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 ~~June~~September 30, 2014

Commission file number 1-2198

The DTE Electric Company meets the conditions set forth in General Instruction H (1) (a) and (b) of Form 10-Q and is, therefore, filing this Form with 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.

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 ~~June~~September 30, 2014

TABLE OF CONTENTS

	Page
Definitions	1
Forward-Looking Statements	2
Part I - FINANCIAL INFORMATION
Items 1. Financial Statements	3
Item 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)	5
Consolidated Statements of Financial Position (Unaudited)	6
Consolidated Statements of Cash Flows (Unaudited)	7
Consolidated Statements of Changes in Shareholder's Equity (Unaudited)	8
Notes to Consolidated Financial Statements (Unaudited)	89
Item 2. Management's Narrative Analysis of Results of Operations	24
Item 4. Controls and Procedures	2627
Part II - OTHER INFORMATION
Item 1. Legal Proceedings	2728
Item 1A. Risk Factors	28
Item 6. Exhibits	28
SIGNATURE	29
EX-4-282
EX-12-51
EX-4-283
EX-31-93
EX-12-50
EX-31-94
EX-31-91
EX-32-93
EX-31-92
EX-32-94
EX-32-91
EX-32-92
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

COA		U.S. Court of Appeals for the District of Columbia
Company		DTE Electric Company and any subsidiary companies
Customer Choice		Michigan legislation giving customers the option to choose alternative suppliers for electricity.
DOE		U.S. Department of Energy
DTE Electric		DTE Electric Company (a direct wholly owned subsidiary of DTE Energy Company) and subsidiary companies.
DTE Energy		DTE Energy Company, directly or indirectly the parent of DTE Electric, DTE Gas Company and numerous non-utility subsidiaries
EPA		U.S. Environmental Protection Agency
FASB		Financial Accounting Standards Board
FERC		Federal Energy Regulatory Commission
FOV		Finding of Violation
FTRs		Financial transmission rights are financial instruments that entitle the holder to receive payments related to costs incurred for congestion on the transmission grid.
MDEQ		Michigan Department of Environmental Quality
MISO		Midcontinent Independent System Operator, Inc.
MPSC		Michigan Public Service Commission
MTM		Mark to Market
NEIL		Nuclear Electric Insurance Limited
NOV		Notice of Violation
NRC		U.S. 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.
PLD		City of Detroit's Public Lighting Department
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.
TRIA		Terrorism Risk Insurance Extension Act of 2005
TRM		Transitional Reconciliation Mechanism
VIE		Variable Interest Entity



Units of Measurement

kWh	Kilowatthour of electricity

MWh	Megawatthour of electricity

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,” “aspiration” 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;, including legislative amendments and Customer Choice programs;


•	economic conditions and population changes in our geographic area resulting in changes in demand, customer conservation and thefts of electricity;


•	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;


•	contract disputes, 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.

Part I — Financial Information

Item 1. Financial Statements

DTE Electric Company

Consolidated Statements of Operations (Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
	(In millions)
Operating Revenues	$	1,~~281~~357		$	1,~~265~~457		$	24,~~691~~048		$	23,~~484~~941
Operating Expenses
Fuel and purchased power	~~400~~430			~~435~~487			~~898~~1,328			~~807~~1,294
Operation and maintenance	~~329~~351			~~343~~335			~~671~~1,022			~~674~~1,009
Depreciation and amortization	~~229~~238			~~221~~233			~~457~~695			~~433~~666
Taxes other than income	6566			6367			~~136~~202			~~133~~200
Asset (gains) losses and reserves, net	(1—		)	1(3		)	(1		)	—(3		)
	1,022			1,063			2,161			2,047
	1,085			1,119			3,246			3,166
Operating Income	~~259~~272			~~202~~338			~~530~~802			~~437~~775
Other (Income) and Deductions
Interest expense	6165			68			~~124~~189			~~134~~202
Other income	(1715		)	(914		)	(3045		)	(2438		)
Other expenses	811			67			1526			1219
	52			65			109			122
	61			61			170			183
Income Before Income Taxes	~~207~~211			~~137~~277			~~421~~632			~~315~~592
Income Tax Expense	7775			4797			~~154~~229			~~109~~206
Net Income	$	~~130~~136		$	90180		$	~~267~~403		$	~~206~~386

See Notes to Consolidated Financial Statements (Unaudited)

DTE Electric Company

Consolidated Statements of Comprehensive Income (Unaudited)

	Three Months Ended June 30,				Six Months Ended June 30,
	Three Months Ended September 30,				Nine Months Ended September 30,
	2014		2013		2014			2013
	(In millions)
Net income	$	~~130~~136	$	90180	$	~~267~~403		$	~~206~~386
Other comprehensive income (loss), net of tax:
Other comprehensive income, net of tax:
Benefit obligations, net of taxes of $1, $—, $— and $—, respectively	—		1		(1		)	1
Benefit obligations, net of taxes of $0, $0, $0 and $1, respectively	1		1		—			2
Comprehensive income	$	~~130~~137	$	91181	$	~~266~~403		$	~~207~~388

See Notes to Consolidated Financial Statements (Unaudited)

DTE Electric Company

Consolidated Statements of ~~Cash~~Financial ~~Flows~~Position (Unaudited)

	Six Months Ended June 30,
	September 30,			December 31,
	2014			2013
	(In millions)
Operating Activities
ASSETS
Net income	$	267		$	206
Current Assets
Adjustments to reconcile net income to net cash from operating activities:
Cash and cash equivalents	$	28		$	27
Depreciation and amortization	457			433
Restricted cash, principally Securitization	40			100
Nuclear fuel amortization	19			17
Accounts receivable (less allowance for doubtful accounts of $30 and $28, respectively)
Allowance for equity funds used during construction	(11		)	(6		)
Customer	718			723
Deferred income taxes	145			61
Affiliates	2			24
Changes in assets and liabilities:
Other	16			24
Accounts receivable, net	(14		)	(84		)
Inventories
Inventories	(28		)	43
Fuel	212			188
Accounts payable	10			18
Materials and supplies	229			215
Accrued pension liability — affiliates	(83		)	(134		)
Notes receivable
Accrued postretirement liability — affiliates	(28		)	(138		)
Affiliates	36			200
Regulatory assets and liabilities	(152		)	217
Other	12			2
Other assets	(53		)	11
Regulatory assets	46			13
Other liabilities	(34		)	(27		)
Prepaid property tax	97			41
Net cash from operating activities	495			617
Other	30			27
Investing Activities
	1,466			1,584
Plant and equipment expenditures	(832		)	(607		)
Investments
Restricted cash for debt redemption, principally Securitization	12			12
Nuclear decommissioning trust funds	1,229			1,191
Notes receivable from affiliate	200			(1		)
Other	169			160
Proceeds from sale of nuclear decommissioning trust fund assets	475			309
	1,398			1,351
Investment in nuclear decommissioning trust funds	(483		)	(317		)
Property
Other Investments	(15		)	(15		)
Property, plant and equipment	19,518			18,730
Net cash used for investing activities	(643		)	(619		)
Less accumulated depreciation and amortization	(7,183		)	(6,951		)
Financing Activities
	12,335			11,779
Issuance of long-term debt, net of issuance costs	248			371
Other Assets
Redemption of long-term debt	(281		)	(152		)
Regulatory assets	2,171			2,275
Short-term borrowings — other	275			(34		)
Securitized regulatory assets	86			231
Short-term borrowings — affiliate	97			(20		)
Intangible assets	39			41
Dividends on common stock	(185		)	(171		)
Other	177			149
Other	(4		)	(2		)
	2,473			2,696
Net cash from (used for) financing activities	150			(8		)
Total Assets	$	17,672		$	17,410
Net Increase (Decrease) in Cash and Cash Equivalents	2			(10		)
Cash and Cash Equivalents at Beginning of the Period	27			30
Cash and Cash Equivalents at End of the Period	$	29		$	20
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	152		$	130

See Notes to Consolidated Financial Statements (Unaudited)

DTE Electric Company

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

	June 30,			December 31,
	September 30,			December 31,
	2014			2013
	(In millions)
	(In millions, except shares)
ASSETS
LIABILITIES AND SHAREHOLDER’S EQUITY
Current Assets
Current Liabilities
Cash and cash equivalents	$	29		$	27
Accounts payable
Restricted cash, principally Securitization	88			100
Affiliates	$	54		$	60
Accounts receivable (less allowance for doubtful accounts of $27 and $28, respectively)
Other	346			424
Customer	749			723
Accrued interest	66			61
Affiliates	17			24
Current portion long-term debt, including capital leases	119			504
Other	39			24
Regulatory liabilities	162			278
Inventories
Deferred income taxes	106			91
Fuel	210			188
Short-term borrowings
Materials and supplies	221			215
Affiliates	56			58
Notes receivable
Other	254			—
Affiliates	—			200
Other	142			177
Other	12			2
	1,305			1,653
Regulatory assets	52			13
Long-Term Debt (net of current portion)
Other	73			68
Mortgage bonds, notes and other	5,144			4,540
	1,490			1,584
Securitization bonds	—			105
Investments
Capital lease obligations	—			4
Nuclear decommissioning trust funds	1,237			1,191
	5,144			4,649
Other	167			160
Other Liabilities
	1,404			1,351
Deferred income taxes	2,986			2,807
Property
Regulatory liabilities	276			386
Property, plant and equipment	19,276			18,730
Asset retirement obligations	1,745			1,667
Less accumulated depreciation and amortization	(7,085		)	(6,951		)
Unamortized investment tax credit	37			41
	12,191			11,779
Nuclear decommissioning	179			178
Other Assets
Accrued pension liability — affiliates	583			705
Regulatory assets	2,175			2,275
Accrued postretirement liability — affiliates	327			369
Securitized regulatory assets	135			231
Other	110			101
Intangible assets	40			41
	6,243			6,254
Other	158			149
Commitments and Contingencies (Notes 7 and 10)
	2,508			2,696
Shareholder’s Equity
Total Assets	$	17,593		$	17,410
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	3,596			3,596
Retained earnings	1,400			1,274
Accumulated other comprehensive loss	(16		)	(16		)
	4,980			4,854
Total Liabilities and Shareholder’s Equity	$	17,672		$	17,410

See Notes to Consolidated Financial Statements (Unaudited)

DTE Electric Company

Consolidated Statements of ~~Financial~~Cash ~~Position~~Flows (Unaudited) ~~— (Continued)~~

	June 30,			December 31,
	Nine Months Ended September 30,
	2014			2013
	(In millions, except shares)
	(In millions)
LIABILITIES AND SHAREHOLDER’S EQUITY
Operating Activities
Current Liabilities
Net income	$	403		$	386
Accounts payable
Adjustments to reconcile net income to net cash from operating activities:
Affiliates	$	57		$	60
Depreciation and amortization	695			666
Other	359			424
Nuclear fuel amortization	33			25
Accrued interest	57			61
Allowance for equity funds used during construction	(16		)	(10		)
Current portion long-term debt, including capital leases	215			504
Deferred income taxes	199			104
Regulatory liabilities	148			278
Asset (gains) losses and reserves, net	—			(3		)
Deferred income taxes	103			91
Changes in assets and liabilities:
Short-term borrowings
Accounts receivable, net	36			(40		)
Affiliates	155			58
Inventories	(38		)	53
Other	275			—
Accounts payable	7			15
Other	150			177
Accrued pension liability — affiliates	(122		)	(229		)
	1,519			1,653
Accrued postretirement liability — affiliates	(42		)	(148		)
Long-Term Debt (net of current portion)
Regulatory assets and liabilities	(163		)	302
Mortgage bonds, notes and other	4,905			4,540
Other assets	(74		)	(42		)
Securitization bonds	—			105
Other liabilities	(39		)	(15		)
Capital lease obligations	—			4
Net cash from operating activities	879			1,064
	4,905			4,649
Investing Activities
Other Liabilities
Plant and equipment expenditures	(1,143		)	(946		)
Deferred income taxes	2,937			2,807
Restricted cash for debt redemption, principally Securitization	60			58
Regulatory liabilities	293			386
Notes receivable from affiliate	164			(4		)
Asset retirement obligations	1,717			1,667
Proceeds from sale of nuclear decommissioning trust fund assets	652			477
Unamortized investment tax credit	37			41
Investment in nuclear decommissioning trust funds	(665		)	(489		)
Nuclear decommissioning	180			178
Other	(16		)	(21		)
Accrued pension liability — affiliates	622			705
Net cash used for investing activities	(948		)	(925		)
Accrued postretirement liability — affiliates	341			369
Financing Activities
Other	107			101
Issuance of long-term debt, net of issuance costs	942			768
	6,234			6,254
Redemption of long-term debt	(837		)	(491		)
Commitments and Contingencies (Notes 7 and 10)
Short-term borrowings — other	254			(119		)
Shareholder’s Equity
Short-term borrowings — affiliate	(2		)	(25		)
Common stock, $10 par value, 400,000,000 shares authorized, and 138,632,324 shares issued and outstanding	3,596			3,596
Dividends on common stock	(277		)	(257		)
Retained earnings	1,356			1,274
Other	(10		)	(2		)
Accumulated other comprehensive loss	(17		)	(16		)
Net cash from (used for) financing activities	70			(126		)
	4,935			4,854
Net Increase in Cash and Cash Equivalents	1			13
Total Liabilities and Shareholder’s Equity	$	17,593		$	17,410
Cash and Cash Equivalents at Beginning of the Period	27			30
Cash and Cash Equivalents at End of the Period	$	28		$	43
Supplemental disclosure of non-cash investing and financing activities
Plant and equipment expenditures in accounts payable	$	139		$	155

See Notes to Consolidated Financial Statements (Unaudited)

DTE Electric Company

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

				AdditionalPaid-inCapital					AccumulatedOtherComprehensiveLoss
				Additional Paid-in Capital		Retained Earnings			Accumulated Other Comprehensive Loss
	Common Stock					~~RetainedEarnings~~
	Shares	Amount										Total
	(Dollars in millions, shares in thousands)
Balance, December 31, 2013	138,632	$	1,386	$	2,210	$	1,274		$	(16	)	$	4,854
Net income	—	—		—		~~267~~403			—			~~267~~403
Dividends declared on common stock	—	—		—		(~~185~~277		)	—			(~~185~~277		)
Benefit obligations, net of tax	—	—		—		—			(1		)	(1		)
Balance, September 30, 2014	138,632	$	1,386	$	2,210	$	1,400		$	(16	)	$	4,980
Balance, June 30, 2014	138,632	$	1,386	$	2,210	$	1,356		$	(17	)	$	4,935

See Notes to Consolidated Financial Statements (Unaudited)

~~NOTE~~ ~~1 — BASIS OF PRESENTATION~~8

DTE Electric Company

Notes to Consolidated Financial Statements (Unaudited)

NOTE 1 — ORGANIZATION AND BASIS OF PRESENTATION

Corporate Structure

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

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

Basis of Presentation

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

The accompanying Consolidated Financial Statements are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Company’s estimates.

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

~~Certain~~Prior ~~prior~~ year balances were ~~reclassified~~revised to ~~match~~reflect ~~the~~an ~~current~~increase ~~year's~~of ~~financial~~$437 ~~statement~~million ~~presentation. Such revisions included an increase~~ in the Consolidated Statements of Cash Flows line items for (i) Proceeds from sale of nuclear decommissioning trust funds, and (ii) Investment in nuclear decommissioning trust funds ~~by $282 million~~ for the ~~six~~nine months ended ~~June~~September 30, 2013. These revisions were needed to properly state the gross purchases and sales activity in the nuclear decommissioning trust fund for the ~~six~~nine months ended ~~June~~September 30, 2013. The total of Net cash used infor investing activities for the ~~six~~nine months ended ~~June~~September 30, 2013 was unchanged by these revisions. The revisions noted above are not deemed material, individually or in the aggregate, to the prior period ~~consolidated~~Consolidated ~~financial~~Financial ~~statements~~Statements.

Principles of Consolidation

The Company consolidates all majority-owned subsidiaries and investments in entities in which it has controlling influence. Non-majority owned investments are accounted for using the equity method when the Company is able to influence the operating policies of the investee. When the Company does not influence the operating policies of an investee, the cost method is used. These ~~consolidated~~Consolidated ~~financial~~Financial ~~statements~~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 8Company has variable interests in VIEs through certain of its long-term purchase contracts. As of September 30, 2014, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any significant 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.

DTE Electric Company

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

The Company has variable interests in VIEs through certain of its long-term purchase contracts. As of June 30, 2014, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase contracts are predominately related to working capital accounts and generally represent the amounts owed by the Company for the deliveries associated with the current billing cycle under the contracts. The Company has not provided any significant 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 June 30, 2014 and December 31, 2013 restricted for Securitization that are either (1) assets that can be used only to settle their obligations related to Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.

	June 30,		December 31,
	2014		2013
	(In millions)
ASSETS
Restricted cash	$	88	$	100
Accounts receivable	39		34
Securitized regulatory assets	135		231
Other long-term assets	2		4
	$	264	$	369
LIABILITIES
Accounts payable and accrued current liabilities	$	5	$	7
Current portion long-term debt	201		196
Current regulatory liabilities	41		43
Securitization bonds	—		105
Other long-term liabilities	8		8
	$	255	$	359

DTE Electric Company

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

The following table summarizes the major balance sheet items as of September 30, 2014 and December 31, 2013 restricted for Securitization that are either (1) assets that can be used only to settle their obligations related to Securitization or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary.



	September 30,		December 31,
	2014		2013
	(In millions)
ASSETS
Restricted cash	$	40	$	100
Accounts receivable	40		34
Securitized regulatory assets	86		231
Other long-term assets	2		4
	$	168	$	369

LIABILITIES
Accounts payable and accrued current liabilities	$	1	$	7
Current portion long-term debt	105		196
Current regulatory liabilities	44		43
Securitization bonds	—		105
Other long-term liabilities	9		8
	$	159	$	359

NOTE 2 — SIGNIFICANT ACCOUNTING POLICIES

~~Comprehensive~~Changes ~~Income~~in (Accumulated Other Comprehensive Loss)

~~Comprehensive~~For ~~income (loss) is~~ the ~~change~~three inand ~~common~~nine ~~shareholders'~~months ~~equity~~ended ~~during~~September a30, ~~period~~2014 ~~from transactions~~ and ~~events from non-owner sources~~2013, ~~including~~reclassifications ~~net~~out ~~income. As~~of ~~shown in the following tables, amounts recorded to~~ accumulated other comprehensive loss for the ~~three~~Company ~~and~~were ~~six~~not ~~months~~material. Changes ~~ended~~in ~~June~~accumulated ~~30,~~other ~~2014~~comprehensive ~~include~~loss ~~unrealized~~are ~~gains~~presented ~~and losses on available-for-sale securities, and changes~~ in ~~benefit~~the ~~obligations,~~Consolidated ~~consisting~~Statements of ~~deferred~~Changes ~~actuarial~~in ~~losses,~~Shareholder’s ~~prior service costs and transition amounts related to pension and other postretirement benefit plans~~Equity.

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Three Months Ended June 30, 2014
	Net Unrealized Gain/(Loss) on Investments		Benefit Obligations			Total
	(In millions)
Beginning balance, March 31, 2014	$	1	$	(18	)	$	(17	)
Other comprehensive income before reclassifications	—		—			—
Amounts reclassified from Accumulated other comprehensive income	—		—			—
Net current-period other comprehensive income	—		—			—
Ending balance, June 30, 2014	$	1	$	(18	)	$	(17	)

	Changes in Accumulated Other Comprehensive Loss by Component (a)
	Six Months Ended June 30, 2014
	Net Unrealized Gain/(Loss) on Investments		Benefit Obligations			Total
	(In millions)
Beginning balance, December 31, 2013	$	1	$	(17	)	$	(16	)
Other comprehensive income before reclassifications	—		(1		)	(1		)
Amounts reclassified from Accumulated other comprehensive income	—		—			—
Net current-period other comprehensive income	—		(1		)	(1		)
Ending balance, June 30, 2014	$	1	$	(18	)	$	(17	)

_______________________________________

(a) All amounts are net of tax.

Intangible Assets

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

	June 30,		December 31,
	September 30,		December 31,
	2014		2013
	(In millions)
Emission allowances	$	21	$	2
Renewable energy credits	5150		51
	53		53
	51		53
Less current intangible assets	1312		12
	$	4039	$	41

Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business.

DTE Electric Company

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

Income Taxes

The Company's effective tax rate for the three months ended ~~June~~September 30, 2014 was 3736% as compared to 3435% for the three months ended ~~June~~September 30, 2013. The Company's effective tax rate for the ~~six~~nine months ended ~~June~~September 30, 2014 was 3736% as compared to 35% for the ~~six~~nine months ended ~~June~~September 30, 2013. ~~The increases in the effective tax rates are due primarily to a reduction in the domestic production activities tax benefit.~~

DTE Electric had an income tax ~~receivable~~payable of $162 million at ~~June~~ September 30, 2014 and an income tax receivable of $23 million at December 31, 2013 ~~due~~with ~~from~~ DTE Energy.

The Company had $3 million of unrecognized tax benefits at ~~June~~ September 30, 2014, that, if recognized, would favorably impact its effective tax rate. The Company does not anticipate any material changes to the unrecognized tax benefits in the next twelve months.

Stock-Based Compensation

The Company received an allocation of costs from DTE Energy associated with stock-based compensation of $1014 million and $1910 million for the three months ended ~~June~~September 30, 2014 and 2013, respectively while such allocation was $2943 million ~~and $33 million~~ for the ~~six~~nine months ended ~~June~~September 30, 2014 and 2013, respectively.

NOTE 3 — NEW ACCOUNTING PRONOUNCEMENTS

In May 2014, the ~~Financial Accounting Standards Board (~~FASB) issued Accounting Standards Update (ASU) No. 2014-09, Revenue from Contracts with Customers. The objectives of this ASU are to improve upon revenue recognition requirements by providing a single comprehensive model to determine the measurement of revenue and timing of recognition. The core principle is that an entity will recognize revenue to depict the transfer of goods or services to customers at an amount that the entity expects to be entitled to in exchange for those goods or services. This ASU also requires expanded qualitative and quantitative disclosures regarding the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. The revenue standard is effective for the first interim period within annual reporting periods beginning after December 15, 2016 and is to be applied retrospectively. Early adoption is not permitted. The Company is currently assessing the impact of this ASU on its ~~consolidated~~Consolidated ~~financial~~Financial ~~statements~~Statements.

NOTE 4 — 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 ~~June~~September 30, 2014 and December 31, 2013. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.

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


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

DTE Electric Company

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


•	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 ~~June~~September 30, 2014 and December 31, 2013:

	June 30, 2014								December 31, 2013
	September 30, 2014								December 31, 2013
	Level 1		Level 2		Level 3		Net Balance		Level 1		Level 2		Level 3		Net Balance
	(In millions)
Assets:
Cash equivalents (a)	$	5	$	9651	$	—	$	~~101~~56	$	2	$	114	$	—	$	116
Nuclear decommissioning trusts	~~798~~789		~~439~~440		—		1,~~237~~229		779		412		—		1,191
Other investments (b)	92		5051		—		~~142~~143		91		44		—		135
Derivative assets — FTRs	—		—		74		74		—		—		3		3
Total	$	~~895~~886	$	~~585~~542	$	74	$	1,~~487~~432	$	872	$	570	$	3	$	1,445
Assets:
Current	$	5	$	9651	$	74	$	~~108~~60	$	2	$	114	$	3	$	119
Noncurrent	~~890~~881		~~489~~491		—		1,~~379~~372		870		456		—		1,326
Total Assets	$	~~895~~886	$	~~585~~542	$	74	$	1,~~487~~432	$	872	$	570	$	3	$	1,445

_______________________________________

(a) At ~~June~~September 30, 2014, available-for-sale securities of $~~101~~56 million, included $8840 million and $1316 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position. At December 31, 2013, available-for-sale securities of $116 million, included $100 million and $16 million of cash equivalents included in Restricted cash and Other investments, respectively, on the Consolidated Statements of Financial Position.

(b) Available-for-sale equity securities at both ~~June~~September 30, 2014 and December 31, 2013 of $7 million are included in Other investments on the Consolidated Statements of Financial Position.

Cash Equivalents

Cash equivalents include investments with maturities of three months or less when purchased. The cash equivalents shown in the fair value table are comprised of short-term investments and money market funds.

Nuclear Decommissioning Trusts and Other Investments

The nuclear decommissioning trusts and other investments hold debt and equity securities directly and indirectly through institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The institutional mutual funds hold exchange-traded equity or debt securities and are valued based on stated net asset values (NAV). Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered to be preferable. The Company has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, the Company selectively corroborates the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by the Company's Trust Investments Department which reports to the Company's Vice President and Treasurer.

DTE Electric Company

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

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 ~~six~~nine months ended ~~June~~September 30, 2014 and 2013:

	Three Months EndedJune 30,						Six Months EndedJune 30,
	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
	(In millions)
Net Assets as of beginning of the period	$	1		$	1		$	3		$	1
Net Assets as of beginning of period	$	7		$	2		$	3		$	1
Change in fair value recorded in regulatory assets/liabilities	7(3		)	3			119			47
Purchases, issuances and settlements:
Settlements	(1—		)	(2—		)	(78		)	(3		)
Net Assets as of June 30	$	7		$	2		$	7		$	2
Net Assets as of September 30,	$	4		$	5		$	4		$	5
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 June 30, 2014 and 2013	$	7		$	2		$	7		$	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, 2014 and 2013	$	(1	)	$	3		$	4		$	5

No transfers between Levels 1, 2 or 3 occurred in the three and ~~six~~nine months ended ~~June~~ September 30, 2014 and 2013.

Fair Value of Financial Instruments

The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. The Company has obtained an understanding of how the fair values are derived. The Company also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are estimated using discounted cash flow techniques that incorporate market interest rates as well as assumptions about the remaining life of the loans and credit risk. Depending on the information available, other valuation techniques may be used that rely on internal assumptions and models. Valuation policies and procedures are determined by the Company's Treasury Department which reports to the Company's Vice President and Treasurer.

DTE Electric Company

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

The following table presents the carrying amount and fair value of financial instruments as of ~~June~~ September 30, 2014 and December 31, 2013:

	June 30, 2014								December 31, 2013
	September 30, 2014								December 31, 2013
	Carrying		Fair Value						Carrying		Fair Value
	Amount		Level 1		Level 2		Level 3		Amount		Level 1		Level 2		Level 3
	(In millions)
Notes receivable, excluding capital leases	$	1314	$	—	$	—	$	1314	$	10	$	—	$	—	$	10
Notes receivable — affiliates	$	—36	$	—	$	—	$	—36	$	200	$	—	$	—	$	200
Short-term borrowings — affiliates	$	~~155~~56	$	—	$	—	$	~~155~~56	$	58	$	—	$	—	$	58
Short-term borrowings — other	$	~~275~~254	$	—	$	~~275~~254	$	—	—		$	—	$	—	$	—
Long-term debt, excluding capital leases	$	5,~~116~~259	$	—	$	5,~~233~~062	$	~~352~~728	$	5,146	$	—	$	5,253	$	136

Nuclear Decommissioning Trust Funds

DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. This obligation is reflected as an asset retirement obligation on the Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates.

The following table summarizes the fair value of the nuclear decommissioning trust fund assets:

	June 30,		December 31,
	September 30,		December 31,
	2014		2013
	(In millions)
Fermi 2	$	1,~~214~~205	$	1,172
Fermi 1	3		3
Low-level radioactive waste	2021		16
Total	$	1,~~237~~229	$	1,191

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

	Three Months Ended June 30,						Six Months Ended June 30,
	Three Months Ended September 30,						Nine Months Ended September 30,
	2014			2013			2014			2013
	(In millions)
Realized gains	$	78		$	11		$	1624		$	1930
Realized losses	$	(43	)	$	(711	)	$	(1114	)	$	(1425	)
Proceeds from sales of securities	$	~~204~~177		$	~~173~~168		$	~~475~~652		$	~~309~~477

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:

	June 30, 2014				December 31, 2013
	September 30, 2014				December 31, 2013
	FairValue		UnrealizedGains		FairValue		UnrealizedGains
	Fair		Unrealized		Fair		Unrealized
	Value		Gains		Value		Gains
	(In millions)
Equity securities	$	~~762~~748	$	~~220~~209	$	730	$	201
Debt securities	~~462~~465		1918		442		12
Cash and cash equivalents	1316		—		19		—
	$	1,~~237~~229	$	~~239~~227	$	1,191	$	213

The debt securities at June 30, 2014 and December 31, 2013 had an average maturity of approximately 7 years, respectively. Securities held in the nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.

DTE Electric Company

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

~~Unrealized~~The ~~losses~~debt ~~incurred~~securities ~~by the Fermi 2 trust are recognized as a Regulatory asset. DTE Electric recognized $28 million and $31 million of unrealized losses as Regulatory assets~~ at ~~June~~ September 30, 2014 and December 31, 2013, ~~respectively. Since~~had ~~the~~an ~~decommissioning~~average maturity of ~~Fermi~~approximately 17 isyears, ~~funded~~respectively. Securities byheld ~~DTE~~in ~~Electric~~the ~~rather~~nuclear ~~than~~decommissioning ~~through~~trust afunds ~~regulatory~~are ~~recovery~~classified ~~mechanism,~~as ~~there is no corresponding regulatory asset treatment~~available-for-sale. ~~Therefore,~~As ~~unrealized~~DTE ~~losses~~Electric ~~incurred~~does bynot have the ~~Fermi~~ability 1to ~~trust~~hold ~~are~~impaired ~~recognized~~investments infor ~~earnings~~a ~~immediately. There~~period ~~were~~of notime ~~unrealized~~sufficient ~~losses~~to ~~recognized~~allow infor the ~~three~~anticipated ~~and~~recovery ~~six~~of ~~months~~market ~~ended~~value, ~~June~~all ~~30,~~unrealized ~~2014~~losses ~~and~~are ~~2013~~considered ~~for~~to ~~Fermi~~be 1other-than-temporary impairments.

Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset. DTE Electric recognized $37 million and $31 million of unrealized losses as Regulatory assets at September 30, 2014 and December 31, 2013, respectively.

Other Securities

At ~~June~~September 30, 2014 and December 31, 2013, the securities were comprised primarily of money market and equity securities. During the three and ~~six~~nine months ended ~~June~~September 30, 2014 and 2013, no amounts of unrealized losses on available-for-sale securities were reclassified out of other comprehensive income and realized into net income for the periods. Gains related to trading securities held at ~~June~~September 30, 2014 and 2013 were $78 million and $812 million, respectively.

NOTE 5 — FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS

The Company recognizes all derivatives at their fair value as Derivative assets or liabilities on the Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge), or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in 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 MTM and 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 ~~June~~September 30, 2014 and December 31, 2013:

	June 30,		December 31,
	September 30,		December 31,
	2014		2013
	(In millions)
FTRs — Other current assets	$	74	$	3
Total derivatives not designated as hedging instrument	$	74	$	3

DTE Electric Company

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

NOTE 6 — ASSET RETIREMENT OBLIGATIONS

A reconciliation of the asset retirement obligations for the ~~six~~nine months ended ~~June~~September 30, 2014 follows:

	(In millions)
Asset retirement obligations at December 31, 2013	$	1,667
Accretion	5177
Liabilities incurred	78
Liabilities settled	(3		)
Revision in estimated cash flows	(54		)
Asset retirement obligations at June 30, 2014	$	1,717
Asset retirement obligations at September 30, 2014	$	1,745

NOTE 7 — REGULATORY MATTERS

Refundable Revenue Decoupling (RDM)/ Deferred Gain Amortization

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

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

Transitional Reconciliation Mechanism (TRM)

On July 19, 2013, DTE Electric filed its TRM application proposing a transitional tariff option for certain former PLD customers and a modified line extension provision. The application also proposed a recovery mechanism for the deferred net incremental revenue requirement 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 May 13, 2014, the MPSC approved the TRM as requested and also ordered DTE Electric to include in the TRM the PLD transmission delivery service costs incurred while DTE Electric is temporarily relying upon PLD to operate and maintain PLD's system during the system conversion period. The meter installation phase of the transition was completed in June 2014. On July 1, 2014, former PLD customers became customers of DTE Electric.

PSCR Proceedings

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

2012 PSCR Year — In March 2013, DTE Electric filed the 2012 PSCR reconciliation calculating a net under-recovery of approximately $87 million that includes an under-recovery of approximately $148 million for the 2011 PSCR year. The reconciliation includes purchased power costs related to the manual shutdown of our Fermi 2 nuclear power plant in June 2012 caused by the failure of one of the plant's two non-safety related feed-water pumps. The plant was restarted on July 30, 2012, which restored production to nominal 68% of full capacity. In September 2013, the repair to the plant was completed and production was returned to full capacity. DTE Electric was able to purchase sufficient power from MISO to continue to provide uninterrupted service to our customers. Certain intervenors in the reconciliation case have challenged the recovery of up to $32 million of the Fermi- 2 related purchased power costs. Resolution of this matter is expected by ~~late 2014 or~~ early 2015.

DTE Electric Company

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

NOTE 8 — LONG-TERM DEBT

Debt Issuances

In 2014, the following debt was issued:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
June	Mortgage Bonds (a)	3.77%	2026	$	100
June	Mortgage Bonds (a)	4.60%	2044	150
				$	250
July	Mortgage Bonds (a)	3.375%	2025	350
July	Mortgage Bonds (a)	4.30%	2044	350
				$	950

_______________________________________


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

In July 2014, DTE Electric issued $350 million of 3.375% mortgage bonds due 2025 and $350 million of 4.30% mortgage bonds due 2044. Proceeds will be used for redemption of DTE Electric long-term debt, for the repayment of short-term borrowings and for general corporate purposes.

Debt Redemptions

In 2014, the following debt was redeemed:

Month	Type	Interest Rate	Maturity	Amount
				(In millions)
March	Mortgage Bonds	Various	2014	$	13
March	Securitization Bonds	6.62%	2014	100
April	Tax Exempt Revenue Bonds (a)	2.35%	2024	31
April	Tax Exempt Revenue Bonds (a)	4.65%	2028	32
June	Tax Exempt Revenue Bonds (a)	4.875%	2029	36
June	Tax Exempt Revenue Bonds (a)	6.00%	2036	69
				$	281
July	Senior Notes	4.80%	2015	200
August	Senior Notes	5.40%	2014	200
August	Tax Exempt Revenue Bonds (a)	5.25%	2029	60
September	Securitization Bonds	6.62%	2014	96
				$	837

_______________________________________

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

In June 2014, DTE Electric called for redemption $200 million of 4.80% senior notes due in February 2015 to be redeemed in July 2014 and $60 million of 5.25% tax exempt revenue bonds due in August 2029 to be redeemed in August 2014.

NOTE 9 — 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 ~~June~~ September 30, 2014, there was $~~275~~254 million outstanding against the facility, while there were no amounts outstanding against the facility at December 31, 2013.

The agreement requires the Company to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. In the agreement, “total funded debt” means all indebtedness of the Company and its consolidated subsidiaries, including capital lease obligations, hedge agreements and guarantees of third parties' debt, but excluding contingent obligations and nonrecourse and junior subordinated debt. “Capitalization” means the sum of (a) total funded debt plus (b) “consolidated net worth,” which is equal to consolidated total stockholders' equity of the Company and its consolidated subsidiaries (excluding pension effects under certain FASB statements), as determined in accordance with accounting principles generally accepted in the United States of America. At ~~June~~ September 30, 2014, the total funded debt to total capitalization ratio for DTE Electric was 0.52 to 1 and is in compliance with this financial covenant.

DTE Electric Company

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

NOTE 10 — 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 spent approximately $2 billion through 2013. The Company estimates DTE Electric will make capital expenditures of approximately $~~280~~200 million in 2014 and up to approximately $1.2 billion of additional capital expenditures through 2021 based on current regulations. Further, additional rulemakings are expected over the next few years which could require additional controls for sulfur dioxide, nitrogen oxides and other hazardous air pollutants. The Cross State Air Pollution Rule (CSAPR), finalized in July 2011, required further reductions of sulfur dioxide and nitrogen oxides emissions beginning in 2012. On December 30, 2011, the U.S. Court of Appeals for the District of Columbia (D.C.) Circuit (Court of Appeals) 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 of Appeals issued its decision, vacating CSAPR and leaving CAIR in place. The EPA's petition seeking a rehearing of the 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 for a review of the Court of Appeals' decision on CSAPR. On April 29, 2014, the U.S. Supreme Court issued its ruling reversing the Court of Appeals' stay decision and remanding the case for further proceedings. The EPA has since requested the Court of Appeals to lift the stay on CSAPR and proposed that phase one of the rule would start effective January 2015. Notwithstanding the U.S. Supreme Court remand decision and potential decision by the Court of Appeals to lift the stay, DTE Electric expects to meet its obligations under CSAPR beginning in 2015. Furthermore, the EPA and a number of states, including Michigan, have started working on the framework of revised CSAPR regulations which may still be proposed in the next few years to address other challenges to the existing CSAPR regulations. DTE Electric will continue to monitor these developments and adjust its compliance strategy accordingly.

~~The~~Additional ~~Mercury~~rulemakings are expected over the next few years which could require additional controls for sulfur dioxide, nitrogen oxides and other hazardous air pollutants. The Cross State Air ~~Toxics~~Pollution ~~Standard~~Rule (~~MATS~~CSAPR), ~~rule~~finalized in July 2011, ~~formerly~~required ~~known~~further asreductions of sulfur dioxide and nitrogen oxides emissions beginning in 2012. On December 30, 2011, the COA granted the motions to stay the rule, leaving DTE Electric ~~Generating~~temporarily ~~Unit~~subject ~~Maximum~~to ~~Achievable~~the ~~Control~~previously ~~Technology~~existing ~~(EGU~~Clean ~~MACT)~~Air Interstate Rule ~~was~~(CAIR). On ~~finalized~~August on21, ~~December~~2012, 16the COA issued its decision, ~~2011~~vacating CSAPR and leaving CAIR in place. The ~~MATS~~EPA's ~~rule~~petition ~~requires~~seeking ~~reductions~~a rehearing of ~~mercury~~the ~~and~~COA's ~~other~~decision ~~hazardous~~regarding ~~air~~the ~~pollutants~~CSAPR ~~beginning~~was indenied ~~April~~on ~~2015~~January 24, ~~with~~2013. On June 24, 2013, the U.S. Supreme Court granted EPA's petition for a ~~potential~~review ~~extension~~of tothe COA's decision on CSAPR. On April ~~2016~~29, 2014, the U.S. Supreme Court issued its ruling reversing the COA's stay decision and remanding the case for further proceedings. ~~DTE~~The ~~Electric~~EPA has since requested the COA to lift the stay on CSAPR and ~~been~~proposed ~~granted~~that ~~compliance~~phase ~~date~~one ~~extensions~~of ~~for~~the ~~all~~rule ~~relevant~~would ~~units~~start toeffective ~~April~~January ~~2016~~2015. ~~DTE~~Notwithstanding ~~Electric~~the ~~has~~U.S. ~~tested~~Supreme ~~technologies~~Court toremand ~~determine~~decision ~~technological~~ and ~~economic~~potential ~~feasibility~~decision asby ~~MATS~~the ~~compliance~~COA ~~alternatives~~to lift the stay, DTE Electric expects to ~~Flue~~meet ~~Gas~~its ~~Desulfurization~~obligations ~~(FGD)~~under ~~systems~~CSAPR beginning in 2015. ~~Implementation~~Furthermore, the EPA and a number of ~~Dry~~states, ~~Sorbent~~including ~~Injection~~Michigan, ~~(DSI)~~have ~~and~~started ~~Activated~~working ~~Carbon~~on ~~Injection~~the ~~(ACI)~~framework ~~technologies~~of ~~will~~revised ~~allow~~CSAPR ~~several~~regulations ~~units~~which ~~that~~may ~~would~~still ~~not~~be ~~have~~proposed ~~been~~in ~~economical~~the ~~for~~next ~~FGD~~few ~~installations~~years to address other challenges to the existing CSAPR regulations. DTE Electric will continue ~~operation~~to inmonitor these developments and adjust its compliance ~~with~~strategy ~~MATS~~accordingly.

The Mercury and Air Toxics Standard (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized on December 16, 2011. The MATS rule requires reductions of mercury and other hazardous air pollutants beginning in April 2015, with a potential extension to April 2016. DTE Electric has requested and been granted compliance date extensions for all relevant units to April 2016, with the exception of Monroe Power Plant. All Monroe Power Plant units will be in compliance with MATS requirements by April 2015. 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 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.

DTE Electric Company

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

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant, but not relating to the July 2009 NOV/FOV. Among other relief, the EPA requested the court to require DTE Electric to install and operate the best available control technology at Unit 2 of the Monroe Power Plant. Further, the EPA requested the court to issue a preliminary injunction to require DTE Electric to (i) begin the process of obtaining the necessary permits for the Monroe Unit 2 modification and (ii) offset the pollution from Monroe Unit 2 through emissions reductions from DTE Electric's fleet of coal-fired power plants until the new control equipment is operating. On August 23, 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. On March 3, 2014, the U.S. District Court judge granted again DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. On April 3, 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2 and 3, Belle River Units 1 and 2, Trenton Channel Unit 9 and denied the claims related to River Rouge ~~Unit~~that 3were brought by the Sierra Club. On June 30, 2014, the EPA filed a motion requesting certification for appeal of the March 3, 2014 summary judgment decision. On October 3, 2014, the EPA and the U.S. Department of Justice filed the anticipated notice of appeal of the U.S. District Court judge's dismissal of the Monroe Unit 2 case. This will officially start the appellate process. The amended New Source Review claims are all stayed until the appeal is resolved by the U.S. Court of Appeals for the Sixth Circuit.

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

In March 2013, the Sierra Club filed suit against DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs ~~allege~~alleged 1,499 six-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin the Company from operating the power plants except in complete compliance with applicable laws and permit requirements, pay civil penalties, conduct beneficial environmental mitigation projects, pay attorney fees and require the installation of any necessary pollution controls or to convert and/or operate the plants' boilers on natural gas to avoid additional violations and to off-set historic unlawful emissions. In December 2013, a U.S. District Court judge issued an order dismissing, without prejudice, the plaintiff's complaint allowing them to file an amended complaint by January 17, 2014. The order dismissing the complaint resulted from a considerable number of plaintiff's claims being time barred based on the statute of limitations. On January 17, 2014, the plaintiffs filed an amended complaint for the period January 13, 2008 - June 30, 2012, reducing the total number of six-minute periods from 1,499 to 1,139. DTE Electric filed an answer to the amended complaint on March 11, 2014. ~~The~~On ~~resolution~~October of16, ~~this~~2014, ~~matter~~the isSierra ~~not~~Club, ~~expected~~DTE toEnergy ~~have~~and DTE Electric filed a ~~material~~stipulation ~~effect~~to onvoluntary dismiss the ~~Company's~~litigation ~~operations~~in orits ~~financial statements~~entirety.

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 final rule was issued on May 19, 2014. The final rule specifies a time period exceeding three years to complete studies to determine the type of technology needed to reduce impacts to fish. Final compliance for the installation of the required technology will be determined by each state on a case by case basis. We are currently evaluating the compliance options and working with the State of Michigan on evaluating whether any controls are needed. These evaluations/studies may require modifications to some existing intake structures. It is not possible to quantify the impact of this rulemaking at this time.

On April 19, 2013, the EPA proposed revised steam electric effluent guidelines regulating wastewater streams from coal-fired power plants including multiple possible options for compliance. The rules are expected to be finalized by September 2015. DTE Electric has provided comments to the EPA. However, it is not possible at this time to quantify the impacts of these developing requirements.

DTE Electric Company

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

~~Contaminated~~On ~~and~~April ~~Other~~19, ~~Sites —~~2013, ~~Prior to~~ the ~~construction~~EPA ofproposed ~~major~~revised ~~interstate~~steam ~~natural~~electric ~~gas~~effluent ~~pipelines,~~guidelines ~~gas~~regulating ~~for~~wastewater ~~heating~~streams ~~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~~fired of gas manufacturing at each MGP 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~~including ~~underground~~multiple ~~and~~possible ~~aboveground~~options ~~storage~~for ~~tank locations~~compliance. The ~~findings~~rules ofare ~~these investigations indicated that the estimated cost to remediate these sites is~~ expected to be ~~incurred~~finalized ~~over~~by ~~the~~September ~~next several years~~2015. AtDTE ~~June~~Electric ~~30,~~has ~~2014~~provided ~~and~~comments ~~December 31,~~to ~~2013,~~ the ~~Company had $8 million accrued for remediation, respectively~~EPA. ~~Any change in assumptions~~However, ~~such~~it asis ~~remediation~~not ~~techniques,~~possible ~~nature~~at ~~and~~this ~~extent~~time ofto ~~contamination~~quantify ~~and regulatory requirements, could impact~~ the ~~estimate~~impacts of ~~remedial~~these ~~action~~developing ~~costs for the sites and affect the Company’s financial position and cash flows~~requirements. ~~The Company believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each site.~~

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 MGP 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, 2014 and December 31, 2013, the Company had $10 million and $8 million accrued for remediation, respectively. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company believes the likelihood of a material change to the accrued amount is remote based on current knowledge of the conditions at each site.

DTE Electric owns and operates three permitted engineered ash storage facilities to dispose of fly ash from the coal fired power plants. The EPA has published proposed rules to regulate coal ash under the authority of the Resources Conservation and Recovery Act (RCRA). The proposed rule published in June 2010 contains two primary regulatory options to regulate coal ash residue. The EPA is currently considering either designating coal ash as a “Hazardous Waste” as defined by RCRA or regulating coal ash as non-hazardous waste under RCRA. Agencies and legislatures have urged the EPA to regulate coal ash as a non-hazardous waste. If the EPA designates coal ash as a hazardous waste, the agency could apply some, or all, of the disposal and reuse standards that have been applied to other existing hazardous wastes to disposal and reuse of coal ash. Some of the regulatory actions currently being contemplated could have a significant impact on our operations and financial position and the rates we charge our customers. The rules are expected to be finalized by December 2014. It is not possible to quantify the impact of those expected rulemakings at this time.

Other

In December 2012, the EPA finalized a new set of regulations regarding the identification of non-hazardous secondary materials that are considered solid waste, industrial boiler and process heater maximum achievable control technologies (IBMACT) for major and area sources, and commercial/industrial solid waste incinerator new source performance standard and emission guidelines (CISWI). Capital costs for pollution controls and/or boiler conversions and the expenses for the one-time energy assessments are not expected to be material.

In 2010, the EPA finalized a new 1-hour sulfur dioxide ambient air quality standard that requires states to submit plans for non-attainment areas to be in compliance by 2017. Michigan's non-attainment area includes DTE Electric facilities in southwest Detroit and areas of Wayne County. Preliminary modeling runs by the MDEQ suggest that emission reductions may be required by significant sources of sulfur dioxide emissions in these areas, including DTE Electric power plants. The state implementation plan process is in the information gathering stage, and DTE Electric is unable to estimate any required emissions reductions at this time.

Nuclear Operations

Property Insurance

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

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

DTE Electric has $1.5 billion in primary coverage and $1.25 billion of excess coverage for stabilization, decontamination, debris removal, repair and/or replacement of property and decommissioning. The combined coverage limit for total property damage is $2.75 billion, subject to a $1 million deductible. The total limit for property damage for non-nuclear events is $2 billion and an aggregate of $327 million of coverage for extra expenses over a two-year period.

DTE Electric Company

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

InDTE ~~2007,~~Electric ~~the~~has ~~Terrorism Risk Insurance Extension Act of 2005 (TRIA) was extended through December 31, 2014~~$1. A5 ~~major~~billion ~~change~~ in ~~the~~primary ~~extension~~coverage isand ~~the~~$1.25 ~~inclusion~~billion of ~~“domestic”~~excess ~~acts~~coverage offor ~~terrorism~~stabilization, indecontamination, ~~the~~debris ~~definition~~removal, ofrepair ~~covered~~ and/or ~~“certified”~~replacement ~~acts. For multiple terrorism losses caused by acts~~ of ~~terrorism~~property ~~not~~and ~~covered~~decommissioning. The ~~under~~combined ~~the~~coverage ~~TRIA~~limit ~~occurring~~for ~~within~~total ~~one~~property ~~year~~damage ~~after~~is ~~the~~$2.75 ~~first~~billion, ~~loss~~subject ~~from~~to ~~terrorism,~~a ~~the~~$1 ~~NEIL~~million ~~policies~~deductible. The ~~would~~total ~~make~~limit ~~available~~for toproperty ~~all~~damage ~~insured~~for ~~entities~~non-nuclear upevents tois $3.2 billion, ~~plus~~and ~~any~~an ~~amounts~~aggregate ~~recovered~~of ~~from~~$327 ~~reinsurance,~~million ~~government~~of ~~indemnity,~~coverage orfor ~~other~~extra ~~sources~~expenses toover ~~cover~~a ~~losses~~two-year period.

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

Under the NEIL policies, DTE Electric could be liable for maximum assessments of up to approximately $35 million per event if the loss associated with any one event at any 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 that required DTE Electric to pay the DOE a fee of 1 mill per kWh of Fermi 2 electricity generated and sold. The fee iswas 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~~and ~~continues~~a tonewly ~~develop~~completed ~~its on-site~~ dry cask storage facility. The ~~and~~initial ~~has~~dry ~~scheduled~~cask ~~the~~loading ~~initial~~campaign ~~offload~~planned ~~from~~for ~~the~~2014 ~~spent~~has ~~fuel~~been ~~pool in 2014~~completed. 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 agreement, including extensions, provides for a claims process and payment of delay-related costs experienced by DTE Electric through 2016. DTE Electric has begun the claims process and claims are being settled and paid on a timely basis. The settlement proceeds reduce the cost of the dry cask storage facility assets and provide reimbursement for related operating expenses. The federal government continues to maintain its legal obligation to accept spent nuclear fuel from Fermi 2 for permanent storage. Issues relating to long-term waste disposal policy and to the disposition of funds contributed by DTE Electric ratepayers to the federal waste fund await future governmental action.

In February 2013, the ~~U.S. Court of Appeals for the District of Columbia (~~COA) granted a motion to reopen the fee adequacy litigation to review the DOE's latest fee adequacy report which was released in January 2013. In November 2013, the COA issued a decision ordering the DOE to submit a proposal to Congress to reduce the nuclear waste fee to zero until the DOE enacts an alternative nuclear waste management plan. In January 2014, the DOE submitted such a proposal to Congress that was scheduled to take effect in 90 legislative calendar days, absent legislative action to the contrary. Simultaneously, the DOE filed a petition for rehearing of the November 2013 decision with the COA. In March 2014, the COA denied DOE's petition for rehearing. The 1 mill per kWh fee was reduced to zero effective May 16, 2014.

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.

DTE Electric Company

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

Labor Contracts

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

Purchase Commitments

As of ~~June~~September 30, 2014, the Company was party to numerous long-term purchase commitments relating to a variety of goods and services required for the Company’s business. These agreements primarily consist of fuel supply commitments, renewable energy contracts and energy trading contracts. The Company estimates that these commitments will be approximately $2.3 billion from 2014 through 2033.

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

Bankruptcies

The Company purchases and sells electricity from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail and other industries. Certain of its customers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Company regularly reviews contingent matters relating to these customers and its purchase and sale contracts and records provisions for amounts considered at risk of probable loss. The Company believes its accrued amounts are adequate for probable loss.

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~~For ~~Note 7 for~~ a discussion of contingencies related to regulatory matters see Note 7 to the Consolidated Financial Statements, "Regulatory Matters".

NOTE 11 — RETIREMENT BENEFITS AND TRUSTEED ASSETS

The following table details the components of net periodic benefit costs for pension benefits and other postretirement benefits:

	Pension Benefits						Other Postretirement Benefits
	2014			2013			2014			2013
Three Months Ended June 30	(In millions)
Three Months Ended September 30,	(In millions)
Service cost	$	1714		$	1917		$	6		$	96
Interest cost	4041			3736			17			16
Expected return on plan assets	(4948		)	(4745		)	(21		)	(1918		)
Amortization of:
Net actuarial loss	2630			3639			53			12
Prior service cost (credit)	1—			—1			(2827		)	(2827		)
Net periodic benefit cost (credit)	$	3537		$	4548		$	(2122	)	$	(1011	)

DTE Electric Company

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

	Pension Benefits						Other Postretirement Benefits
	2014			2013			2014			2013
Six Months Ended June 30	(In millions)
Nine Months Ended September 30,	(In millions)
Service cost	$	3448		$	3855		$	1319		$	2127
Interest cost	80121			73109			3451			3450
Expected return on plan assets	(97145		)	(93138		)	(4263		)	(3755		)
Amortization of:
Net actuarial loss	5383			72111			811			2436
Prior service cost (credit)	1			—1			(5582		)	(4572		)
Net periodic benefit cost (credit)	$	71108		$	90138		$	(4264	)	$	(314	)

Pension and Other Postretirement Contributions

During the first ~~six~~nine months of 2014, the Company contributed $~~100~~145 million to its pension plans. ~~At the discretion of management, and depending upon financial market conditions, the Company may make up to an additional $45 million contribution to its pension plans in 2014.~~

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

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 ~~six~~nine months ended ~~June~~September 30, 2014 as compared to the comparable 2013 period are discussed below:

	Three Months Ended						~~Six~~Nine Months Ended
	June 30,						June 30,
	September 30,						September 30,
	2014			2013			2014			2013
	(In millions)
Operating revenues	$	1,281		$	1,265		$	2,691		$	2,484
Operating Revenues	$	1,357		$	1,457		$	4,048		$	3,941
Fuel and purchased power	~~400~~430			~~435~~487			~~898~~1,328			~~807~~1,294
Gross margin	~~881~~927			~~830~~970			12,~~793~~720			12,~~677~~647
Operation and maintenance	~~329~~351			~~343~~335			~~671~~1,022			~~674~~1,009
Depreciation and amortization	~~229~~238			~~221~~233			~~457~~695			~~433~~666
Taxes other than income	6566			6367			~~136~~202			~~133~~200
Asset (gains) losses and reserves, net	(1—		)	1(3		)	(1		)	—(3		)
Operating Income	~~259~~272			~~202~~338			~~530~~802			~~437~~775
Other (Income) and Deductions	5261			6561			~~109~~170			~~122~~183
Income Tax Expense	7775			4797			~~154~~229			~~109~~206
Net Income	$	~~130~~136		$	90180		$	~~267~~403		$	~~206~~386
Operating Income as a Percentage of Operating Revenues	20		%	1623		%	20		%	1820		%

Gross margin ~~increased~~decreased $51 43 million and increased $~~116~~73 million in the three and ~~six~~nine months ended ~~June~~September 30, 2014, respectively. Revenues associated with certain tracking mechanisms and surcharges are offset by related expenses elsewhere in the Consolidated Statements of Operations.

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

	Three Months			~~Six~~Nine Months
	(In millions)
Amortization of refundable revenue decoupling/deferred gain	$	32—		$	63
Base sales, inclusive of weather effect	10(51		)	26(24		)
Securitization bond and tax surcharge	—(2		)	86
Renewable energy program	65			1116
Low income energy assistance surcharge	64			1317
Regulatory mechanisms and other	(31		)	(5		)
Increase in gross margin	$	51		$	116
Increase (decrease) in gross margin	$	(43	)	$	73

	Three Months Ended		~~Six~~Nine Months Ended
	June 30,		June 30,
	September 30,		September 30,
	2014	2013	2014	2013
	(In thousands of MWh)
Electric Sales
Residential	3,~~452~~932	34,~~345~~401	711,~~430~~362	711,~~199~~600
Commercial	4,~~168~~541	4,~~158~~504	812,~~216~~757	812,~~081~~585
Industrial	2,~~554~~710	2,~~675~~635	57,~~055~~765	57,~~111~~746
Other	~~171~~62	~~216~~233	~~376~~438	~~468~~701
	10,345	10,394	21,077	20,859
	11,245	11,773	32,322	32,632
Interconnection sales (a)	~~479~~1,416	~~792~~711	12,~~097~~513	12,~~565~~276
Total Electric Sales	1012,~~824~~661	1112,~~186~~484	2234,~~174~~835	2234,~~424~~908
Electric Deliveries
Retail and Wholesale	1011,~~345~~245	1011,~~394~~773	2132,~~077~~322	2032,~~859~~632
Electric Customer Choice, including self generators (b)	1,~~237~~334	1,~~287~~393	23,~~504~~838	23,~~547~~940
Total Electric Sales and Deliveries	1112,~~582~~579	1113,~~681~~166	2336,~~581~~160	2336,~~406~~572

_______________________________________

(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.

Operation and maintenance expense ~~decreased~~increased $1416 million and $313 million in the three and ~~six~~nine months ended ~~June~~September 30, 2014, respectively. The ~~decrease~~increase in the ~~second~~third quarter was due primarily to ~~lower~~increased ~~employee~~storm ~~benefit~~restoration expenses of $2433 million ~~and $12 million of reinvestment expenses in 2013~~, partially offset by ~~higher~~decreased ~~storm~~employee ~~restoration~~benefit expenses of $914 million, ~~increased low income energy assistance of~~ $76 million ~~and~~of ~~higher~~decreased power plant generation expenses ~~for~~and ~~planned~~$4 ~~outages~~million of $5decreased ~~million~~distribution operations expenses. The ~~decrease~~increase in the ~~six~~nine-month period was primarily due to ~~lower~~increased ~~employee~~storm ~~benefit~~restoration expenses of $4637 million, ~~and~~increased power plant generation expenses for planned outages of $1221 million ofand ~~reinvestment~~increased ~~expenses~~low inincome ~~2013~~energy assistance of $17 million, partially offset by ~~higher~~decreased ~~power~~employee ~~plant~~benefit ~~generation~~ expenses of $3561 million and $7 million of decreased distribution operations expenses. In addition, ~~increased~~the ~~low~~2014 ~~income~~third ~~energy~~quarter ~~assistance~~and ofnine-month periods included $138 million of expenses related to the transition of PLD customers to DTE Electric’s distribution system effective July 1, ~~higher~~2014. In ~~storm~~May ~~restoration~~2014, ~~expenses~~the MPSC approved a TRM that provides for recovery of $4the ~~million~~deferred ~~and~~net ~~higher~~incremental ~~energy~~revenue ~~optimization~~requirement associated with the transition that is reflected in the Depreciation and ~~renewable~~amortization ~~energy~~line ~~expenses~~in ofthe $4Consolidated ~~million~~Statements of Operations.

Depreciation and amortization expense increased $8 5 million and $2429 million in the three and ~~six~~nine months ended ~~June~~September 30, 2014, respectively. The increase in the ~~second~~third quarter was due to ~~higher~~$9 ~~amortization~~million of ~~regulatory~~increased ~~assets~~expense ofdue $5to ~~million,~~an ~~primarily~~increased ~~related~~depreciable ~~to Securitization~~base, ~~and~~partially $3offset ~~million~~by ofdecreased ~~increased~~amortization ~~expense~~of ~~due~~regulatory toassets aof ~~higher~~$4 ~~depreciable base~~million. The increase in the ~~six~~nine-month period was due to ~~higher~~$20 ~~amortization~~million of ~~regulatory~~increased ~~assets~~expense ofdue ~~$16~~to ~~million,~~an ~~primarily~~increased ~~related~~depreciable tobase ~~Securitization,~~ and $89 million of increased ~~expense~~amortization ~~due~~of toregulatory aassets, ~~higher~~primarily ~~depreciable~~related ~~base~~to Securitization.

Other (~~income~~Income) and ~~deductions~~Deductions ~~were~~decreased ~~lower~~ by $13 million in ~~each of~~ the ~~three~~nine ~~and six~~ months ~~periods~~ ended ~~June~~September 30, 2014~~. The~~ ~~decrease in the second quarter was~~ due primarily to ~~lower~~decreased interest expense ~~and higher investment earnings, while the decrease in the six-month period was due primarily to lower interest expense~~.

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 capital investments 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 customer 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 May 2014, the Company filed an application with the NRC requesting a renewal of the license for its Fermi 2 nuclear power plant. The Company has requested a 20-year extension of its original license due to expire in 2025.

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 proposed performance standards for carbon dioxide emissions from existing, reconstructed and modified plants on June 2, 2014 and plans to issue a final standard by July 2015. DTE Electric is 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., since the Company has no plans to build new coal-fired generation. 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 credits 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 as authorized by the MPSC. Increased costs for energy produced from traditional coal-based sources could also increase the economic viability of energy produced from renewable, natural gas-fired generation and/or nuclear sources, from energy efficiency initiatives, and from the potential development of market-based trading of carbon offsets which could provide new business opportunities. A June 23, 2014 U.S. Supreme Court decision on the EPA’s authority to regulate greenhouse gas emissions under permitting programs of the Clean Air Act is expected to have little effect on DTE Electric since the Supreme Court's decision upholds the EPA’s authority to regulate GHGs at sources that are already subject to permitting due to emissions of conventional pollutants. In addition, the Supreme Court's ruling does not affect the EPA’s current proposed carbon performance standards at new or existing power plants. At the present time, it is not possible to quantify the financial impacts of these climate related legislative or regulatory initiatives on DTE Electric or its customers.

NEW ACCOUNTING PRONOUNCEMENTS

See Note 3 ofto the ~~Notes to~~ Consolidated Financial Statements, "New Accounting Pronouncements".

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 ~~June~~September 30, 2014, 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~~U.S. Securities and Exchange Commission'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 ~~June~~September 30, 2014 that have materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.

2627

Part II - Other Information

Item 1. Legal Proceedings

InFor ~~July~~more ~~2009,~~information ~~DTE~~on ~~Energy~~material ~~received~~legal aproceedings ~~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~~matters ~~permit requirements under the Clean Air Act. In June 2010, the EPA issued a NOV/FOV making similar allegations~~ related to aus ~~project~~ and ~~outage~~our ~~at Unit 2 of the Monroe Power Plant. In March 2013~~subsidiaries, ~~DTE~~see ~~Energy~~Notes ~~received~~7 aand ~~supplemental~~10 ~~NOV from the EPA relating~~ to the ~~July~~Consolidated ~~2009~~Financial ~~NOV/FOV. The~~Statements, ~~supplemental~~"Regulatory ~~NOV~~Matters" ~~alleged~~and ~~additional~~"Commitments ~~violations~~and ~~relating to the New Source Review provisions under the Clean Air Act, among other things~~Contingencies".

In August 2010, the U.S. Department of Justice, at the request of the EPA, brought a civil suit in the U.S. District Court for the Eastern District of Michigan against DTE Energy and DTE Electric, related to the June 2010 NOV/FOV and the outage work performed at Unit 2 of the Monroe Power Plant, but not relating to the July 2009 NOV/FOV. Among other relief, the EPA requested the court to require DTE Electric to install and operate the best available control technology at Unit 2 of the Monroe Power Plant. Further, the EPA requested the court to issue a preliminary injunction to require DTE Electric to (i) begin the process of obtaining the necessary permits for the Monroe Unit 2 modification and (ii) offset the pollution from Monroe Unit 2 through emissions reductions from DTE Electric's fleet of coal-fired power plants until the new control equipment is operating. On August 23, 2011, the U.S. District Court judge granted DTE Energy's motion for summary judgment in the civil case, dismissing the case and entering judgment in favor of DTE Energy and DTE Electric. On October 20, 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. On March 28, 2013, the Court of Appeals remanded the case to the U.S. District Court for review of the procedural component of the New Source Review notification requirements. On September 3, 2013, the EPA caused to be filed a motion seeking leave to amend their complaint regarding the June 2010 NOV/FOV adding additional claims related to outage work performed at the Trenton Channel and Belle River power plants as well as additional claims related to work performed at the Monroe Power Plant. In addition, the Sierra Club caused to be filed a motion to add a claim regarding the River Rouge Power Plant. On March 3, 2014, the U.S. District Court judge granted again DTE Energy's motion for summary judgment dismissing the civil case related to Monroe Unit 2. On April 3, 2014, the U.S. District Court judge granted motions filed by the EPA and the Sierra Club to amend their New Source Review complaint adding additional claims for Monroe Units 1, 2 and 3, Belle River Units 1 and 2, Trenton Channel Unit 9 and River Rouge Unit 3. On June 30, 2014, the EPA filed a motion requesting certification for appeal of the March 3, 2014 summary judgment decision.

In March 2013, the Sierra Club filed suit against DTE Energy and DTE Electric alleging violations of the Clean Air Act at four of DTE Electric's coal-fired power plants. The plaintiffs allege 1,499 6-minute periods of excess opacity of air emissions from 2007-2012 at those facilities. The suit asks that the court enjoin DTE Energy and DTE Electric from operating the power plants except in complete compliance with applicable laws and permit requirements, pay civil penalties, conduct beneficial environmental mitigation projects, pay attorney fees and require the installation of any necessary pollution controls or to convert and/or operate the plants' boilers on natural gas to avoid additional violations and to off-set historic unlawful emissions. In December 2013, a U.S. District Court judge issued an order dismissing, without prejudice, the plaintiff's complaint allowing them to file an amended complaint by January 17, 2014. The order dismissing the complaint resulted from a considerable number of plaintiff's claims being time barred based on the statute of limitations. On January 17, 2014, the plaintiffs filed an amended complaint for the period January 13, 2008 - June 30, 2012, reducing the total number of 6-minute periods from 1,499 to 1,139. DTE Energy and DTE Electric filed an answer to the amended complaint on March 11, 2014. The resolution of this matter is not expected to have a material effect on the Company's operations or financial statements.

For additional discussion on legal matters, see Notes 7 and 10 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 2013 Form 10-K. Although we have tried to identify and discuss key risk factors, others could emerge in the future.

Item 6. Exhibits

		(i) Exhibits filed herewith:
4-282		Supplemental Indenture, dated as of June 1, 2014, to the Mortgage and Deed of Trust dated as of October 1, 1924, between DTE Electric Company and The Bank of New York Mellon, N.A., as successor trustee. (2014 Series A and B)
12-51		Computation of Ratio of Earnings to Fixed Charges
4-283		Supplemental Indenture, dated as of July 1, 2014, to the Mortgage and Deed of Trust dated as of October 1, 1924, between DTE Electric Company and The Bank of New York Mellon, N.A., as successor trustee. (2014 Series D and E)
31-93		Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report
12-50		Computation of Ratio of Earnings to Fixed Charges
31-94		Chief Financial Officer Section 302 Form 10-Q Certification of Periodic Report
31-91		Chief Executive Officer Section 302 Form 10-Q Certification of Periodic Report
31-92		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:
32-91		Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report
32-93		Chief Executive Officer Section 906 Form 10-Q Certification of Periodic Report
32-92		Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report
32-94		Chief Financial Officer Section 906 Form 10-Q Certification of Periodic Report

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: July 25, 2014	By	/s/ DONNA M. ENGLAND
Date: October 24, 2014	By	/S/ DONNA M. ENGLAND
		Donna M. EnglandChief Accounting Officer(Principal Accounting Officer)

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