. Bonds of 2013 Series B will be redeemable at the option of the Company, in whole at any time or in part from time to time at the redemption prices set forth below.
	At any time prior to December 15, 2023, the optional redemption price will be equal to the greater of (i) 100% of the principal amount of the bonds of 2013 Series B to be redeemed and (ii) the sum of the present values of the remaining scheduled payments of principal and interest of the bonds of 2013 Series B to be redeemed (not including any portion of any payments of interest accrued to the redemption date) until stated maturity, in each case discounted from their respective scheduled payment dates to such redemption date on a semiannual basis (assuming a 360-day year consisting of 30-day months) at the Adjusted Treasury Rate (as defined below) plus 15 basis points, as determined by the Reference Treasury Dealer (as defined below), plus, in each case, accrued and unpaid interest thereon to the redemption date.
	At any time on or after December 15, 2023, the optional redemption price will be equal to 100% of the principal amount of the bonds of 2013 Series B to be redeemed plus accrued and unpaid interest thereon to the redemption date.
	Notwithstanding the foregoing, installments of interest on the bonds of 2013 Series B that are due and payable on interest payment dates falling on or prior to a redemption date will be payable on the interest payment date to the registered holders as of the close of business on the relevant record date.
	“Adjusted Treasury Rate” means, with respect to any optional redemption date, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue (as defined below), calculated on the third Business Day preceding such redemption date assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.
	“Comparable Treasury Issue” means the United States Treasury security selected by the Reference Treasury Dealer as having a maturity comparable to the remaining term of the bonds of 2013 Series B that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of the bonds of 2013 Series B.
	“Comparable Treasury Price” means, with respect to any optional redemption date, (i) the average of the Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if the Trustee obtains fewer than three such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.
	“Reference Treasury Dealer”means (i) each of BNP Paribas Securities Corp., Citigroup Global Markets Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated and Scotia Capital (USA) Inc. (or their respective affiliates which are Primary Treasury Dealers), and their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. government securities dealer in the United States (a “Primary Treasury Dealer”), we will substitute therefor another Primary Treasury Dealer, and (ii) any other Primary Treasury Dealer(s) selected by the mortgage trustee after consultation with us.

14

	“Reference Treasury Dealer Quotation” means, with respect to each Reference Treasury Dealer and any optional redemption date, the average, as determined by the Trustee, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Trustee by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such redemption date.
	The bonds of 2013 Series B shall be redeemable as aforesaid upon giving notice of such redemption by first class mail, postage prepaid, by or on behalf of the Company at least thirty (30) days, but not more than sixty (60) days, prior to the date fixed for redemption to the registered holders of bonds of 2013 Series B so called for redemption at their last respective addresses appearing on the register thereof, but failure to mail such notice to the registered holders of any bonds of 2013 Series B designated for redemption shall not affect the validity of any such redemption of any other bonds of such series. Interest shall cease to accrue on any bonds of 2013 Series B (or any portion thereof) so called for redemption from and after the date fixed for redemption if payment sufficient to redeem the bonds of 2013 Series B (or such portion) designated for redemption has been duly provided for. Bonds of 2013 Series B redeemed in part only shall be in amounts of $1,000 or any multiple thereof.
	If the giving of the notice of redemption shall have been completed, or if provision satisfactory to the Trustee for the giving of such notice shall have been made, and if the Company shall have deposited with the Trustee in trust funds (which shall have become available for payment to the holders of the bonds of 2013 Series B so to be redeemed) sufficient to redeem bonds of 2013 Series B in whole or in part, on the date fixed for redemption, then all obligations of the Company in respect of such bonds (or portions thereof) so to be redeemed and interest due or to become due thereon shall cease and be discharged and the holders of such bonds of 2013 Series B (or portions thereof) shall thereafter be restricted exclusively to such funds for any and all claims of whatsoever nature on their part under the Indenture or in respect of such bonds (or portions thereof) and interest.
	The bonds of 2013 Series B shall not be entitled to or subject to any sinking fund and shall not be redeemable other than as provided in Section 2 hereof.
EXCHANGE AND TRANSFER.	SECTION 3. At the option of the registered holder, any bonds of 2013 Series B, upon surrender thereof for cancellation at the office or agency of the Company in the Borough of Manhattan, the City and State of New York, together with a written instrument of transfer (if so required by the Company or by the Trustee) in form approved by the Company duly executed by the holder or by its duly authorized attorney, shall be exchangeable for a like aggregate principal amount of bonds of 2013 Series B upon the terms and conditions specified herein and in Section 7 of Article II of the Indenture. The Company waives its rights under Section 7 of Article II of the Indenture not to make exchanges or transfers of bonds of 2013 Series B during any period of ten (10) days next preceding any redemption date for such bonds.
	Bonds of 2013 Series B, in definitive and temporary form, may bear such legends as may be necessary to comply with any law or with any rules or regulations made pursuant thereto.

15

FORM OF BONDS OF 2013 SERIES B.	SECTION 4. The bonds of 2013 Series B and the form of Trustee's Certificate to be endorsed on such bonds shall be substantially in the following forms, respectively:
	DTE ELECTRIC COMPANY GENERAL AND REFUNDING MORTGAGE BOND 2013 SERIES B
	[This bond is a global security within the meaning of the indenture hereinafter referred to and is registered in the name of a depository or a nominee of a depository. Unless and until it is exchanged in whole or in part for bonds in certificated form, this bond may not be transferred except as a whole by the Depository Trust Company (“DTC”) to a nominee of DTC or by DTC or any such nominee to a successor of DTC or any such nominee to a successor of DTC or a nominee of such successor. Unless this bond is presented by an authorized representative of DTC to the issuer or its agent for registration of transfer, exchange or payment, and any bond issued is registered in the name of Cede & Co. or in such other name as requested by an authorized representative of DTC (and any payment hereon is made to Cede & Co., or to such other entity as is requested by an authorized representative of DTC) any transfer, pledge or other use hereof for value or otherwise by a person is wrongful, inasmuch as the registered owner hereof, Cede & Co., has an interest herein.]
	CUSIP
	$______________ No. R-___
	DTE ELECTRIC COMPANY (hereinafter called the “Company”), a corporation of the State of Michigan, for value received, hereby promises to pay to [Cede & Co.], or registered assigns, at the Company's office or agency in the Borough of Manhattan, the City and State of New York, the principal sum of ________________________Dollars ($___________) in lawful money of the United States of America on March 15, 2024 (subject to earlier redemption or release) and interest thereon at the rate of 3.65% per annum, in like lawful money, from August 27, 2013 and after the first payment of interest on bonds of this Series has been made or otherwise provided for, from the most recent date to which interest has been paid or otherwise provided for, semi-annually on March 15 and September 15 of each year (commencing March 15, 2014), until the Company's obligation with respect to payment of said principal shall have been discharged, all as provided, to the extent and in the manner specified in the Indenture hereinafter mentioned and in the supplemental indenture pursuant to which this bond has been issued.
	This bond is one of an authorized issue of bonds of the Company, unlimited as to amount except as provided in the Indenture hereinafter mentioned or any indentures supplemental thereto, and is one of a series of General and Refunding Mortgage Bonds known as 2013 Series B, limited to an aggregate principal amount of $400,000,000, except as otherwise provided in the Indenture hereinafter mentioned. This bond and all other bonds of said series are issued and to be issued under, and are all equally and ratably secured (except insofar as any sinking, amortization, improvement or analogous fund, established in accordance with the provisions of the Indenture hereinafter mentioned, may afford additional security for the bonds of any particular series and except as provided in Section 3 of Article VI of said Indenture) by an
	This bond is one of an authorized issue of bonds of the Company, unlimited as to amount except as provided in the Indenture hereinafter mentioned or any indentures supplemental thereto, and is one of a series of General and Refunding Mortgage Bonds known as 2013 Series B, limited to an aggregate principal amount of $400,000,000, except as otherwise provided in the Indenture hereinafter mentioned. This bond and all other bonds of said series are issued and to be issued under, and are all equally and ratably secured (except insofar as any sinking, amortization, improvement or analogous fund, established in accordance with the provisions of the Indenture hereinafter mentioned, may afford additional security for the bonds of any particular series and except as provided in Section 3 of Article VI of said Indenture) by an

16

Indenture, dated as of October 1, 1924, duly executed by the Company to The Bank of New York Mellon Trust Company, N.A., as successor Trustee, to which Indenture and all indentures supplemental thereto (including the Supplemental Indenture dated as of August 1, 2013) reference is hereby made for a description of the properties and franchises mortgaged and conveyed, the nature and extent of the security, the terms and conditions upon which the bonds are issued and under which additional bonds may be issued, and the rights of the holders of the bonds and of the Trustee in respect of such security (which Indenture and all indentures supplemental thereto, including the Supplemental Indenture dated as of August 1, 2013, are hereinafter collectively called the “Indenture”). As provided in the Indenture, said bonds may be for various principal sums and are issuable in series, which may mature at different times, may bear interest at different rates and may otherwise vary as in said Indenture provided. With the consent of the Company and to the extent permitted by and as provided in the Indenture, the rights and obligations of the Company and of the holders of the bonds and the terms and provisions of the Indenture, or of any indenture supplemental thereto, may be modified or altered in certain respects by affirmative vote of at least eighty-five percent (85%) in amount of the bonds then outstanding, and, if the rights of one or more, but less than all, series of bonds then outstanding are to be affected by the action proposed to be taken, then also by affirmative vote of at least eighty-five percent (85%) in amount of the series of bonds so to be affected (excluding in every instance bonds disqualified from voting by reason of the Company's interest therein as specified in the Indenture); provided, however, that, without the consent of the holder hereof, no such modification or alteration shall, among other things, affect the terms of payment of the principal of or the interest on this bond, which in those respects is unconditional.

This bond is not subject to repayment at the option of the holder hereof. Except as provided below, this bond is not redeemable by the Company prior to maturity and is not subject to any sinking fund.

This bond will be redeemable at the option of the Company, in whole at any time or in part from time to time at the redemption prices set forth below. At any time prior to December 15, 2023, the optional redemption price will be equal to the greater of (i) 100% of the principal amount of this bond to be redeemed and (ii) the sum of the present values of the remaining scheduled payments of principal and interest of this bond to be redeemed (not including any portion of any payments of interest accrued to the optional redemption date) until stated maturity, in each case discounted from their respective scheduled payment dates to such redemption date on a semiannual basis (assuming a 360-day year consisting of 30-day months) at the Adjusted Treasury Rate (as defined below) plus 15 basis points, as determined by the Reference Treasury Dealer (as defined below), plus, in each case, accrued and unpaid interest thereon to the redemption date. At any time on or after December 15, 2023, the optional redemption price will be equal to 100% of the principal amount of this bond to be redeemed plus accrued and unpaid interest thereon to the redemption date.

Notwithstanding the foregoing, installments of interest on this bond that are due and payable on interest payment dates falling on or prior to a redemption date will be payable on the interest payment date to the registered holders as of the close of business on the relevant record date.

17

“Adjusted Treasury Rate” means, with respect to any optional redemption date, the rate per annum equal to the semiannual equivalent yield to maturity of the Comparable Treasury Issue, calculated on the third Business Day preceding such redemption date assuming a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date.

“Comparable Treasury Issue” means the United States Treasury security selected by the Reference Treasury Dealer as having a maturity comparable to the remaining term of this bond that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities of comparable maturity to the remaining term of this bond.

“Comparable Treasury Price” means, with respect to any optional redemption date, (i) the average of the Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (ii) if the Trustee obtains fewer than three such Reference Treasury Dealer Quotations, the average of all such quotations, or (iii) if only one Reference Treasury Dealer Quotation is received, such quotation.

“Reference Treasury Dealer”means (i) each of BNP Paribas Securities Corp., Citigroup Global Markets Inc., Merrill Lynch, Pierce, Fenner & Smith Incorporated and Scotia Capital (USA) Inc. (or their respective affiliates which are Primary Treasury Dealers), and their respective successors; provided, however, that if any of the foregoing shall cease to be a primary U.S. government securities dealer in the United States (a “Primary Treasury Dealer”), we will substitute therefor another Primary Treasury Dealer, and (ii) any other Primary Treasury Dealer(s) selected by the mortgage trustee after consultation with us.

“Reference Treasury Dealer Quotation” means, with respect to each Reference Treasury Dealer and any optional redemption date, the average, as determined by the Trustee, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Trustee by such Reference Treasury Dealer at 5:00 p.m., New York City time, on the third Business Day preceding such redemption date.

Notice of any optional redemption will be mailed at least 30 days but not more than 60 days before the optional redemption date to the holder hereof at its registered address. If notice has been provided in accordance with the Indenture and funds for the redemption of this bond called for redemption have been made available on the redemption date, this bond will cease to bear interest on the date fixed for redemption. Thereafter, the only right of the holder hereof will be to receive payment of the redemption price.

Under the Indenture, funds may be deposited with the Trustee (which shall have become available for payment), in advance of the redemption date of any of the bonds of 2013 Series B (or portions thereof), in trust for the redemption of such bonds (or portions thereof) and the interest due or to become due thereon, and thereupon all obligations of the Company in respect of such bonds (or portions thereof) so to be redeemed and such interest shall cease and be discharged, and the holders thereof shall thereafter be restricted exclusively to such funds for any and all claims of whatsoever nature on their part under the Indenture or with respect to such bonds (or portions thereof) and interest.

18

In case an event of default, as defined in the Indenture, shall occur, the principal of all the bonds issued thereunder may become or be declared due and payable, in the manner, with the effect and subject to the conditions provided in the Indenture.

The bonds of this series are issuable only in fully registered form without coupons in denominations of $1,000 and any integral multiple thereof. This Global Security is exchangeable for bonds in definitive form only under certain limited circumstances set forth in the Indenture. As provided in the Indenture and subject to certain limitations therein set forth, bonds of this series are exchangeable for a like aggregate principal amount of bonds of this series of a different authorized denomination, as requested by the registered holder surrendering the same.

This bond is transferable by the registered holder hereof, in person or by his attorney duly authorized in writing, on the books of the Company kept at its office or agency in the Borough of Manhattan, the City and State of New York, upon surrender and cancellation of this bond, and thereupon, a new registered bond of the same series of authorized denominations for a like aggregate principal amount will be issued to the transferee in exchange therefor, and this bond with others in like form may in like manner be exchanged for one or more new bonds of the same series of other authorized denominations, but of the same aggregate principal amount, all as provided and upon the terms and conditions set forth in the Indenture, and upon payment, in any event, of the charges prescribed in the Indenture.

No recourse shall be had for the payment of the principal of or the interest on this bond, or for any claim based hereon or otherwise in respect hereof or of the Indenture, or of any indenture supplemental thereto, against any incorporator, or against any past, present or future stockholder, director or officer, as such, of the Company, or of any predecessor or successor corporation, either directly or through the Company or any such predecessor or successor corporation, whether for amounts unpaid on stock subscriptions or by virtue of any constitution, statute or rule of law, or by the enforcement of any assessment or penalty or otherwise howsoever; all such liability being, by the acceptance hereof and as part of the consideration for the issue hereof, expressly waived and released by every holder or owner hereof, as more fully provided in the Indenture.

This bond shall not be valid or become obligatory for any purpose until The Bank of New York Mellon Trust Company, N.A., the Trustee under the Indenture, or its successor thereunder, shall have signed the form of certificate endorsed hereon.

19

	IN WITNESS WHEREOF, DTE ELECTRIC COMPANY has caused this instrument to be executed by an authorized officer, with his or her manual or facsimile signatures, and its corporate seal, or a facsimile thereof, to be impressed or imprinted hereon and the same to be attested by its Corporate Secretary or Assistant Corporate Secretary by manual or facsimile signature.
	Dated: _____________ DTE ELECTRIC COMPANY
	By:_________________________________ Name: Title:
	[Corporate Seal]
	Attest: By:____________________________ Name: Title:
	[FORM OF TRUSTEE'S CERTIFICATE]
FORM OF TRUSTEE'S CERTIFICATE.	This bond is one of the bonds, of the series designated therein, described in the within-mentioned Indenture.
	THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., as Trustee
	By:_________________________________        Authorized Representative

	PART III.
	RECORDING AND FILING DATA
RECORDING AND FILING OF ORIGINAL INDENTURE.	The Original Indenture and indentures supplemental thereto have been recorded and/or filed and Certificates of Provision for Payment have been recorded as hereinafter set forth.
	The Original Indenture has been recorded as a real estate mortgage and filed as a chattel Mortgage in the offices of the respective Registers of Deeds of certain counties in the State of Michigan as set forth in the Supplemental Indenture dated as of September 1, 1947, has been recorded as a real estate mortgage in the office of the Register of Deeds of Mason County, Michigan as set forth in the Supplemental Indenture dated as of June 15, 1971, has been recorded as a real estate mortgage in the office of the Register of Deeds of Genesee County, Michigan as set forth in the Supplemental Indenture dated as of May 1, 1974, has been recorded as a real estate mortgage in the office of the Register of Deeds of Gratiot County, Michigan on June 18, 2012 at Liber 923 Page 772, has been recorded as a real estate mortgage in the office of the Register of Deeds of Midland County, Michigan on June 18, 2012 at Liber 1555 Page 504, has been filed in the Office of the Secretary of State of Michigan on November 16, 1951 and has been filed and recorded in the office of the Interstate Commerce Commission on December 8, 1969.

20

has been recorded as a real estate mortgage in the office of the Register of Deeds of Midland County, Michigan on June 18, 2012 at Liber 1555 Page 504, has been filed in the Office of the Secretary of State of Michigan on November 16, 1951 and has been filed and recorded in the office of the Interstate Commerce Commission on December 8, 1969.

RECORDING AND FILING OF SUPPLEMENTAL INDENTURES.

Pursuant to the terms and provisions of the Original Indenture, indentures supplemental thereto heretofore entered into have been Recorded as a real estate mortgage and/or filed as a chattel mortgage or as a financing statement in the offices of the respective Registers of Deeds of certain counties in the State of Michigan, the Office of the Secretary of State of Michigan and the Office of the Interstate Commerce Commission or the Surface Transportation Board, as set forth in supplemental indentures as follows:

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTALINDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
June 1, 1925(a)(b)	Series B Bonds	February 1, 1940
August 1, 1927(a)(b)	Series C Bonds	February 1, 1940
February 1, 1931(a)(b)	Series D Bonds	February 1, 1940
June 1, 1931(a)(b)	Subject Properties	February 1, 1940
October 1, 1932(a)(b)	Series E Bonds	February 1, 1940
September 25, 1935(a)(b)	Series F Bonds	February 1, 1940
September 1, 1936(a)(b)	Series G Bonds	February 1, 1940
November 1, 1936(a)(b)	Subject Properties	February 1, 1940
February 1, 1940(a)(b)	Subject Properties	September 1, 1947
December 1, 1940(a)(b)	Series H Bonds and Additional Provisions	September 1, 1947
September 1, 1947(a)(b)(c)	Series I Bonds, Subject Properties and Additional Provisions	November 15, 1951
March 1, 1950(a)(b)(c)	Series J Bonds and Additional Provisions	November 15, 1951
November 15, 1951(a)(b)(c)	Series K Bonds, Additional Provisions and Subject Properties	January 15, 1953
January 15, 1953(a)(b)	Series L Bonds	May 1, 1953
May 1, 1953(a)	Series M Bonds and Subject Properties	March 15, 1954
March 15, 1954(a)(c)	Series N Bonds and Subject Properties	May 15, 1955
May 15, 1955(a)(c)	Series O Bonds and Subject Properties	August 15, 1957
August 15, 1957(a)(c)	Series P Bonds, Additional Provisions and Subject Properties	June 1, 1959
June 1, 1959(a)(c)	Series Q Bonds and Subject Properties	December 1, 1966
December 1, 1966(a)(c)	Series R Bonds, Additional Provisions and Subject Properties	October 1, 1968
October 1, 1968(a)(c)	Series S Bonds and Subject Properties	December 1, 1969
December 1, 1969(a)(c)	Series T Bonds and Subject Properties	July 1, 1970

21

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTALINDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
July 1, 1970(c)	Series U Bonds and Subject Properties	December 15, 1970
December 15, 1970(c)	Series V Bonds and Series W Bonds	June 15, 1971
June 15, 1971(c)	Series X Bonds and Subject Properties	November 15, 1971
November 15, 1971(c)	Series Y Bonds and Subject Properties	January 15, 1973
January 15, 1973(c)	Series Z Bonds and Subject Properties	May 1, 1974
May 1, 1974	Series AA Bonds and Subject Properties	October 1, 1974
October 1, 1974	Series BB Bonds and Subject Properties	January 15, 1975
January 15, 1975	Series CC Bonds and Subject Properties	November 1, 1975
November 1, 1975	Series DDP Nos. 1-9 Bonds and Subject Properties	December 15, 1975
December 15, 1975	Series EE Bonds and Subject Properties	February 1, 1976
February 1, 1976	Series FFR Nos. 1-13 Bonds	June 15, 1976
June 15, 1976	Series GGP Nos. 1-7 Bonds and Subject Properties	July 15, 1976
July 15, 1976	Series HH Bonds and Subject Properties	February 15, 1977
February 15, 1977	Series MMP Bonds and Subject Properties	March 1, 1977
March 1, 1977	Series IIP Nos. 1-7 Bonds, Series JJP Nos. 1-7 Bonds, Series KKP Nos. 1-7 Bonds and Series LLP Nos. 1-7 Bonds	June 15, 1977
June 15, 1977	Series FFR No. 14 Bonds and Subject Properties	July 1, 1977
July 1, 1977	Series NNP Nos. 1-7 Bonds and Subject Properties	October 1, 1977
October 1, 1977	Series GGP Nos. 8-22 Bonds and Series OOP Nos. 1-17 Bonds and Subject Properties	June 1, 1978
June 1, 1978	Series PP Bonds, Series QQP Nos. 1-9 Bonds and Subject Properties	October 15, 1978
October 15, 1978	Series RR Bonds and Subject Properties	March 15, 1979
March 15, 1979	Series SS Bonds and Subject Properties	July 1, 1979

22

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTALINDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
July 1, 1979	Series IIP Nos. 8-22 Bonds, Series NNP Nos. 8-21 Bonds and Series TTP Nos. 1-15 Bonds and Subject Properties	September 1, 1979
September 1, 1979	Series JJP No. 8 Bonds, Series KKP No. 8 Bonds, Series LLP Nos. 8-15 Bonds, Series MMP No. 2 Bonds and Series OOP No. 18 Bonds and Subject Properties	September 15, 1979
September 15, 1979	Series UU Bonds	January 1, 1980
January 1, 1980	1980 Series A Bonds and Subject Properties	April 1, 1980
April 1, 1980	1980 Series B Bonds	August 15, 1980
August 15, 1980	Series QQP Nos. 10-19 Bonds, 1980 Series CP Nos. 1-12 Bonds and 1980 Series DP No. 1-11 Bonds and Subject Properties	August 1, 1981
August 1, 1981	1980 Series CP Nos. 13-25 Bonds and Subject Properties	November 1, 1981
November 1, 1981	1981 Series AP Nos. 1-12 Bonds	June 30, 1982
June 30, 1982	Article XIV Reconfirmation	August 15, 1982
August 15, 1982	1981 Series AP Nos. 13-14 Bonds and Subject Properties	June 1, 1983
June 1, 1983	1981 Series AP Nos. 15-16 Bonds and Subject Properties	October 1, 1984
October 1, 1984	1984 Series AP Bonds and 1984 Series BP Bonds and Subject Properties	May 1, 1985
May 1, 1985	1985 Series A Bonds	May 15, 1985
May 15, 1985	1985 Series B Bonds and Subject Properties	October 15, 1985
October 15, 1985	Series KKP No. 9 Bonds and Subject Properties	April 1, 1986
April 1, 1986	1986 Series A Bonds and Subject Properties	August 15, 1986
August 15, 1986	1986 Series B Bonds and Subject Properties	November 30, 1986
November 30, 1986	1986 Series C Bonds	January 31, 1987
January 31, 1987	1987 Series A Bonds	April 1, 1987
April 1, 1987	1987 Series B Bonds and 1987 Series C Bonds	August 15, 1987
August 15, 1987	1987 Series D Bonds, 1987 Series E Bonds and Subject Properties	November 30, 1987
November 30, 1987	1987 Series F Bonds	June 15, 1989
June 15, 1989	1989 Series A Bonds	July 15, 1989
July 15, 1989	Series KKP No. 10 Bonds	December 1, 1989
December 1, 1989	Series KKP No. 11 Bonds and 1989 Series BP Bonds	February 15, 1990

23

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTALINDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
February 15, 1990	1990 Series A Bonds, 1990 Series B Bonds, 1990 Series C Bonds, 1990 Series D Bonds, 1990 Series E Bonds and 1990 Series F Bonds	November 1, 1990
November 1, 1990	Series KKP No. 12 Bonds	April 1, 1991
April 1, 1991	1991 Series AP Bonds	May 1, 1991
May 1, 1991	1991 Series BP Bonds and 1991 Series CP Bonds	May 15, 1991
May 15, 1991	1991 Series DP Bonds	September 1, 1991
September 1, 1991	1991 Series EP Bonds	November 1, 1991
November 1, 1991	1991 Series FP Bonds	January 15, 1992
January 15, 1992	1992 Series BP Bonds	February 29, 1992 and April 15, 1992
February 29, 1992	1992 Series AP Bonds	April 15, 1992
April 15, 1992	Series KKP No. 13 Bonds	July 15, 1992
July 15, 1992	1992 Series CP Bonds	November 30, 1992
July 31, 1992	1992 Series D Bonds	November 30, 1992
November 30, 1992	1992 Series E Bonds and 1993 Series B Bonds	March 15, 1993
December 15, 1992	Series KKP No. 14 Bonds and 1989 Series BP No. 2 Bonds	March 15, 1993
January 1, 1993	1993 Series C Bonds	April 1, 1993
March 1, 1993	1993 Series E Bonds	June 30, 1993
March 15, 1993	1993 Series D Bonds	September 15, 1993
April 1, 1993	1993 Series FP Bonds and 1993 Series IP Bonds	September 15, 1993
April 26, 1993	1993 Series G Bonds and Amendment of Article II, Section 5	September 15, 1993
May 31, 1993	1993 Series J Bonds	September 15, 1993
June 30, 1993	1993 Series AP Bonds	(d)
June 30, 1993	1993 Series H Bonds	(d)
September 15, 1993	1993 Series K Bonds	March 1, 1994
March 1, 1994	1994 Series AP Bonds	June 15, 1994
June 15, 1994	1994 Series BP Bonds	December 1, 1994
August 15, 1994	1994 Series C Bonds	December 1, 1994
December 1, 1994	Series KKP No. 15 Bonds and 1994 Series DP Bonds	August 1, 1995
August 1, 1995	1995 Series AP Bonds and 1995 Series BP Bonds	August 1, 1999
August 1, 1999	1999 Series AP Bonds, 1999 Series BP Bonds and 1999 Series CP Bonds	(d)
August 15, 1999	1999 Series D Bonds	(d)
January 1, 2000	2000 Series A Bonds	(d)
April 15, 2000	Appointment of Successor Trustee	(d)
August 1, 2000	2000 Series BP Bonds	(d)

24

SUPPLEMENTAL INDENTURE DATED AS OF	PURPOSE OF SUPPLEMENTALINDENTURE	RECORDED AND/OR FILED AS SET FORTH IN SUPPLEMENTAL INDENTURE DATED AS OF
March 15, 2001	2001 Series AP Bonds	(d)
May 1, 2001	2001 Series BP Bonds	(d)
August 15, 2001	2001 Series CP Bonds	(d)
September 15, 2001	2001 Series D Bonds and 2001 Series E Bonds	(d)
September 17, 2002	Amendment of Article XIII, Section 3 and Appointment of Successor Trustee	(d)
October 15, 2002	2002 Series A Bonds and 2002 Series B Bonds	(d)
December 1, 2002	2002 Series C Bonds and 2002 Series D Bonds	(d)
August 1, 2003	2003 Series A Bonds	(d)
March 15, 2004	2004 Series A Bonds and 2004 Series B Bonds	(d)
July 1, 2004	2004 Series D Bonds	(d)
February 1, 2005	2005 Series A Bonds and 2005 Series B Bonds	May 15, 2006
April 1, 2005	2005 Series AR Bonds and 2005 Series BR Bonds	May 15, 2006
August 1, 2005	2005 Series DT Bonds	May 15, 2006
September 15, 2005	2005 Series C Bonds	May 15, 2006
September 30, 2005	2005 Series E Bonds	May 15, 2006
May 15, 2006	2006 Series A Bonds	December 1, 2006
December 1, 2006	2006 Series CT Bonds	December 1, 2007
December 1, 2007	2007 Series A Bonds	April 1, 2008
April 1, 2008	2008 Series DT Bonds	May 1, 2008
May 1, 2008	2008 Series ET Bonds	July 1, 2008
June 1, 2008	2008 Series G Bonds	October 1, 2008
July 1, 2008	2008 Series KT Bonds	October 1, 2008
October 1, 2008	2008 Series J Bonds	December 1, 2008
December 1, 2008	2008 Series LT Bonds	March 15, 2009
March 15, 2009	2009 Series BT Bonds	November 1, 2009
November 1, 2009	2009 Series CT Bonds	August 1, 2010
August 1, 2010	2010 Series B Bonds	December 1, 2010
September 1, 2010	2010 Series A Bonds	December 1, 2010
December 1, 2010	2010 Series CT Bonds	March 1, 2011
March 1, 2011	2011 Series AT Bonds	May 15, 2011
May 15, 2011	2011 Series B Bonds	August 1, 2011
August 1, 2011	2011 Series GT Bonds	June 20, 2012
August 15, 2012	2011 Series D, 2011 Series E and 2011 Series F Bonds	June 20, 2012
September 1, 2012	2011 Series H Bonds	June 20, 2012
June 20, 2012	2012 Series A and B Bonds	March 15, 2013

(a) See Supplemental Indenture dated as of July 1, 1970 for Interstate Commerce Commission filing and recordation information.

25

(b) See Supplemental Indenture dated as of May 1, 1953 for Secretary of State of Michigan filing information.

(c) See Supplemental Indenture dated as of May 1, 1974 for County of Genesee, Michigan recording and filing information.

(d) Recording and filing information for this Supplemental Indenture has not been set forth in a subsequent Supplemental Indenture.

RECORDING AND FILING OF SUPPLEMENTAL INDENTURE DATED AS OF MARCH 15, 2013.	Further, pursuant to the terms and provisions of the Original Indenture, a Supplemental Indenture dated as of March 15, 2013 providing for the terms of bonds to be issued thereunder of 2013 Series A has heretofore been entered into between the Company and the Trustee and has been filed in the Office of the Secretary of State of Michigan as a financing statement on March 29, 2013 (Filing No. 2013044537-8), has been filed and recorded in the Office of the Surface Transportation Board on March 29, 2013 (Recordation No. 5485-HHHHHH), and has been recorded as a real estate mortgage in the offices of the respective Register of Deeds of certain counties in the State of Michigan, as follows:
County		Recorded	Liber/ Instrument no.	Page
Genesee		4/4/2013	2013304040047956	NA
Gratiot		3/29/2013	938	473
Huron		4/1/2013	1441	625
Ingham		4/18/2013	2013-020713	NA
Lapeer		3/29/2013	2632	906
Lenawee		3/29/2013	2465	130
Livingston		3/29/2013	2013R-012310	NA
Macomb		5/21/2013	22119	806
Mason		3/29/2013	2013R02137	NA
Midland		4/1/2013	01565	77
Monroe		3/29/2013	2013R09003	NA
Oakland		4/18/2013	45681	476
St. Clair		3/29/2013	4376	1
Sanilac		4/1/2013	1199	454
Tuscola		4/1/2013	1275	850
Washtenaw		3/29/2013	4968	325
Wayne		4/1/2013	50690	1,300

RECORDING OF CERTIFICATES OF PROVISION FOR PAYMENT.	Certificates of Provision for Payment have been recorded in the offices of the respective Registers of Deeds of certain counties in the State of Michigan, with respect to all bonds of Series A, B, C, D, E, F, G, H, K, L, M, O, W, BB, CC, DDP Nos. 1 and 2, FFR Nos. 1-3, GGP Nos. 1 and 2, IIP No. 1, JJP No. 1, KKP No. 1, LLP No. 1 and GGP No. 8.
	PART IV.
	THE TRUSTEE.
TERMS AND CONDITIONS OF ACCEPTANCE OF TRUST BY TRUSTEE.	The Trustee hereby accepts the trust hereby declared and provided, and agrees to perform the same upon the terms and conditions in the Original Indenture, as amended to date and as supplemented by this Supplemental Indenture, and in this Supplemental Indenture set forth, and upon the following terms and conditions:

26

The Trustee shall not be responsible in any manner whatsoever for and in respect of the validity or sufficiency of this Supplemental Indenture or the due execution hereof by the Company or for or in respect of the recitals contained herein, all of which recitals are made by the Company solely.

	PART V.
	MISCELLANEOUS.
CONFIRMATION OF SECTION 318(c) OF TRUST INDENTURE ACT.	Except to the extent specifically provided therein, no provision of this Supplemental Indenture or any future supplemental indenture is intended to modify, and the parties do hereby adopt and confirm, the provisions of Section 318(c) of the Trust Indenture Act which amend and supersede provisions of the Indenture in effect prior to November 15, 1990.
EXECUTION IN COUNTERPARTS.	THIS SUPPLEMENTAL INDENTURE MAY BE SIMULTANEOUSLY EXECUTED IN ANY NUMBER OF COUNTERPARTS, EACH OF WHICH WHEN SO EXECUTED SHALL BE DEEMED TO BE AN ORIGINAL; BUT SUCH COUNTERPARTS SHALL TOGETHER CONSTITUTE BUT ONE AND THE SAME INSTRUMENT.
TESTIMONIUM.	IN WITNESS WHEREOF, DTE ELECTRIC COMPANY AND THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A. HAVE CAUSED THESE PRESENTS TO BE SIGNED IN THEIR RESPECTIVE CORPORATE NAMES BY THEIR RESPECTIVE CHAIRMEN OF THE BOARD, PRESIDENTS, VICE PRESIDENTS, ASSISTANT VICE PRESIDENTS, TREASURERS OR ASSISTANT TREASURERS AND IMPRESSED WITH THEIR RESPECTIVE CORPORATE SEALS, ATTESTED BY THEIR RESPECTIVE SECRETARIES OR ASSISTANT SECRETARIES, ALL AS OF THE DAY AND YEAR FIRST ABOVE WRITTEN.

27

EXECUTION BYDTE ELECTRIC COMPANY

COMPANY.

By:/s/Donald J. Goshorn

(Corporate Seal) Name:Donald J. Goshorn

Title:Assistant Treasurer

Attest:

By:/s/Lisa A. Muschong

Name:Lisa A. Muschong

Title: Corporate Secretary

Signed, sealed and delivered by

DTE ELECTRIC COMPANY

in the presence of:

/s/W. Scott Bennett

Name: W. Scott Bennett

/s/Dana Pierre-Louis

Name: Dana Pierre-Louis

28

STATE OF MICHIGAN)

) SS

COUNTY OF WAYNE)

ACKNOWLEDG-MENT OF EXECUTION BY COMPANY.

On this 20th day of August, 2013, before me, the subscriber, a Notary Public within and for the County of Wayne, in the State of Michigan, acting in the County of Wayne, personally appeared Donald J. Goshorn, to me personally known, who, being by me duly sworn, did say that he does business at One Energy Plaza, Detroit, Michigan 48226 and is the Assistant Treasurer of DTE ELECTRIC COMPANY, one of the corporations described in and which executed the foregoing instrument; that he knows the corporate seal of the said corporation and that the seal affixed to said instrument is the corporate seal of said corporation; and that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors and that he subscribed his name thereto by like authority; and said Donald J. Goshorn acknowledged said instrument to be the free act and deed of said corporation.

(Notarial Seal)

/s/Jennifer Evans Jennifer Evans Notary Public, Wayne County, MI Acting in Wayne My Commission Expires: December 28, 2016

29

EXECUTION BY THE BANK OF NEW YORK MELLON TRUST

TRUSTEE.COMPANY, N.A.

By:/s/Nicholas J. McArthur

(Corporate Seal)Name: Nicholas J. McArthur

Title: Authorized Officer

Attest:

By: /s/Kellee Przytulski

Name:Kellee Przytulski

Title:Authorized Officer

Signed, sealed and delivered by

THE BANK OF NEW YORK MELLON

TRUST COMPANY, N.A.

in the presence of

/s/Dana Pierre-Louis

Name: Dana Pierre-Louis

/s/Kathleen Hier

Name: Kathleen Hier

30

STATE OF MICHIGAN)

) SS

COUNTY OF WAYNE)

ACKNOWLEDG-MENT OF EXECUTION BY TRUSTEE.

On this 26th day of August, 2013, before me, the subscriber, a Notary Public within and for the County of Wayne, in the State of Michigan, acting in the County of Wayne, personally appeared Nicholas J. McArthur, to me personally known, who, being by me duly sworn, did say that his business office is located at 719 Griswold Street, Suite 930, Detroit, Michigan 48226, and he is an Authorized Officer of THE BANK OF NEW YORK MELLON TRUST COMPANY, N.A., one of the corporations described in and which executed the foregoing instrument; that he knows the corporate seal of the said corporation and that the seal affixed to said instrument is the corporate seal of said corporation; and that said instrument was signed and sealed in behalf of said corporation by authority of its Board of Directors and that he subscribed his name thereto by like authority; and said Nicholas J. McArthur acknowledged said instrument to be the free act and deed of said corporation.

(Notarial Seal)

/s/Jennifer Evans Jennifer Evans Notary Public, Wayne County, MI Acting in Wayne My Commission Expires: December 28, 2016

31

STATE OF MICHIGAN)

) SS

COUNTY OF WAYNE)

AFFIDAVIT AS TO CONSIDERATION AND GOOD FAITH. Donald J. Goshorn, being duly sworn, says: that he is the Vice President and Treasurer of DTE ELECTRIC COMPANY, the Mortgagor named in the foregoing instrument, and that he has knowledge of the facts in regard to the making of said instrument and of the consideration therefor; that the consideration for said instrument was and is actual and adequate, and that the same was given in good faith for the purposes in such instrument set forth.

/s/Donald J. Goshorn

Name:Donald J. Goshorn

Title: Assistant Treasurer

DTE Electric Company

Sworn to before me this 20th day of August, 2013

(Notarial Seal)/s/Jennifer Evans

Jennifer Evans

Notary Public, Wayne County, MI

Acting in Wayne

My Commission Expires: December 28, 2016

32

This instrument was drafted by:

Dana Pierre-Louis, Esq.

One Energy Plaza

688 WCB

Detroit, Michigan 48226

When recorded return to:

Jennifer Evans

One Energy Plaza

688 WCB

Detroit, Michigan 48226

33

EX-12.47

									Exhibit 12-47
DTE Electric Company
Computation of Ratio of Earnings to Fixed Charges
	Nine Months Ended		Twelve Months Ended December 31
(Millions of Dollars)	September 30, 2013		2012		2011		2010		2009		2008
Earnings:
Pretax earnings	$	587	$	761	$	702	$	707	$	604	$	517
Fixed Charges	212		286		310		328		348		324
Net earnings	$	799	$	1,047	$	1,012	$	1,035	$	952	$	841
Fixed charges:
Interest expense	$	200	$	269	$	287	$	310	$	325	$	293
Adjustments	12		17		23		18		23		31
Fixed Charges	$	212	$	286	$	310	$	328	$	348	$	324
Ratio of earnings to fixed charges	3.77		3.66		3.26		3.16		2.74		2.60

EX-31.85

Exhibit 31-85

FORM 10-Q CERTIFICATION

I, Gerard M. Anderson, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of DTE Electric Company;

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

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

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

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

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

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

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

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

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

/S/ GERARD M. ANDERSON	Date:	October 25, 2013
Gerard M. Anderson
Chairman of the Board and Chief Executive Officer of DTE Electric Company

EX-31.86

Exhibit 31-86

FORM 10-Q CERTIFICATION

I, David E. Meador, certify that:

1. I have reviewed this Quarterly Report on Form 10-Q of DTE Electric Company;

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

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

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

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

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

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

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

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

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

/S/ DAVID E. MEADOR	Date:	October 25, 2013
David E. Meador
Executive Vice President and Chief Financial Officer of DTE Electric Company

EX-32.85

Exhibit 32-85

CERTIFICATION PURSUANT TO

18 U. S. C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Electric Company (the “Company”) for the quarter ended September 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Gerard M. Anderson, certify, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	October 25, 2013	/S/ GERARD M. ANDERSON
		Gerard M. Anderson
		Chairman of the Board and Chief Executive Officer of DTE Electric Company

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

EX-32.86

Exhibit 32-86

CERTIFICATION PURSUANT TO

18 U. S. C. SECTION 1350

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report on Form 10-Q of DTE Electric Company (the “Company”) for the quarter ended September 30, 2013, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, David E. Meador, certify, pursuant to 18 U.S.C. Section 1350 as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge and belief:

(1) the Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:	October 25, 2013	/S/ DAVID E. MEADOR
		David E. Meador
		Executive Vice President and Chief Financial Officer of DTE Electric Company

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

XML

Commitments and Contingencies (Notes)

9 Months Ended

Sep. 30, 2013

Commitments and Contingencies Disclosure [Abstract]

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 $1.9 billion through 2012. The Company estimates DTE Electric will make capital expenditures of approximately $190 million in 2013 and up to approximately $1.8 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 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 not expected before 2014. Notwithstanding the appeal filed with the Supreme Court, the EPA and a number of states have started working on the framework of revised CSAPR regulations which we anticipate to be proposed in the next few years.

The Mercury and Air Toxics Standard (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized on December 16, 2011. The MATS rule requires reductions of mercury and other hazardous air pollutants beginning in April 2015, with a potential extension to April 2016. DTE Electric has requested and been granted compliance date extensions for some units to April 2016. DTE Electric has tested technologies to determine technological and economic feasibility as MATS compliance alternatives to Flue Gas Desulfurization (FGD) systems. Implementation of Dry Sorbent Injection (DSI) and Activated Carbon Injection (ACI) technologies will allow several units that would not have been economical for FGD installations to continue operation in compliance with MATS.

In July 2009, DTE Energy received a Notice of Violation/Finding of Violation (NOV/FOV) from the EPA alleging, among other things, that five DTE Electric power plants violated New Source Performance standards, Prevention of Significant Deterioration requirements, and operating permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations related to a project and outage at Unit 2 of the Monroe Power Plant. In March 2013, DTE Energy received a supplemental NOV from the EPA relating to the July 2009 NOV/FOV. The supplemental NOV alleged additional violations relating to the New Source Review provisions under the Clean Air Act, among other things.

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant, but not relating to the July 2009 NOV/FOV. Among other relief, the EPA requested the court to require DTE Electric to install and operate the best available control technology at Unit 2 of the Monroe Power Plant. Further, the EPA requested the court to issue a preliminary injunction to require DTE Electric to (i) begin the process of obtaining the necessary permits for the Monroe Unit 2 modification and (ii) offset the pollution from Monroe Unit 2 through emissions reductions from DTE Electric's fleet of coal-fired power plants until the new control equipment is operating. On August 23, 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. The EPA and Sierra Club motions are currently pending with the U. S. District Court Judge.

DTE Electric believes that the plants identified by the EPA, including Unit 2 of the Monroe Power Plant, have complied with all applicable federal environmental regulations. Depending upon the outcome of discussions with the EPA regarding the two NOVs/FOVs, DTE Electric could be required to install additional pollution control equipment at some or all of the power plants in question, implement early retirement of facilities where control equipment is not economical, engage in supplemental environmental programs, and/or pay fines. The Company cannot predict the financial impact or outcome of this matter, or the timing of its resolution.

On March 13, 2013, the Sierra Club filed suit against DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,4996-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. 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. In July 2012, the EPA announced that a notice of its final action on the rule will be issued in June 2013. On June 27, 2013, the EPA announced an agreement to extend the deadline for issuance of the final rule until November 4, 2013. On April 19, 2013, the EPA proposed revised steam electric effluent guidelines regulating wastewater streams from coal-fired power plants including multiple possible options for compliance. The rules are expected to be finalized by May 2014. DTE Electric has provided comments to the EPA. However, it is not possible at this time to quantify the impacts of these developing requirements.

Contaminated and Other Sites— Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke or oil. The facilities, which produced gas, have been designated as manufactured gas plant (MGP) sites. DTE Electric conducted remedial investigations at contaminated sites, including three former MGP sites. The investigations have revealed contamination related to the by-products of gas manufacturing at each site. In addition to the MGP sites, the Company is also in the process of cleaning up other contaminated sites, including the area surrounding an ash landfill, electrical distribution substations, electric generating power plants, and underground and aboveground storage tank locations. The findings of these investigations indicated that the estimated cost to remediate these sites is expected to be incurred over the next several years. At September 30, 2013 and at December 31, 2012, the Company had $9 million accrued for remediation. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company believes that the likelihood of a materially greater liability than the accrued amount is remote based on current knowledge of the conditions at each site.

DTE Electric owns and operates a permitted engineered ash storage facility at the Monroe Power Plant 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. It is not possible to quantify the impact of those expected rulemakings at this time.

Other

In March 2011, the EPA finalized a new set of regulations regarding the identification of non-hazardous secondary materials that are considered solid waste, industrial boiler and process heater maximum achievable control technologies (IBMACT) for major and area sources, and commercial/industrial solid waste incinerator new source performance standard and emission guidelines (CISWI). The effective dates of the major source IBMACT and CISWI regulations were stayed anda re-proposal was issued by the EPA in December 2011. Final IBMACT and CISWI were issued by the EPA in December 2012. The Company is developing compliance plans to upgrade or convert existing industrial boilers to natural gas and to perform required energy assessments in compliance with the applicable new standards. Capital costs for the boiler conversions and the expenses for the one-time energy assessments are not expected to be material.

In 2010, the EPA finalized a new 1-hour sulfur dioxide ambient air quality standard that requires states to submit plans for non-attainment areas to be in compliance by 2017. Michigan's non-attainment area includes DTE 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 any required emission reductions for DTE Electric sources to meet the standard cannot be estimated currently.

Nuclear Operations

Property Insurance

DTE Electric maintains property insurance policies specifically for the Fermi 2 plant. These policies cover such items as replacement power and property damage. The Nuclear Electric Insurance Limited (NEIL) is the primary supplier of the insurance policies.

DTE Electric maintains a policy for extra expenses, including replacement power costs necessitated by Fermi 2's unavailability due to an insured event. This policy has a 12-week waiting period and provides an aggregate $490 million of coverage over a three-year period.

DTE Electric has $500 million in primary coverage and $2.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property and decommissioning. The combined coverage limit for total property damage is $2.75 billion, subject to a $1 million deductible. As of April 1, 2013, the total limit for property damage for non-nuclear events is $1.8 billion and an aggregate of $327 million of coverage for extra expenses over a two-year period.

In 2007, the Terrorism Risk Insurance Extension Act of 2005 (TRIA) was extended through December 31, 2014. A major change in the extension is the inclusion of “domestic” acts of terrorism in the definition of covered or “certified” acts. For multiple terrorism losses caused by acts of terrorism not covered under the TRIA occurring within one year after the first loss from terrorism, the NEIL policies would make available to all insured entities up to $3.2 billion, plus any amounts recovered from reinsurance, government indemnity, or other sources to cover losses.

Under the NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $34 million per event if the loss associated with any one event at any 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 anticipates 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 all claims submitted have been accepted. The settlement proceeds reduced the cost of the dry cask storage facility assets. In February 2013, the U.S. Court of Appeals for the District of Columbia granted a motion to reopen the fee adequacy litigation to review the DOE's latest fee adequacy report which was released in January 2013. DTE Electric will continue to pay fees to the U.S. government's nuclear waste fund pending further action by the D.C. Circuit. 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.

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

Our contract with a bargaining unit for the majority of our represented employees was due to expire in June 2013. Early negotiations resulted in a new contract that became effective in March 2013. The new contract will expire in June 2017.

Purchase Commitments

As of September 30, 2013, the Company was party to numerous long-term purchase commitments relating to a variety of goods and services required for the Company’s business. These agreements primarily consist of fuel supply commitments, renewable energy contracts and energy trading contracts. The Company estimates that these commitments will be approximately $2.6 billion from 2013 through 2034.

The Company also estimates that 2013 capital expenditures will be approximately $1.5 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.

XML

Consolidated Statements of Comprehensive Income (Parentheticals) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Tax effect on benefit obligations	$ 0	$ 0

XML

Significant Accounting Policies (Note)

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

Significant Accounting Policies [Text Block]

SIGNIFICANT ACCOUNTING POLICIES

Comprehensive Income

Comprehensive income is the change in common shareholder’s 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 and nine months ended September 30, 2013 reflected changes in benefit obligations.

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Three Months Ended September 30, 2013
	Benefit Obligations (b)			Total
	(In millions)
Beginning balance, June 30, 2013	$	(21	)	$	(21	)
Other comprehensive income before reclassifications	—			—
Amounts reclassified from accumulated other comprehensive income	1			1
Net current-period other comprehensive income	1			1
Ending balance, September 30, 2013	$	(20	)	$	(20	)

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Nine Months Ended September 30, 2013
	Benefit Obligations (b)			Total
	(In millions)
Beginning balance, December 31, 2012	$	(22	)	$	(22	)
Other comprehensive income before reclassifications	—			—
Amounts reclassified from accumulated other comprehensive income	2			2
Net current-period other comprehensive income	2			2
Ending balance, September 30, 2013	$	(20	)	$	(20	)

_______________________________________

(a) All amounts are net of tax.

(b) The amounts reclassified from accumulated other comprehensive income are included in the computation of the net periodic pension cost (see Retirement Benefits and Trusteed Assets Note 10).

Intangible Assets

The Company has certain intangible assets relating to emission allowances and renewable energy credits as shown below:

	September 30,		December 31,
	2013		2012
	(In millions)
Emission allowances	$	3	$	6
Renewable energy credits	48		44
	51		50
Less current intangible assets	14		20
	$	37	$	30

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 from continuing operations for the three months ended September 30, 2013 was 35 percent as compared to 37 percent for the three months ended September 30, 2012. The Company's effective tax rate from continuing operations for the nine months ended September 30, 2013 was 35 percent as compared to 37 percent for the nine months ended September 30, 2012. The decrease in the effective tax rate in 2013 is due primarily to higher production tax credits. DTE Electric had an income tax payable of $34 million at September 30, 2013 and $13 million at December 31, 2012 due to DTE Energy.

The Company had $3 million of unrecognized tax benefits at September 30, 2013, 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 $10 million and $12 million for the three months ended September 30, 2013 and September 30, 2012, respectively, while such allocation was $43 million and $32 million for the nine months ended September 30, 2013 and September 30, 2012, respectively.

XML

Asset Retirement Obligations (Tables)

9 Months Ended

Sep. 30, 2013

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Change in Asset Retirement Obligation [Table Text Block]

A reconciliation of the asset retirement obligations for the nine months ended September 30, 2013 follows:

	(In millions)
Asset retirement obligations at December 31, 2012	$	1,557
Accretion	72
Revision in estimated cash flows	13
Liabilities settled	(2		)
Asset retirement obligations at September 30, 2013	$	1,640

XML

Retirement Benefits and Trusteed Assets (Notes)

9 Months Ended

Sep. 30, 2013

Pension and Other Postretirement Benefit Expense [Abstract]

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
	2013			2012			2013			2012
Three Months Ended September 30	(In millions)
Service cost	$	17		$	15		$	6		$	11
Interest cost	36			38			16			23
Expected return on plan assets	(45		)	(41		)	(18		)	(15		)
Amortization of:
Net actuarial loss	39			33			12			16
Prior service cost (credit)	1			—			(27		)	(4		)
Net periodic benefit cost (credit)	$	48		$	45		$	(11	)	$	31

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Nine Months Ended September 30	(In millions)
Service cost	$	55		$	48		$	27		$	38
Interest cost	109			116			50			69
Expected return on plan assets	(138		)	(124		)	(55		)	(46		)
Amortization of:
Net actuarial loss	111			93			36			44
Prior service cost (credit)	1			—			(72		)	(12		)
Net transition liability	—			—			—			1
Settlements	—			2			—			—
Net periodic benefit cost (credit)	$	138		$	135		$	(14	)	$	94

Pension and Other Postretirement Contributions

During the first nine months of 2013, the Company contributed $250 million to its pension plans, including contributions of DTE Energy common stock of $200 million. At the discretion of management, and depending upon financial market conditions, the Company may make up to an additional $25 million contribution to its pension plans in 2013.

In January 2013, the Company contributed $120 million to its other postretirement benefit plans. At the discretion of management, the Company may make up to an additional $120 million contribution to its other postretirement benefit plans in 2013.

Re-Measurement of Other Postretirement Benefit Obligation

In March 2013, the Company reached an agreement on a new four-year labor contract with certain represented employees. As a term of the agreement, the Company replaced sponsored retiree medical, prescription drug and dental coverage for future Medicare eligible retirees with a Retiree Health Care Allowance (RHCA) account of $3,250 per year. The modification in retiree health coverage will reduce future postretirement benefit costs.

Based on the impact of such benefit cost savings on the financial statements, the Company re-measured its retiree health plan as of March 31, 2013. In performing the re-measurement, the Company updated its significant actuarial assumptions, including an adjustment to the discount rate from 4.15% at December 31, 2012 to 4.30% at March 31, 2013. Plan assets were also updated to reflect fair value as of the re-measurement date. As a result of the re-measurement, the accumulated postretirement benefit obligation (APBO) was reduced by $192 million. The Company's Accrued postretirement benefit liability - affiliates at March 31, 2013 was $661 million as compared to $996 million at December 31, 2012, a reduction of $335 million. The reduction reflects the impact of the re-measurement of the plan, January 2013 plan contributions and recognition of first quarter 2013 postretirement benefit costs and benefit payments.

Beginning April 2013, net postretirement benefit costs were recorded based on the updated actuarial assumptions and benefit changes resulting from the new labor contracts. As a result of the re-measurement, fiscal year 2013 postretirement benefit costs are expected to decrease by approximately $51 million to an annual net benefit of approximately $23 million.

XML

Retirement Benefits and Trusteed Assets Retirement Benefits and Trusted Assets (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Pension Plans, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	$ 17	$ 15	$ 55	$ 48
Interest Cost	36	38	109	116
Expected Return on Plan Assets	(45)	(41)	(138)	(124)
Amortization of Net Acutuarial Losses	39	33	111	93
Amortization of Prior Service Cost (Credit)	1	0	1	0
Amortization of Net Transition Liability			0	0
Settlements			0	2
Net Periodic Benefit Cost	48	45	138	135
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service Cost	6	11	27	38
Interest Cost	16	23	50	69
Expected Return on Plan Assets	(18)	(15)	(55)	(46)
Amortization of Net Acutuarial Losses	12	16	36	44
Amortization of Prior Service Cost (Credit)	(27)	(4)	(72)	(12)
Amortization of Net Transition Liability			0	1
Settlements			0	0
Net Periodic Benefit Cost	$ (11)	$ 31	$ (14)	$ 94

XML

Fair Value (Details Textuals) (USD $)	9 Months Ended												9 Months Ended	12 Months Ended			9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member]	Sep. 30, 2013 Fair Value, Measurements, Recurring [Member] Fair Value, Inputs, Level 2 [Member]	Dec. 31, 2012 Fair Value, Measurements, Recurring [Member] Fair Value, Inputs, Level 2 [Member]	Sep. 30, 2013 Restricted Assets [Member] Fair Value, Measurements, Recurring [Member] Fair Value, Inputs, Level 2 [Member]	Dec. 31, 2012 Restricted Assets [Member] Fair Value, Measurements, Recurring [Member] Fair Value, Inputs, Level 2 [Member]	Sep. 30, 2013 Other Investments [Member] Fair Value, Measurements, Recurring [Member] Equity [Member]	Dec. 31, 2012 Other Investments [Member] Fair Value, Measurements, Recurring [Member] Equity [Member]	Sep. 30, 2013 Other Investments [Member] Fair Value, Measurements, Recurring [Member] Fair Value, Inputs, Level 2 [Member]	Dec. 31, 2012 Other Investments [Member] Fair Value, Measurements, Recurring [Member] Fair Value, Inputs, Level 2 [Member]	Sep. 30, 2013 Nuclear Decommissioning Trust Fund [Member]	Dec. 31, 2012 Nuclear Decommissioning Trust Fund [Member]	Sep. 30, 2013 Fermi 2 [Member]	Dec. 31, 2012 Fermi 2 [Member]	Sep. 30, 2013 Fermi 1 [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Cash equivalents			$ 61,000,000	$ 116,000,000	$ 61,000,000	$ 116,000,000	$ 44,000,000	$ 102,000,000			$ 17,000,000	$ 14,000,000	$ 12,000,000	$ 7,000,000
Available-for-sale Securities, Fair Value Disclosure									6,000,000	5,000,000
Transfers Between Levels 1, 2 and 3	0	0
Other than Temporary Impairment Losses, Investments, Portion Recognized in Earnings, Net		0
Average Maturity of Debt Securities													7 years	6 years
Unrealized losses recognized as regulatory assets															38,000,000	44,000,000
Fermi I Corresponding Regulatory Asset Treatment																	0
Other than Temporary Impairment Losses, Investments, Portion Recognized in Earnings, Net																	0
Unrealized Losses on Available for Sale Securities	0	0
Trading Securities, Change in Unrealized Holding Gain (Loss)	$ 12,000,000	$ 9,000,000

XML

Basis of Presentation (Details Textuals) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013 customers	Dec. 31, 2012
Organization, Consolidation and Presentation of Financial Statements [Line Items]
Number of Electric Customers	2,100,000
Significant Potential Exposure to Loss Due to VIE Long-Term Purchase Contracts	$ 0
Notes receivable	6	3
Variable Interest Entity, Not Primary Beneficiary [Member]
Organization, Consolidation and Presentation of Financial Statements [Line Items]
Notes receivable	$ 0	$ 3

XML

Retirement Benefits and Trusteed Assets Retirement Benefits and Trusted Assets (Tables)

9 Months Ended

Sep. 30, 2013

Defined Benefit Plan, Assets for Plan Benefits [Abstract]

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
	2013			2012			2013			2012
Three Months Ended September 30	(In millions)
Service cost	$	17		$	15		$	6		$	11
Interest cost	36			38			16			23
Expected return on plan assets	(45		)	(41		)	(18		)	(15		)
Amortization of:
Net actuarial loss	39			33			12			16
Prior service cost (credit)	1			—			(27		)	(4		)
Net periodic benefit cost (credit)	$	48		$	45		$	(11	)	$	31

	Pension Benefits						Other Postretirement Benefits
	2013			2012			2013			2012
Nine Months Ended September 30	(In millions)
Service cost	$	55		$	48		$	27		$	38
Interest cost	109			116			50			69
Expected return on plan assets	(138		)	(124		)	(55		)	(46		)
Amortization of:
Net actuarial loss	111			93			36			44
Prior service cost (credit)	1			—			(72		)	(12		)
Net transition liability	—			—			—			1
Settlements	—			2			—			—
Net periodic benefit cost (credit)	$	138		$	135		$	(14	)	$	94

XML

Short-Term Credit Arrangements and Borrowings (Details Textuals) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
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	0.53
Commercial Paper [Member]
Short-term Debt [Line Items]
Line of Credit Facility, Amount Outstanding	$ 11	$ 130
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

XML

Fair Value (Details 2) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Fair Value of Financial Instruments [Line Items]
Notes receivable, excluding capital leases Carrying Amount	$ 8	$ 5
Short-term borrowings - other Carrying Amount	11	130
Long-term debt Carrying Amount	5,245	4,963
Fair Value, Inputs, Level 1 [Member]
Fair Value of Financial Instruments [Line Items]
Notes receivable, excluding capital leases Fair Value	0	0
Short-term Debt, 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
Short-term Debt, Fair Value	11	130
Long-term debt Fair Value	5,163	5,021
Fair Value, Inputs, Level 3 [Member]
Fair Value of Financial Instruments [Line Items]
Notes receivable, excluding capital leases Fair Value	8	5
Short-term Debt, Fair Value	0	0
Long-term debt Fair Value	426	620
Affiliates [Member]
Fair Value of Financial Instruments [Line Items]
Short-term borrowings - affiliates Carrying Amount	55	80
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	$ 55	$ 80

XML

Financial and Other Derivative Instruments (Details 1) (FTR [Member])	Sep. 30, 2013 dte.volumes
FTR [Member]
Derivative [Line Items]
Investment Contract Volume	72,875

XML

Retirement Benefits and Trusteed Assets Retirement Benefits and Trusteed Assets (Details Textuals) (USD $)	9 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Retiree Health Care Allowance	$ 3,250
Remeasurement Reduction to Post Retirement Benefit Obligation	192,000,000	335,000,000
Remeasurement Reduction to Post Retirement Benefit Obligation Liability	661,000,000	996,000,000
Remeasurement Decrease in Benefit Cost for Postretirement Plans	51,000,000
Annual Decrease in Other Postretirement Benefits Costs due to Remeasurement	23,000,000
Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension Contributions	250,000,000
Estimated Future Employer Contributions in Current Fiscal Year	25,000,000
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Contributions by Employer	120,000,000
Estimated Future Employer Contributions in Current Fiscal Year	120,000,000
Assumptions Used Calculating Benefit Obligation, Discount Rate	4.30%	4.15%
Common Stock [Member] | Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension Contributions	$ 200,000,000

XML

Significant Accounting Policies Significant Accounting Policies (Details 1) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 51	$ 50
Intangible Assets, Current	14	20
Finite-Lived Intangible Assets, Net	37	30
Emission Allowances [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	3	6
Renewable Energy Credits [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Assets, Gross	$ 48	$ 44

XML

Regulatory Matters (Details Textuals) (USD $)		3 Months Ended	9 Months Ended			60 Months Ended	84 Months Ended
	Jul. 29, 2013	Mar. 31, 2013 MPSC [Member]	Sep. 30, 2013 MPSC [Member]	Oct. 17, 2013 MPSC [Member]	Jul. 30, 2012 MPSC [Member]	Jun. 28, 2018 Five Year (Minimum) [Member]	Jun. 28, 2020 Seven Year (Maximum) [Member]
Regulatory Asset and Liability [Line Items]
Transition PLD customers to DTE Electric distribution system						5 years	7 years
Rate increase previously authorized by the MPSC challeged by Court of Appeals affirmed by the MPSC				$ 8,000,000
Rate Base Amount related to Advanced Metering Infrasctructure Program reopened related to previously approved order			55,000,000
PSCR under-recovery from One Plan Year Prior		87,000,000
PSCR Under-Recovery from Two Plan Years Prior		148,000,000
Two Plan Years Prior PSCR Reconciliation included amount of Purchased Power Cost Related to Manual Shutdown of Fermi 2		30,000,000
Fermi 2 Production Level of Full Capacity					68.00%
Monthly Funding Factor for all Michigan Electric utilities participating in Low Income Energy Assistance Fund	$ 0.99

XML

Long-Term Debt (Tables)

9 Months Ended

Sep. 30, 2013

Long-term Debt, Unclassified [Abstract]

Schedule of Issued Debt [Table Text Block]

In 2013, the following debt was issued:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
March	Mortgage Bonds (a)	4.00%	2043	$	375
August	Mortgage Bonds (a)	3.65%	2024	400
				$	775

_______________________________________

(a) Proceeds were used for the redemption of DTE Electric long-term debt, for the repayment of short-term borrowings, and for general corporate purposes.

Schedule of Extinguishment of Debt [Table Text Block]

In 2013, the following debt was redeemed:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
March	Securitization Bonds	6.42%	2013	$	88
March	Tax Exempt Revenue Bonds (a)	5.30%	2030	51
April	Other Long-Term Debt	Various	2013	13
September	Securitization Bonds	6.62%	2015	89
September	Senior Notes	6.40%	2013	250
				$	491

_____________________________

(a) DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.

XML

Consolidated Statements of Financial Position (Unaudited) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Current Assets
Cash and cash equivalents	$ 43	$ 30
Restricted cash, principally Securitization	44	102
Accounts receivable (less allowance for doubtful accounts of $xx and $35, respectively)
Customer	766	697
Affiliates	1	5
Other	19	63
Inventories
Fuel	178	246
Materials and supplies	207	193
Notes receivable	2	2
Regulatory assets	42	162
Prepaid property taxes	89	43
Other	29	34
Total Current Assets	1,420	1,577
Investments
Nuclear decommissioning trust funds	1,139	1,037
Other	148	133
Total Investments	1,287	1,170
Property
Property, plant and equipment	18,479	17,689
Less accumulated depreciation and amortization	(6,971)	(6,717)
Property, plant and equipment, net	11,508	10,972
Other Assets
Regulatory assets	2,919	3,348
Securitized regulatory assets	280	413
Intangible assets	37	30
Notes receivable	6	3
Other	145	138
Total Noncurrent Assets	3,387	3,932
Total Assets	17,602	17,651
Accounts payable
Affiliates	89	65
Other	352	350
Accrued interest	69	61
Current portion long-term debt, including capital leases	501	443
Regulatory liabilities	192	66
Short-term borrowings
Affiliates	55	80
Other	11	130
Other	180	153
Total Current Liabilities	1,449	1,348
Long-Term Debt (net of current portion)
Mortgage bonds, notes and other	4,639	4,221
Securitization bonds	105	302
Capital lease obligations	1	1
Total Long-Term Debt (net of current portion)	4,745	4,524
Other Liabilities
Deferred income taxes	2,832	2,761
Regulatory liabilities	408	483
Asset retirement obligations	1,640	1,557
Unamortized investment tax credit	43	49
Nuclear decommissioning	172	159
Accrued pension liability — affiliates	1,138	1,368
Accrued postretirement liability — affiliates	638	996
Other	103	103
Total Noncurrent Liabilities	6,974	7,476
Shareholder’s Equity
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	3,196	3,196
Retained earnings	1,258	1,129
Accumulated other comprehensive loss	(20)	(22)
Total Shareholder's Equity	4,434	4,303
Total Liabilities and Shareholder's Equity	$ 17,602	$ 17,651

XML

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, 2012	$ 4,303	$ 1,386	$ 1,810	$ 1,129	$ (22)
Beginning Balance, shares at Dec. 31, 2012	138,632,324	138,632,000
Net Income	386			386
Dividends declared on common stock	(257)			(257)
Other Comprehensive (Income) Loss, Pension and Other Postretirement Benefit Plans, Adjustment, Net of Tax	2					2
Ending Balance at Sep. 30, 2013	$ 4,434	$ 1,386	$ 1,810	$ 1,258	$ (20)
Ending Balance, shares at Sep. 30, 2013	138,632,324	138,632,000

XML

Fair Value (Notes)

9 Months Ended

Sep. 30, 2013

Fair Value Disclosures [Abstract]

Fair Value

FAIR VALUE

Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated or generally unobservable inputs. The Company makes certain assumptions it believes that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Company and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at September 30, 2013 and December 31, 2012. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Company classifies fair value balances based on the fair value hierarchy defined as follows:

• Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date.

• Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

• Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.

The following table presents assets measured and recorded at fair value on a recurring basis as of September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)
Assets:
Cash equivalents (a)	$	—	$	61	$	—	$	61	$	—	$	116	$	—	$	116
Nuclear decommissioning trusts	757		382		—		1,139		694		343		—		1,037
Other investments (b)	74		48		—		122		64		44		—		108
Derivative assets — FTRs	—		—		5		5		—		—		1		1
Total	$	831	$	491	$	5	$	1,327	$	758	$	503	$	1	$	1,262
Assets:
Current	$	—	$	61	$	5	$	66	$	—	$	116	$	1	$	117
Noncurrent	831		430		—		1,261		758		387		—		1,145
Total Assets	$	831	$	491	$	5	$	1,327	$	758	$	503	$	1	$	1,262

_______________________________________

(a) At September 30, 2013, available-for-sale securities of $61 million, included $44 million and $17 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2012, available-for-sale securities of $116 million, included $102 million and $14 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 September 30, 2013 and December 31, 2012 of $6 million and $5 million, respectively, 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. The fair values of the shares in these investments are based upon observable market prices for similar securities and, therefore, have been categorized as Level 2 in the fair value hierarchy.

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds which hold exchange-traded equity or debt securities are valued based on the underlying securities, using quoted prices in actively traded markets. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered to be preferable. 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 and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013		2012			2013			2012
	(In millions)
Net Assets as of beginning of the period	$	2	$	2		$	1		$	1
Change in fair value recorded in regulatory assets/liabilities	3		7			7			12
Purchases, issuances and settlements:
Settlements	—		(7		)	(3		)	(11		)
Net Assets as of September 30	$	5	$	2		$	5		$	2
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 September 30, 2013 and September 30, 2012	$	3	$	1		$	5		$	2

No transfers between Levels 1, 2 or 3 occurred in the three and nine months ended September 30, 2013 and September 30, 2012.

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 September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	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	$	8	$	—	$	—	$	8	$	5	$	—	$	—	$	5
Short-term borrowings — affiliates	55		—		—		55		80		—		—		80
Short-term borrowings — other	11		—		11		—		130		—		130		—
Long-term debt	5,245		—		5,163		426		4,963		—		5,021		620

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:

	September 30,		December 31,
	2013		2012
	(In millions)
Fermi 2	$	1,120	$	1,021
Fermi 1	3		3
Low-level radioactive waste	16		13
Total	$	1,139	$	1,037

The costs of securities sold are determined on the basis of specific identification. The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
	(In millions)
Realized gains	$	11		$	7		$	30		$	21
Realized losses	(11		)	(6		)	(25		)	(17		)
Proceeds from sales of securities	13			12			40			48

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:

	September 30, 2013				December 31, 2012
	Fair		Unrealized		Fair		Unrealized
	Value		Gains		Value		Gains
	(In millions)
Equity securities	$	732	$	195	$	631	$	122
Debt securities	395		17		399		27
Cash and cash equivalents	12		—		7		—
	$	1,139	$	212	$	1,037	$	149

The debt securities at both September 30, 2013 and December 31, 2012 had an average maturity of approximately 7 and 6 years, respectively. Securities held in the nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.

Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset. DTE Electric recognized $38 million and $44 million of unrealized losses as Regulatory assets at September 30, 2013 and December 31, 2012, respectively. Since the decommissioning of Fermi 1 is funded by DTE Electric rather than through a regulatory recovery mechanism, there is no corresponding regulatory asset treatment. Therefore, unrealized losses incurred by the Fermi 1 trust are recognized in earnings immediately. There were no unrealized losses recognized in the three and nine months ended September 30, 2013 and September 30, 2012 for Fermi 1.

Other Securities

At September 30, 2013 and December 31, 2012, the securities were comprised primarily of money market and equity securities. During the quarter ended September 30, 2013 and the year ended December 31, 2012 no amounts of unrealized losses on available-for-sale securities were reclassified out of other comprehensive income and realized into net income for the periods. Gains related to trading securities held at September 30, 2013 and September 30, 2012 were $12 million and $9 million, respectively.

XML

Basis of Presentation (Notes)

9 Months Ended

Sep. 30, 2013

Organization, Consolidation and Presentation of Financial Statements [Abstract]

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 2012 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, 2013.

Certain prior year balances were reclassified to match the current year's financial statement presentation.

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 September 30, 2013, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any form of financial support associated with these long-term contracts. There is no significant potential exposure to loss as a result of its variable interests through these long-term purchase contracts.

In 2001, DTE Electric financed a regulatory asset related to Fermi 2 and certain other regulatory assets through the sale of rate reduction bonds by a wholly-owned special purpose entity, Securitization. DTE Electric performs servicing activities including billing and collecting surcharge revenue for Securitization. This entity is a VIE and is consolidated by the Company. The maximum risk exposure 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 September 30, 2013 and December 31, 2012 restricted for Securitization that are either (1) assets that can be used only to settle obligations related to the Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.

	September 30,		December 31,
	2013		2012
	(In millions)
ASSETS
Restricted cash	$	44	$	102
Accounts receivable	39		34
Securitized regulatory assets	280		413
Other assets	5		7
	$	368	$	556
LIABILITIES
Accounts payable and accrued current liabilities	$	2	$	11
Current portion long-term debt, including capital leases	196		177
Current regulatory liabilities	48		50
Securitization bonds	105		302
Other long-term liabilities	8		7
	$	359	$	547

As of September 30, 2013 DTE Electric had no balance in Notes receivable, related to non-consolidated VIEs and at December 31, 2012 the Company had $3 million in Notes receivable, related to non-consolidated VIEs.

XML

Financial and Other Derivative Instruments (Details Textuals) (FTR [Member], USD $) In Millions, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013
FTR [Member]
Derivative [Line Items]
Effect of Derivative Instruments Recoverable Through PSCR Mechanism	$ 3	$ 7

XML

Basis of Presentation (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Assets [Abstract]
Restricted cash	$ 44	$ 102
Accounts receivable	766	697
Securitized regulatory assets	280	413
Other assets	145	138
Total Assets	17,602	17,651
Liabilities [Abstract]
Current portion long-term debt, including, capital leases	501	443
Current regulatory liabilities	192	66
Securitization bonds	105	302
Other long term liabilities	103	103
Variable Interest Entity Securitization [Member]
Assets [Abstract]
Restricted cash	44	102
Accounts receivable	39	34
Securitized regulatory assets	280	413
Other assets	5	7
Total Assets	368	556
Liabilities [Abstract]
Accounts payable and accrued current liabilities	2	11
Current portion long-term debt, including, capital leases	196	177
Current regulatory liabilities	48	50
Securitization bonds	105	302
Other long term liabilities	8	7
Total Liabilities	$ 359	$ 547

XML

Fair Value (Details) (Fair Value, Measurements, Recurring [Member], USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	$ 61	$ 116
Nuclear decommissioning trusts	1,139	1,037
Other investments	122	108
Assets	1,327	1,262
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	0	0
Nuclear decommissioning trusts	757	694
Other investments	74	64
Assets	831	758
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Cash equivalents	61	116
Nuclear decommissioning trusts	382	343
Other investments	48	44
Assets	491	503
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
Assets	5	1
FTR [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets - FTRs	5	1
FTR [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets - FTRs	0	0
FTR [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets - FTRs	0	0
FTR [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative assets - FTRs	5	1
Current Asset [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	66	117
Current Asset [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Current Asset [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	61	116
Current Asset [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	5	1
Noncurrent Asset [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	1,261	1,145
Noncurrent Asset [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	831	758
Noncurrent Asset [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	430	387
Noncurrent Asset [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 0	$ 0

XML

Fair Value (Details 5) (Nuclear Decommissioning Trust Fund [Member], USD $) In Millions, unless otherwise specified	9 Months Ended	12 Months Ended
	Sep. 30, 2013	Dec. 31, 2012
Fair Value, Option, Quantitative Disclosures [Line Items]
Cash equivalents	$ 12	$ 7
Nuclear decommissioning trusts	1,139	1,037
Unrealized Gains	212	149
Equity securities [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Equity Securities	732	631
Unrealized Gains	195	122
Debt securities [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Debt securities	395	399
Unrealized Gains	17	27
Cash and cash equivalents [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Unrealized Gains	$ 0	$ 0

XML

Long-Term Debt (Details 2) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013
Extinguishment of Debt [Line Items]
Extinguishment of Debt, Amount	$ 491
Securitization Bonds [Member]
Extinguishment of Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	6.42%
Extinguishment of Debt, Amount	88
Tax Exempt Revenue Bonds [Member]
Extinguishment of Debt [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	5.30%
Extinguishment of Debt, Amount	51
Long Term Debt, Other [Member]
Extinguishment of Debt [Line Items]
Extinguishment of Debt, Amount	$ 13

XML

Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Net Income	$ 180	$ 195	$ 386	$ 419
Other comprehensive income (loss), net of tax:
Benefit Obligations Net Of Tax	(1)	0	2	(2)
Comprehensive income	$ 181	$ 195	$ 388	$ 421

XML

Regulatory Matters (Notes)

9 Months Ended

Sep. 30, 2013

Public Utilities, General Disclosures [Abstract]

Regulatory Matters

REGULATORY MATTERS

Transition of the City of Detroit's Public Lighting Department's (PLD) Customers to DTE Electric's Distribution System

Accounting Authority

On June 28, 2013, DTE Electric filed an application for accounting authority to defer certain costs associated with the transition of the City of Detroit's PLD customers to the DTE Electric distribution system over a five to seven year system conversion period. The Company requested authority to defer as a regulatory asset, all net incremental revenue requirement associated with the transition. The net incremental revenue requirement includes costs to install meters and attach customers; system and customer facility upgrades and repairs; and the difference between DTE Electric's tariff rates and any transitional rates approved in the future. On July 11, 2013, the MPSC approved DTE Electric's request to defer, for accounting purposes, the net incremental revenue requirement.

The approval excludes the request to defer the difference between DTE Electric's tariff rates and any transitional rates that might be approved by the MPSC in the future. The MPSC will address proposed rates and recovery matters in a future contested proceeding. As the accounting order did not provide a regulatory recovery mechanism, a regulatory asset will not be recognized until a regulatory recovery mechanism is put into place and the recovery of the regulatory asset becomes probable.

Transitional Reconciliation Mechanism (TRM)

On July 19, 2013, DTE Electric filed its TRM application proposing a transitional tariff option for certain former PLD customers and a modified line extension provision. The application also proposes a recovery mechanism for the deferred incremental revenue requirement described above. The application further discusses that DTE Electric will be requesting recovery, in subsequent PSCR cases, of PLD transmission delivery service costs incurred while DTE Electric is temporarily relying upon PLD to operate and maintain PLD's system during the conversion period. If the MPSC determines that the transmission costs are not recoverable in the PSCR, the Company requested recovery as part of the TRM.

2009 Electric Rate Case Filing - Court of Appeals Remand to MPSC

In April 2012, the Michigan Court of Appeals (COA) issued a decision relating to an appeal of the January 2010 MPSC rate order in DTE Electric's January 2009 rate case filing. The COA found that the record of evidence in the January 2010 rate order was insufficient to support the MPSC's authorization to recover costs for the advanced metering infrastructure (AMI) program and remanded this matter to the MPSC. On October 17, 2013, the MPSC issued an order affirming the approximately $8 million rate increase authorized in the MPSC's January 2010 rate order for the AMI program and further concluded that the evidence presented after remand supports the authorized cost recovery.

2010 Electric Rate Case Filing - Court of Appeals Decision

In July 2013, the COA issued a decision relating to an appeal of the October 2011 MPSC order in DTE Electric's October 2010 rate case filing. The COA found that the record of evidence in the 2010 rate case order was insufficient to support the MPSC's authorization to recover costs for the AMI program and remanded this matter to the MPSC. The MPSC had approved $55 million of the average rate base related to the AMI program in the October 2011 order. DTE Electric is currently operating its AMI program pursuant to the MPSC's approval set forth in its October 20, 2011 order. On August 29, 2013, the MPSC reopened the 2010 electric rate case for the limited purpose of addressing the COA's opinion on AMI. The Company is unable to predict the outcome of this matter or the timing of its resolution.

Power Supply Cost Recovery Proceedings

The PSCR process is designed to allow DTE Electric to recover all of its power supply costs if incurred under reasonable and prudent policies and practices. DTE Electric's power supply costs include fuel and related transportation costs, purchased and net interchange power costs, nitrogen oxide and sulfur dioxide emission allowances costs, urea costs, transmission costs and MISO costs. The MPSC reviews these costs, policies and practices for prudence in annual plan and reconciliation filings.

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 approximately $30 million of 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. We were 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 some or all of the Fermi-related purchased power costs. Resolution of this matter is expected in 2014.

Low Income Energy Assistance Fund (LIEAF)

On July 1, 2013, Michigan Public Act 95 was signed into law and created the LIEAF. The legislation allows the use of a LIEAF funding factor to be determined by the MPSC and assessed on all customer classes of Michigan electric utilities to fund the LIEAF. On July 29, 2013, the MPSC adopted a funding factor of $0.99 per meter per month for all Michigan electric utilities that are participating in the program, including DTE Electric, effective with the September 2013 billing month. The surcharge billed by DTE Electric is remitted to the State of Michigan for subsequent distribution through a grant process to social service agencies and utilities to assist low income customers.

XML

Consolidated Statements of Cash Flows (Unaudited) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012
Operating Activities
Net Income	$ 386	$ 419
Adjustments to reconcile net income to net cash from operating activities:
Depreciation, depletion and amortization	666	607
Nuclear fuel amortization	25	25
Allowance for equity funds used during construction	(10)	(9)
Deferred income taxes	104	(48)
Asset (gains), losses and reserves, net	(3)	(1)
Changes in assets and liabilities:
Accounts receivable, net	(40)	(13)
Inventories	53	4
Accounts payable	15	(55)
Regulatory assets and liabilities	302	280
Accrued pension liability — affiliates	(229)	(43)
Accrued postretirement liability — affiliates	(148)	(91)
Other assets	(42)	(24)
Other liabilities	(15)	171
Net cash from operating activities	1,064	1,222
Investing Activities
Plant and equipment expenditures	(946)	(855)
Restricted cash for debt redemption, principally Securitization	58	57
Notes receivable from affiliate	(4)	(252)
Proceeds from sale of nuclear decommissioning trust fund assets	40	48
Investments in nuclear decommissioning trust funds	(52)	(61)
Other Investments	21	13
Net cash used for investing activities	(925)	(1,076)
Financing Activities
Issuance of long-term debt	768	496
Redemption of long-term debt	(491)	(401)
Short-term borrowings - other	(119)	0
Proceeds from (Repayments of) Short-term Debt, Affiliate	(25)	1
Dividends on common stock	(257)	(229)
Other	(2)	(3)
Net cash used for financing activities	(126)	(136)
Net Increase (Decrease) in Cash and Cash Equivalents	13	10
Cash and Cash Equivalents at Beginning of Period	30	13
Cash and Cash Equivalents at End of Period	$ 43	$ 23

XML

Consolidated Statements of Operations (Unaudited) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Operating Revenues	$ 1,457	$ 1,542	$ 3,941	$ 4,029
Operating Expenses
Fuel, purchased power and gas	487	543	1,294	1,348
Operation and maintenance	335	337	1,009	1,026
Depreciation, depletion and amortization	233	219	666	607
Taxes other than income	67	65	200	193
Asset (gains) losses and reserves, net	(3)	0	(3)	(1)
Total operating expenses	1,119	1,164	3,166	3,173
Operating Income	338	378	775	856
Other (Income) and Deductions
Interest expense	68	70	202	204
Other income	(14)	(14)	(38)	(41)
Other expenses	7	12	19	27
Total Other (Income) and Deductions	61	68	183	190
Income Before Income Taxes	277	310	592	666
Income Tax Expense	97	115	206	247
Net Income	$ 180	$ 195	$ 386	$ 419

XML

Significant Accounting Policies (Details Textuals) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Dec. 31, 2012
Significant Accounting Policies [Line Items]
Effective Income Tax Rate Reconciliation, Percent	35.00%	37.00%	35.00%	37.00%
Unrecognized Tax Benefits	$ 3		$ 3
Time Period of Decrease in Unrecognized Tax Benefits			12 months
DTE Energy [Member]
Significant Accounting Policies [Line Items]
Income Taxes Payable due to DTE Energy	34		34		13
Allocated Share-based Compensation Expense from DTE Energy	$ 10	$ 12	$ 43	$ 32

XML

Financial and Other Derivative Instruments (Tables)

9 Months Ended

Sep. 30, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Fair value of derivative instruments

The following table presents the fair value of derivative instruments as of September 30, 2013 and December 31, 2012:

	September 30,		December 31,
	2013		2012
	(In millions)
FTRs — Other current assets	$	5	$	1
Total derivatives not designated as hedging instrument	$	5	$	1

Volume of Commodity Contracts [Table Text Block]

The following represents the cumulative gross volume of derivative contracts outstanding as of September 30, 2013:

Commodity	Number of Units
FTRs (MWh)	72,875

XML

Long-Term Debt (Details 1) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Mar. 31, 2013
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 775
Mortgages [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	3.65%	4.00%
Debt Instrument, Face Amount	$ 400	$ 375

XML

Financial and Other Derivative Instruments (Details) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Derivatives not designated as hedging instruments:
Derivative Asset Fair Value Gross Asset	$ 5	$ 1

XML

Fair Value (Details 3) (USD $) In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	$ 1,139	$ 1,037
Fermi 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	1,120	1,021
Fermi 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	3	3
Low level radioactive waste [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Decommissioning Fund Investments	$ 16	$ 13

XML

Fair Value (Details 4) (Nuclear Decommissioning Trust Fund [Member], USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012
Nuclear Decommissioning Trust Fund [Member]
Fair Value, Option, Quantitative Disclosures [Line Items]
Realized gains	$ 11	$ 7	$ 30	$ 21
Realized losses	(11)	(6)	(25)	(17)
Proceeds from sales of securities	$ 13	$ 12	$ 40	$ 48

XML

Asset Retirement Obligations (Notes)

9 Months Ended

Sep. 30, 2013

Asset Retirement Obligation [Abstract]

Asset Retirement Obligations

ASSET RETIREMENT OBLIGATIONS

A reconciliation of the asset retirement obligations for the nine months ended September 30, 2013 follows:

	(In millions)
Asset retirement obligations at December 31, 2012	$	1,557
Accretion	72
Revision in estimated cash flows	13
Liabilities settled	(2		)
Asset retirement obligations at September 30, 2013	$	1,640

XML

Significant Accounting Policies Signficant Accounting Policies (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended	9 Months Ended
	Sep. 30, 2013	Sep. 30, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (21)	$ (22)
Other Comprehensive Income Before Reclassifications	0	0
Amounts Reclassified From Accumulated Other Comprehensive Income	1	2
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	1	2
Accumulated Other Comprehensive Income (Loss), Net of Tax	(20)	(20)
Accumulated Defined Benefit Plans Adjustment [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss), Net of Tax	(21)	(22)
Other Comprehensive Income Before Reclassifications	0	0
Amounts Reclassified From Accumulated Other Comprehensive Income	1	2
Other Comprehensive Income (Loss), Pension and Other Postretirement Benefit Plans, Net Unamortized Gain (Loss) Arising During Period, Net of Tax	1	2
Accumulated Other Comprehensive Income (Loss), Net of Tax	$ (20)	$ (20)

XML

Asset Retirement Obligations (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2013
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations beginning of period	$ 1,557
Accretion	72
Revision in estimated cash flows	13
Liabilities Settled	(2)
Asset retirement obligations end of period	$ 1,640

XML

Short-Term Credit Arrangements and Borrowings (Notes)

9 Months Ended

Sep. 30, 2013

Short-term Debt [Abstract]

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. At September 30, 2013, there was $11 million outstanding against the facility, while there was $130 million outstanding against the facility at December 31, 2012.

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 consolidatedsubsidiaries, 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 September 30, 2013, the total funded debt to total capitalization ratio for DTE Electric was 0.53 to 1 and is in compliance with this financial covenant.

XML

Financial and Other Derivative Instruments (Notes)

9 Months Ended

Sep. 30, 2013

Derivative Instruments and Hedges, Assets [Abstract]

Financial and Other Derivative Instruments

FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS

The Company recognizes all derivatives at their fair value as Derivative Assets or Liabilities on the Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge), or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income and later reclassified into earnings when the underlying transaction occurs. Gains 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 September 30, 2013 and December 31, 2012:

	September 30,		December 31,
	2013		2012
	(In millions)
FTRs — Other current assets	$	5	$	1
Total derivatives not designated as hedging instrument	$	5	$	1

The effects of derivative instruments recoverable through the PSCR mechanism when realized on the Consolidated Statements of Financial Position were $3 million and $7 million in gains related to FTRs recognized in Regulatory liabilities for the three and nine months ended September 30, 2013, respectively.

The following represents the cumulative gross volume of derivative contracts outstanding as of September 30, 2013:

Commodity	Number of Units
FTRs (MWh)	72,875

XML

Consolidated Statements of Financial Position (Parentheticals) (USD $) In Millions, except Share data, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2012
Assets, Current [Abstract]
Allowance for Doubtful Accounts Receivable	$ 35	$ 35
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

XML

Commitments and Contingencies (Details Textuals) (USD $)	9 Months Ended	12 Months Ended
	Sep. 30, 2013 facilities dte_instances	Dec. 31, 2012	Jul. 18, 2013
Loss Contingencies [Line Items]
Environmental Capital Expenditures Through Current Year		$ 1,900,000,000
Environmental Capital Expenditures in Current Year	190,000,000
Environmental Capital Expenditures In Future Years	1,800,000,000
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	1,499
Period of excess opacity of air emissions at alleged facilities	6 minutes
Number of Former MGP Sites	3
Site Contingency, Accrual, Undiscounted Amount	9,000,000	9,000,000
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	500,000,000
Coverage for Stabilization Decontamination Debris Removal Repair and Replacement of Property and Decommissioning	2,250,000,000
Combined Coverage Limit for Total Property Damage	2,750,000,000
Insurance Deductible for Nuclear Power Plant	1,000,000
Total Limit for Property Damage for Non-Nuclear Event	1,800,000,000
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	34,000,000
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
Long-term Purchase Commitment, Amount	2,600,000,000
Estimated future capital expenditures for remainder of the year	1,500,000,000
Bankruptcy Claims, Amount of Claims under Review by Management			$ 20,000,000

XML

Fair Value (Details 1) (USD $) In Millions, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2013	Sep. 30, 2012	Sep. 30, 2013	Sep. 30, 2012	Mar. 31, 2013	Mar. 31, 2012
Fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis
Beginning Balance			$ 1	$ 1	$ 2	$ 2
Recorded in regulatory assets/liabilities	3	7	7	12
Purchases issuances and settlements [Abstract]
Settlements	0	(7)	(3)	(11)
Ending Balance	5	2	5	2	2	2
Fair Value, Measurement with Unobservable Inputs Reconciliation, Recurring Basis, Asset, Period Increase (Decrease)	$ 3	$ 1	$ 5	$ 2

XML

Significant Accounting Policies Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2013

Sep. 30, 2012

Accounting Policies [Abstract]

Comprehensive Income, Policy [Policy Text Block]

Comprehensive Income

Comprehensive income is the change in common shareholder’s 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 and nine months ended September 30, 2013 reflected changes in benefit obligations.

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.

Income Tax, Policy [Policy Text Block]

Income Taxes

The Company's effective tax rate from continuing operations for the three months ended September 30, 2013 was 35 percent as compared to 37 percent for the three months ended September 30, 2012. The Company's effective tax rate from continuing operations for the nine months ended September 30, 2013 was 35 percent as compared to 37 percent for the nine months ended September 30, 2012. The decrease in the effective tax rate in 2013 is due primarily to higher production tax credits. DTE Electric had an income tax payable of $34 million at September 30, 2013 and $13 million at December 31, 2012 due to DTE Energy.

The Company had $3 million of unrecognized tax benefits at September 30, 2013, 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.

Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]

Stock-Based Compensation

The Company received an allocation of costs from DTE Energy associated with stock-based compensation

XML

Long-Term Debt (Notes)

9 Months Ended

Sep. 30, 2013

Long-term Debt, Unclassified [Abstract]

Long-term Debt [Text Block]

LONG-TERM DEBT

Debt Issuances

In 2013, the following debt was issued:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
March	Mortgage Bonds (a)	4.00%	2043	$	375
August	Mortgage Bonds (a)	3.65%	2024	400
				$	775

_______________________________________

(a) Proceeds were used for the redemption of DTE Electric long-term debt, for the repayment of short-term borrowings, and for general corporate purposes.

Debt Redemptions

In 2013, the following debt was redeemed:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
March	Securitization Bonds	6.42%	2013	$	88
March	Tax Exempt Revenue Bonds (a)	5.30%	2030	51
April	Other Long-Term Debt	Various	2013	13
September	Securitization Bonds	6.62%	2015	89
September	Senior Notes	6.40%	2013	250
				$	491

_____________________________

(a) DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.

XML

Fair Value (Tables)

9 Months Ended

Sep. 30, 2013

Fair Value Disclosures [Abstract]

Assets and liabilities measured and recorded at fair value on a recurring basis [Table Text Block]

The following table presents assets measured and recorded at fair value on a recurring basis as of September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)
Assets:
Cash equivalents (a)	$	—	$	61	$	—	$	61	$	—	$	116	$	—	$	116
Nuclear decommissioning trusts	757		382		—		1,139		694		343		—		1,037
Other investments (b)	74		48		—		122		64		44		—		108
Derivative assets — FTRs	—		—		5		5		—		—		1		1
Total	$	831	$	491	$	5	$	1,327	$	758	$	503	$	1	$	1,262
Assets:
Current	$	—	$	61	$	5	$	66	$	—	$	116	$	1	$	117
Noncurrent	831		430		—		1,261		758		387		—		1,145
Total Assets	$	831	$	491	$	5	$	1,327	$	758	$	503	$	1	$	1,262

_______________________________________

(a) At September 30, 2013, available-for-sale securities of $61 million, included $44 million and $17 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2012, available-for-sale securities of $116 million, included $102 million and $14 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 September 30, 2013 and December 31, 2012 of $6 million and $5 million, respectively, 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 and nine months ended September 30, 2013 and 2012:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2013		2012			2013			2012
	(In millions)
Net Assets as of beginning of the period	$	2	$	2		$	1		$	1
Change in fair value recorded in regulatory assets/liabilities	3		7			7			12
Purchases, issuances and settlements:
Settlements	—		(7		)	(3		)	(11		)
Net Assets as of September 30	$	5	$	2		$	5		$	2
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 September 30, 2013 and September 30, 2012	$	3	$	1		$	5		$	2

Fair Value of Financial Instruments [Table Text Block]

The following table presents the carrying amount and fair value of financial instruments as of September 30, 2013 and December 31, 2012:

	September 30, 2013								December 31, 2012
	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	$	8	$	—	$	—	$	8	$	5	$	—	$	—	$	5
Short-term borrowings — affiliates	55		—		—		55		80		—		—		80
Short-term borrowings — other	11		—		11		—		130		—		130		—
Long-term debt	5,245		—		5,163		426		4,963		—		5,021		620

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:

	September 30,		December 31,
	2013		2012
	(In millions)
Fermi 2	$	1,120	$	1,021
Fermi 1	3		3
Low-level radioactive waste	16		13
Total	$	1,139	$	1,037

Schedule of Realized Gain (Loss) [Table Text Block]

The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2013			2012			2013			2012
	(In millions)
Realized gains	$	11		$	7		$	30		$	21
Realized losses	(11		)	(6		)	(25		)	(17		)
Proceeds from sales of securities	13			12			40			48

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:

	September 30, 2013				December 31, 2012
	Fair		Unrealized		Fair		Unrealized
	Value		Gains		Value		Gains
	(In millions)
Equity securities	$	732	$	195	$	631	$	122
Debt securities	395		17		399		27
Cash and cash equivalents	12		—		7		—
	$	1,139	$	212	$	1,037	$	149

XML

Basis of Presentation (Tables)

9 Months Ended

Sep. 30, 2013

Variable Interest Entity, Consolidated, Carrying Amount, Assets and Liabilities, Net [Abstract]

Schedule of Variable Interest Entities [Table Text Block]

	September 30,		December 31,
	2013		2012
	(In millions)
ASSETS
Restricted cash	$	44	$	102
Accounts receivable	39		34
Securitized regulatory assets	280		413
Other assets	5		7
	$	368	$	556
LIABILITIES
Accounts payable and accrued current liabilities	$	2	$	11
Current portion long-term debt, including capital leases	196		177
Current regulatory liabilities	48		50
Securitization bonds	105		302
Other long-term liabilities	8		7
	$	359	$	547

XML

Document Entity Information Document	9 Months Ended
	Sep. 30, 2013
Entity Registrant Name	DTE ELECTRIC CO
Entity Central Index Key	0000028385
Current Fiscal Year End Date	--09-30
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2013
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding	138,632,324

XML

Significant Accounting Policies Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2013

Accounting Policies [Abstract]

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:

	September 30,		December 31,
	2013		2012
	(In millions)
Emission allowances	$	3	$	6
Renewable energy credits	48		44
	51		50
Less current intangible assets	14		20
	$	37	$	30

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 and nine months ended September 30, 2013 reflected changes in benefit obligations.

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Three Months Ended September 30, 2013
	Benefit Obligations (b)			Total
	(In millions)
Beginning balance, June 30, 2013	$	(21	)	$	(21	)
Other comprehensive income before reclassifications	—			—
Amounts reclassified from accumulated other comprehensive income	1			1
Net current-period other comprehensive income	1			1
Ending balance, September 30, 2013	$	(20	)	$	(20	)

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Nine Months Ended September 30, 2013
	Benefit Obligations (b)			Total
	(In millions)
Beginning balance, December 31, 2012	$	(22	)	$	(22	)
Other comprehensive income before reclassifications	—			—
Amounts reclassified from accumulated other comprehensive income	2			2
Net current-period other comprehensive income	2			2
Ending balance, September 30, 2013	$	(20	)	$	(20	)

_______________________________________

(a) All amounts are net of tax.

(b) The amounts reclassified from accumulated other comprehensive income are included in the computation of the net periodic pension cost (see Retirement Benefits and Trusteed Assets Note 10).