DTE ENERGY CO, 10-K filed on 2/13/2015
Annual Report
Document and Entity Information Document and Entity Information (USD $)
In Billions, except Share data, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Jan. 30, 2015
Jun. 30, 2014
Document and Entity Information [Abstract]
 
 
 
Entity Registrant Name
DTE ENERGY CO 
 
 
Entity Central Index Key
0000936340 
 
 
Current Fiscal Year End Date
--12-31 
 
 
Entity Filer Category
Large Accelerated Filer 
 
 
Document Type
10-K 
 
 
Document Period End Date
Dec. 31, 2014 
 
 
Document Fiscal Year Focus
2014 
 
 
Document Fiscal Period Focus
FY 
 
 
Amendment Flag
false 
 
 
Entity Common Stock, Shares Outstanding
 
177,229,483 
 
Entity Well-known Seasoned Issuer
Yes 
 
 
Entity Voluntary Filers
No 
 
 
Entity Current Reporting Status
Yes 
 
 
Entity Public Float
 
 
$ 13.3 
Consolidated Statements of Operations (USD $)
In Millions, except Per Share data, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Income Statement [Abstract]
 
 
 
Operating Revenues
$ 12,301 
$ 9,661 
$ 8,791 
Operating Expenses
 
 
 
Fuel, purchased power and gas
5,879 
4,055 
3,296 
Operation and maintenance
3,347 
2,978 
2,892 
Depreciation, depletion and amortization
1,145 
1,094 
995 
Taxes other than income
352 
340 
332 
Asset (gains) losses and impairments, net
(12)
(9)
(3)
Total operating expenses
10,711 
8,458 
7,512 
Operating Income
1,590 
1,203 
1,279 
Other (Income) and Deductions
 
 
 
Interest expense
429 
436 
440 
Interest income
(10)
(9)
(10)
Other income
(196)
(201)
(173)
Other expenses
92 
55 
62 
Total Other (Income) and Deductions
315 
281 
319 
Income Before Income Taxes
1,275 
922 
960 
Income Tax Expense
364 
254 
286 
Income from Continuing Operations
911 
668 
674 
Loss from Discontinued Operations, net of tax
0 
0 
(56)
Net Income
911 
668 
618 
Less: Net Income Attributable to Noncontrolling Interests
6 
7 
8 
Net Income Attributable to DTE Energy Company
$ 905 
$ 661 
$ 610 
Basic Earnings per Common Share
 
 
 
Income from continuing operations (in dollars per share)
$ 5.11 
$ 3.76 
$ 3.89 
Loss from discontinued operations, net of tax (in dollars per share)
$ 0 
$ 0 
$ (0.33)
Total (in dollars per share)
$ 5.11 
$ 3.76 
$ 3.56 
Diluted Earnings per Common Share
 
 
 
Income from continuing operations (in dollars per share)
$ 5.10 
$ 3.76 
$ 3.88 
Loss from discontinued operations, net of tax (in dollars per share)
$ 0 
$ 0 
$ (0.33)
Total (in dollars per share)
$ 5.10 
$ 3.76 
$ 3.55 
Weighted Average Common Shares Outstanding
 
 
 
Basic (in shares)
177 
175 
171 
Diluted (in shares)
177 
175 
172 
Dividends Declared per Common Share
$ 2.69 
$ 2.59 
$ 2.42 
Consolidated Statements of Comprehensive Income (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Statement of Comprehensive Income [Abstract]
 
 
 
Net Income
$ 911 
$ 668 
$ 618 
Other comprehensive income (loss), net of tax:
 
 
 
Benefit obligations, net of taxes of $(9), $13 and $(1), respectively
(18)
22 
(2)
Net unrealized gains on investments during the period, net of taxes of $1, $1 and $1, respectively
1 
2 
1 
Foreign currency translation, net of taxes of $(2), $(1) and $—, respectively
(2)
(2)
1 
Other comprehensive income
(19)
22 
0 
Comprehensive income
892 
690 
618 
Less comprehensive income attributable to noncontrolling interests
6 
7 
8 
Comprehensive income attributable to DTE Energy Company
$ 886 
$ 683 
$ 610 
Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Statement of Comprehensive Income [Abstract]
 
 
 
Tax effect on benefit obligation
$ (9)
$ 13 
$ (1)
Tax effect on net unrealized gains (losses) on investments during the period
1 
1 
1 
Tax effect on foreign currency translation
$ (2)
$ (1)
$ 0 
Consolidated Statements of Financial Position (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Current Assets
 
 
Cash and cash equivalents
$ 48 
$ 52 
Restricted cash, principally Securitization
120 
123 
Accounts receivable (less allowance for doubtful accounts of $54 and $55, respectively)
 
 
Customer
1,504 
1,542 
Other
94 
127 
Inventories
 
 
Fuel and gas
512 
363 
Materials and supplies
292 
265 
Derivative assets
128 
99 
Regulatory assets
76 
26 
Other
313 
209 
Total Current Assets
3,087 
2,806 
Investments
 
 
Nuclear decommissioning trust funds
1,241 
1,191 
Other
628 
603 
Total Investments
1,869 
1,794 
Property
 
 
Property, plant and equipment
26,538 
25,123 
Less accumulated depreciation, depletion and amortization
(9,718)
(9,323)
Property, plant and equipment, net
16,820 
15,800 
Other Assets
 
 
Goodwill
2,018 
2,018 
Regulatory assets
3,651 
2,837 
Securitized regulatory assets
34 
231 
Intangible assets
102 
122 
Notes receivable
90 
102 
Derivative assets
44 
27 
Other
259 
198 
Total Noncurrent Assets
6,198 
5,535 
Total Assets
27,974 
25,935 
Current Liabilities
 
 
Accounts payable
973 
962 
Accrued interest
86 
90 
Dividends payable
122 
116 
Short-term borrowings
398 
131 
Current portion long-term debt, including capital leases
274 
898 
Derivative liabilities
77 
195 
Regulatory liabilities
153 
302 
Other
494 
495 
Total Current Liabilities
2,577 
3,189 
Long-Term Debt (net of current portion)
 
 
Mortgage bonds, notes and other
7,860 
6,618 
Securitization bonds
0 
105 
Junior subordinated debentures
480 
480 
Capital lease obligations
3 
11 
Total Long-Term Debt (net of current portion)
8,343 
7,214 
Other Liabilities
 
 
Deferred income taxes
3,776 
3,321 
Regulatory liabilities
667 
862 
Asset retirement obligations
1,962 
1,827 
Unamortized investment tax credit
41 
47 
Derivative liabilities
8 
43 
Accrued pension liability
1,280 
653 
Accrued postretirement liability
515 
350 
Nuclear decommissioning
182 
178 
Other
281 
297 
Total Noncurrent Liabilities
8,712 
7,578 
Commitments and Contingencies (Notes 8 and 17)
   
   
Equity
 
 
Common stock, without par value, 400,000,000 shares authorized, 176,991,231 and 177,087,230 shares issued and outstanding, respectively
3,904 
3,907 
Retained earnings
4,578 
4,150 
Accumulated other comprehensive loss
(155)
(136)
Total DTE Energy Company Equity
8,327 
7,921 
Noncontrolling interests
15 
33 
Total Equity
8,342 
7,954 
Total Liabilities and Equity
$ 27,974 
$ 25,935 
Consolidated Statements of Financial Position (Parenthetical) (USD $)
In Millions, except Share data, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Current Assets:
 
 
Allowance for doubtful accounts
$ 54 
$ 55 
Stockholders' Equity:
 
 
Common stock, par value (in dollars per share)
$ 0 
$ 0 
Common stock, shares authorized (in shares)
400,000,000 
400,000,000 
Common stock, shares issued (in shares)
176,991,231 
177,087,230 
Common stock, shares outstanding (in shares)
176,991,231 
177,087,230 
Consolidated Statements of Cash Flows (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Operating Activities
 
 
 
Net Income
$ 911 
$ 668 
$ 618 
Adjustments to reconcile net income to net cash from operating activities:
 
 
 
Depreciation, depletion and amortization
1,145 
1,094 
1,018 
Nuclear fuel amortization
48 
38 
29 
Allowance for equity funds used during construction
(21)
(15)
(13)
Deferred income taxes
356 
164 
47 
Loss on sale of non-utility business
0 
0 
83 
Asset (gains) losses and impairments, net
(4)
(8)
1 
Changes in assets and liabilities:
 
 
 
Accounts receivable, net
48 
(154)
52 
Inventories
(177)
123 
35 
Accounts payable
128 
14 
40 
Accrued pension obligation
627 
(644)
280 
Accrued postretirement obligation
165 
(526)
(323)
Derivative assets and liabilities
(199)
107 
53 
Regulatory assets and liabilities
(1,177)
1,269 
278 
Other assets
(30)
(24)
55 
Other liabilities
19 
48 
(44)
Net cash from operating activities
1,839 
2,154 
2,209 
Investing Activities
 
 
 
Plant and equipment expenditures — utility
(1,784)
(1,534)
(1,451)
Plant and equipment expenditures — non-utility
(265)
(342)
(369)
Proceeds from sale of non-utility business
0 
0 
255 
Proceeds from sale of assets
45 
36 
38 
Acquisition, net of cash acquired
0 
0 
(198)
Proceeds from sale of nuclear decommissioning trust fund assets
1,146 
1,118 
759 
Investment in nuclear decommissioning trust funds
(1,156)
(1,134)
(764)
Other
(46)
(50)
(39)
Net cash used for investing activities
(2,060)
(1,906)
(1,769)
Financing Activities
 
 
 
Issuance of long-term debt, net of issuance costs
1,736 
1,234 
759 
Redemption of long-term debt
(1,237)
(961)
(639)
Short-term borrowings, net
267 
(109)
(179)
Issuance of common stock
0 
39 
39 
Repurchase of common stock
(52)
0 
0 
Dividends on common stock
(470)
(445)
(407)
Other
(27)
(19)
(16)
Net cash from (used for) financing activities
217 
(261)
(443)
Net Decrease in Cash and Cash Equivalents
(4)
(13)
(3)
Cash and Cash Equivalents at Beginning of Period
52 
65 
68 
Cash and Cash Equivalents at End of Period
48 
52 
65 
Supplemental disclosure of cash information
 
 
 
Cash paid (received) for: Interest (net of interest capitalized)
415 
418 
438 
Cash paid (received) for: Income taxes
(35)
121 
173 
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
 
 
 
Plant and equipment expenditures in accounts payable
$ 212 
$ 329 
$ 235 
Consolidated Statements of Changes in Equity (USD $)
In Millions, except Share data, unless otherwise specified
Total
Common Stock [Member]
Retained Earnings [Member]
Accumulated Other Comprehensive Loss [Member]
Non-Controlling Interest [Member]
Beginning Balance at Dec. 31, 2011
$ 7,053 
$ 3,417 
$ 3,750 
$ (158)
$ 44 
Beginning Balance (in shares) at Dec. 31, 2011
 
169,247,000 
 
 
 
Increase (Decrease) in Stockholders' Equity [Roll Forward]
 
 
 
 
 
Net Income
618 
 
610 
 
8 
Dividends declared on common stock
(414)
 
(414)
 
 
Issuance of common stock (in shares)
 
684,000 
 
 
 
Issuance of common stock
39 
39 
 
 
 
Contribution of common stock to pension plan (in shares)
 
1,335,000 
 
 
 
Contribution of common stock to pension plan
80 
80 
 
 
 
Benefit obligations, net of tax
(2)
 
 
(2)
 
Net change in unrealized losses on investments, net of tax
1 
 
 
1 
 
Foreign currency translation, net of tax
1 
 
 
1 
 
Stock-based compensation, distributions to noncontrolling interests and other (in shares)
 
1,086,000 
 
 
 
Stock-based compensation, distributions to noncontrolling interests and other
35 
51 
(2)
 
(14)
Ending Balance at Dec. 31, 2012
7,411 
3,587 
3,944 
(158)
38 
Ending Balance (in shares) at Dec. 31, 2012
 
172,352,000 
 
 
 
Increase (Decrease) in Stockholders' Equity [Roll Forward]
 
 
 
 
 
Net Income
668 
 
661 
 
7 
Dividends declared on common stock
(454)
 
(454)
 
 
Issuance of common stock (in shares)
 
589,000 
 
 
 
Issuance of common stock
39 
39 
 
 
 
Contribution of common stock to pension plan (in shares)
 
3,026,000 
 
 
 
Contribution of common stock to pension plan
200 
200 
 
 
 
Benefit obligations, net of tax
22 
 
 
22 
 
Net change in unrealized losses on investments, net of tax
2 
 
 
2 
 
Foreign currency translation, net of tax
(2)
 
 
(2)
 
Stock-based compensation, distributions to noncontrolling interests and other (in shares)
 
1,120,000 
 
 
 
Stock-based compensation, distributions to noncontrolling interests and other
68 
81 
(1)
 
(12)
Ending Balance at Dec. 31, 2013
7,954 
3,907 
4,150 
(136)
33 
Ending Balance (in shares) at Dec. 31, 2013
177,087,230 
177,087,000 
 
 
 
Increase (Decrease) in Stockholders' Equity [Roll Forward]
 
 
 
 
 
Net Income
911 
 
905 
 
6 
Dividends declared on common stock
(476)
 
(476)
 
 
Repurchase of common stock (in shares)
 
(713,000)
 
 
 
Repurchase of common stock
(52)
(52)
 
 
 
Benefit obligations, net of tax
(18)
 
 
(18)
 
Net change in unrealized losses on investments, net of tax
1 
 
 
1 
 
Foreign currency translation, net of tax
(2)
 
 
(2)
 
Stock-based compensation, distributions to noncontrolling interests and other (in shares)
 
617,000 
 
 
 
Stock-based compensation, distributions to noncontrolling interests and other
24 
49 
(1)
 
(24)
Ending Balance at Dec. 31, 2014
$ 8,342 
$ 3,904 
$ 4,578 
$ (155)
$ 15 
Ending Balance (in shares) at Dec. 31, 2014
176,991,231 
176,991,000 
 
 
 
Organization and Basis of Presentation (Notes)
Organization and Basis of Presentation
ORGANIZATION AND BASIS OF PRESENTATION
Corporate Structure
DTE Energy owns the following businesses:

•
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 Gas is a natural gas utility engaged in the purchase, storage, transportation, distribution and sale of natural gas to approximately 1.2 million customers throughout Michigan and the sale of storage and transportation capacity; and

•
Other businesses involved in 1) natural gas pipelines, gathering and storage; 2) power and industrial projects; and 3) energy marketing and trading operations.
DTE Electric and DTE Gas are regulated by the MPSC. Certain activities of DTE Electric and DTE Gas, as well as various other aspects of businesses under DTE Energy are regulated by the FERC. In addition, the Company is regulated by other federal and state regulatory agencies including the NRC, the EPA, the MDEQ and the CFTC.
References in this Report to “we”, “us”, “our”, “Company” or “DTE” are to DTE Energy and its subsidiaries, collectively.
Basis of Presentation
The accompanying Consolidated Financial Statements are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Company’s estimates.
Principles of Consolidation
The Company consolidates all majority-owned subsidiaries and investments in entities in which it has controlling influence. Non-majority owned investments are accounted for using the equity method when the Company is able to influence the operating policies of the investee. When the Company does not influence the operating policies of an investee, the cost method is used. These Consolidated Financial Statements also reflect the Company's proportionate interests in certain jointly owned utility plants. The Company eliminates all intercompany balances and transactions.
The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, the Company considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.
Legal entities within the Company's Power and Industrial Projects segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with the Company retaining operational and customer default risk. These entities generally are VIEs and consolidated when the Company is the primary beneficiary. In addition, we have interests in certain VIEs through which we share control of all significant activities for those entities with our partners, and therefore are accounted for under the equity method.
The Company has variable interests in VIEs through certain of its long-term purchase and sale contracts. As of December 31, 2014, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominately related to working capital accounts and generally represent the amounts owed by or to 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 and sale contracts.
In 2001, DTE Electric financed a regulatory asset related to Fermi 2 and certain other regulatory assets through the sale of rate reduction bonds by a wholly-owned special purpose entity, Securitization. DTE Electric performs servicing activities including billing and collecting surcharge revenue for Securitization. This entity is a VIE and is consolidated by the Company.
The maximum risk exposure for consolidated VIEs is reflected on the Company's Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment and amounts which it has guaranteed.
The following table summarizes the major balance sheet items for consolidated VIEs as of December 31, 2014 and 2013. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. VIEs, in which the Company holds a majority voting interest and is the primary beneficiary, that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIE's obligations have been excluded from the table below.
 
December 31, 2014
 
December 31, 2013
 
Securitization
 
Other
 
Total
 
Securitization
 
Other
 
Total
 
(In millions)
ASSETS
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$
—

 
$
7

 
$
7

 
$
—

 
$
12

 
$
12

Restricted cash
96

 
8

 
104

 
100

 
8

 
108

Accounts receivable
26

 
15

 
41

 
34

 
16

 
50

Inventories
—

 
67

 
67

 
—

 
118

 
118

Property, plant and equipment, net
—

 
81

 
81

 
—

 
99

 
99

Securitized regulatory assets
34

 
—

 
34

 
231

 
—

 
231

Other current and long-term assets
1

 
6

 
7

 
4

 
9

 
13

 
$
157

 
$
184

 
$
341

 
$
369

 
$
262

 
$
631

LIABILITIES
 
 
 
 
 
 
 
 
 
 
 
Accounts payable and accrued current liabilities
$
3

 
$
8

 
$
11

 
$
7

 
$
23

 
$
30

Current portion long-term debt, including capital leases
105

 
10

 
115

 
196

 
9

 
205

Current regulatory liabilities
32

 
—

 
32

 
43

 
—

 
43

Mortgage bonds, notes and other
—

 
15

 
15

 
—

 
21

 
21

Securitization bonds
—

 
—

 
—

 
105

 
—

 
105

Capital lease obligations
—

 
3

 
3

 
—

 
7

 
7

Other current and long-term liabilities
9

 
6

 
15

 
8

 
6

 
14

 
$
149

 
$
42

 
$
191

 
$
359

 
$
66

 
$
425


Amounts for non-consolidated VIEs as of December 31, 2014 and 2013 are as follows:
 
December 31, 2014
 
December 31, 2013
 
(In millions)
Other investments
$
134

 
$
141

Notes receivable
$
15

 
$
8

Significant Accounting Policies (Notes)
Significant Accounting Policies
SIGNIFICANT ACCOUNTING POLICIES
Revenues
Revenues from the sale and delivery of electricity, and the sale, delivery and storage of natural gas are recognized as services are provided. DTE Electric and DTE Gas record revenues for electricity and gas provided but unbilled at the end of each month. Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are recorded on the Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.
For further discussion of recovery mechanisms authorized by the MPSC see Note 8 to the Consolidated Financial Statements, "Regulatory Matters".
Non-utility businesses recognize revenues as services are provided and products are delivered. For discussion of derivative contracts see Note 12 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments".
Other Income
Other income is recognized for non-operating income such as equity earnings, allowance for equity funds used during construction and contract services. Power & Industrial Projects also recognizes Other income in connection with the sale of membership interests in reduced emissions fuel facilities to investors. In exchange for the cash received, the investors will receive a portion of the economic attributes of the facilities, including income tax attributes. The transactions are not treated as a sale of membership interests for financial reporting purposes. Other income is considered earned when refined coal is produced and tax credits are generated. Power & Industrial Projects recognized approximately $78 million, $81 million and $63 million of Other income for the years ended December 31, 2014, 2013 and 2012, respectively.
Accounting for ISO Transactions
DTE Electric participates in the energy market through MISO. MISO requires that we submit hourly day-ahead, real- time and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time and FTR markets and net transactions across all MISO energy market locations. In any single hour DTE Electric records net purchases in Fuel, purchased power and gas and net sales in Operating revenues on the Consolidated Statements of Operations.
Energy Trading participates in the energy markets through various independent system operators and regional transmission organizations (ISOs and RTOs). These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the regional transmission organizations. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time and FTR markets. These transactions are related to trading contracts which are presented on a net basis in Operating Revenues in the Consolidated Statements of Operations.
DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience, and reconcile accruals to actual costs when invoices are received from MISO, and other ISOs and RTOs.
Changes in Accumulated Other Comprehensive Loss
Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. The amounts recorded to accumulated other comprehensive loss include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities and the Company’s interest in other comprehensive income of equity investees, which comprise the net unrealized gains and losses on investments, changes in benefit obligations, consisting of deferred actuarial losses, prior service costs, and foreign currency translation adjustments.
The following table summarizes the changes in Accumulated other comprehensive loss by component for the years ended December 31, 2014 and 2013:
 
Changes in Accumulated Other Comprehensive Loss by Component (a)
 
Net
Unrealized
Gain/(Loss)
on Derivatives
 
Net
Unrealized
Gain/(Loss)
on Investments
 
Benefit
Obligations
(b)
 
Foreign
Currency
Translation
 
Total
 
(In millions)
Balance, January 1, 2013
$
(4
)
 
$
(8
)
 
$
(148
)
 
$
2

 
$
(158
)
Other comprehensive income (loss) before reclassifications
—

 
2

 
13

 
(2
)
 
13

Amounts reclassified from accumulated other comprehensive income
—

 
—

 
9

 
—

 
9

Net current-period other comprehensive income (loss)
—

 
2


22


(2
)

22

Balance, December 31, 2013
$
(4
)
 
$
(6
)

$
(126
)

$
—


$
(136
)
Other comprehensive income (loss) before reclassifications
—

 
1

 
(25
)
 
(2
)
 
(26
)
Amounts reclassified from accumulated other comprehensive income
—

 
—

 
7

 
—

 
7

Net current-period other comprehensive income (loss)
—

 
1


(18
)

(2
)

(19
)
Balance, December 31, 2014
$
(4
)
 
$
(5
)

$
(144
)

$
(2
)

$
(155
)
______________________________________
(a)All amounts are net of tax.
(b)
The amounts reclassified from accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 18 to the Consolidated Financial Statements "Retirement Benefits and Trusteed Assets").
Cash, Cash Equivalents and Restricted Cash
Cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt, primarily Securitization bonds, and partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a current asset.
Receivables
Accounts receivable are primarily composed of trade receivables and unbilled revenue. Our accounts receivable are stated at net realizable value.
The allowance for doubtful accounts for DTE Electric and DTE Gas is generally calculated using the aging approach that utilizes rates developed in reserve studies. We establish an allowance for uncollectible accounts based on historical losses and management’s assessment of existing economic conditions, customer trends, and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. We assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated.
The customer allowance for doubtful accounts for our other businesses is calculated based on specific review of probable future collections based on receivable balances in excess of 30 days.
Unbilled revenues of $773 million and $815 million are included in customer accounts receivable at December 31, 2014 and 2013, respectively.
Notes Receivable
Notes receivable, or financing receivables, are primarily comprised of capital lease receivables and loans and are included in Notes receivable and Other current assets on the Company’s Consolidated Statements of Financial Position.
Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Company ceases accruing interest (nonaccrual status), considers a note receivable impaired, and establishes an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected in accordance with the contractual terms of the note receivable. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current.
In determining the allowance for credit losses for notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty’s ability to pay. In addition, the Company monitors the credit ratings of the counterparties from which we have notes receivable.
Inventories
The Company generally values inventory at average cost.
Natural gas inventory of $43 million and $4 million as of December 31, 2014 and 2013, respectively, at DTE Gas is determined using the last-in, first-out (LIFO) method. At December 31, 2014, the replacement cost of gas remaining in storage exceeded the LIFO cost by $110 million. At December 31, 2013, the replacement cost of gas remaining in storage exceeded the LIFO cost by $170 million.
Property, Retirement and Maintenance, and Depreciation, Depletion and Amortization
Property is stated at cost and includes construction-related labor, materials, overheads and AFUDC for utility property. The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred, except for Fermi 2.
Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC.
Non-utility property is depreciated over its estimated useful life using the straight-line and units of production methods.
Depreciation, depletion and amortization expense also includes the amortization of certain regulatory assets.
Approximately $16 million and $26 million of expenses related to Fermi 2 refueling outages were accrued at December 31, 2014 and 2013, respectively. Amounts are accrued on a pro-rata basis, generally over an 18-month period, that coincides with scheduled refueling outages at Fermi 2. This accrual of outage costs matches the regulatory recovery of these costs in rates set by the MPSC. See Note 8 to the Consolidated Financial Statements, "Regulatory Matters".
The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas in the Consolidated Statements of Operations and is recorded using the units-of-production method.
Long-Lived Assets
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected discounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
Intangible Assets
The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below:
 
December 31, 2014
 
December 31, 2013
 
(In millions)
Emission allowances
$
1

 
$
2

Renewable energy credits
45

 
51

Contract intangible assets
122

 
126

 
168

 
179

Less accumulated amortization
57

 
45

Intangible assets, net
111

 
134

Less current intangible assets
9

 
12

 
$
102

 
$
122


Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business. The Company amortizes contract intangible assets on a straight-line basis over the expected period of benefit, ranging from 1 to 27 years. Intangible assets amortization expense was $12 million in 2014, $14 million in 2013 and $6 million in 2012.
The following table summarizes the estimated amortization expense expected to be recognized during each year through 2019:
Estimated amortization expense
(In millions)
2015
$
12

2016
$
11

2017
$
8

2018
$
8

2019
$
6


Excise and Sales Taxes
The Company records the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Consolidated Statements of Operations.
Deferred Debt Costs
The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. In accordance with MPSC regulations applicable to the Company’s electric and gas utilities, the unamortized discount, premium and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium and expense on early redemptions of debt associated with non-utility operations are charged to earnings.
Investments in Debt and Equity Securities
The Company generally classifies investments in debt and equity securities as either trading or available-for-sale and has recorded such investments at market value with unrealized gains or losses included in earnings or in other comprehensive income or loss, respectively. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to regulatory assets or liabilities, due to a recovery mechanism from customers. The Company’s equity investments are reviewed for impairment each reporting period. If the assessment indicates that the impairment is other than temporary, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 11 of the Consolidated Financial Statements, "Fair Value".
Government Grants
Grants are recognized when there is reasonable assurance that the grant will be received and that any conditions associated with the grant will be met. When grants are received related to Property, plant and equipment, the Company reduces the cost of the assets on the Consolidated Statements of Financial Position, resulting in lower depreciation expense over the life of the associated asset. Grants received related to expenses are reflected as a reduction of the associated expense in the period in which the expense is incurred.
DTE Energy Foundation
Charitable contributions to the DTE Energy Foundation were $25 million, $18 million and $21 million for the years ended December 31, 2014, 2013 and 2012, respectively. The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations.
Other Accounting Policies
See the following notes for other accounting policies impacting the Company’s Consolidated Financial Statements:
Note
 
Title
7
 
Asset Retirement Obligations
8
 
Regulatory Matters
9
 
Income Taxes
11
 
Fair Value
12
 
Financial and Other Derivative Instruments
19
 
Stock-Based Compensation
Accounting Pronouncements (Notes)
New Accounting Pronouncements
NEW ACCOUNTING PRONOUNCEMENTS
In May 2014, the 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 Financial Statements.
Discontinued Operations (Notes)
Discontinued Operations
DISCONTINUED OPERATIONS
Sale of Unconventional Gas Production Business
In December 2012, the Company sold its 100% equity interest in its Unconventional Gas Production business which consisted of gas and oil production assets in the western Barnett and Marble Falls shale areas of Texas. The sale resulted in gross proceeds of approximately $255 million, which resulted in a pre-tax loss of approximately $83 million ($55 million after tax). The activity of the discontinued business is shown below. The amounts exclude general corporate overhead costs, and related tax effects, and no portion of corporate interest costs were allocated to discontinued operations.
 
2012
 
(In millions)
Operating Revenues
$
55

 
 
Operation and maintenance
24

Depreciation, depletion and amortization
23

Taxes other than income
4

Asset (gains) losses, net
83

 
134

Operating Loss
(79
)
Other (Income) and Deductions
6

Loss Before Income Taxes
(85
)
Income Tax Benefit
(29
)
Net Loss Attributable to DTE Energy Company
$
(56
)
Property, Plant and Equipment (Notes)
Property, Plant and Equipment
PROPERTY, PLANT AND EQUIPMENT
Summary of property by classification as of December 31:
 
2014
 
2013
 
(In millions)
Property, Plant and Equipment
 
 
 
DTE Electric
 
 
 
Generation
$
11,641

 
$
11,127

Distribution
8,164

 
7,603

Total DTE Electric
19,805

 
18,730

DTE Gas
 
 
 
Distribution
2,946

 
2,834

Storage
448

 
431

Other
863

 
836

Total DTE Gas
4,257

 
4,101

Non-utility and other
2,476

 
2,292

Total
26,538

 
25,123

Less Accumulated Depreciation, Depletion and Amortization
 
 
 
DTE Electric
 
 
 
Generation
(4,149
)
 
(4,004
)
Distribution
(3,067
)
 
(2,947
)
Total DTE Electric
(7,216
)
 
(6,951
)
DTE Gas
 
 
 
Distribution
(1,130
)
 
(1,129
)
Storage
(142
)
 
(138
)
Other
(363
)
 
(338
)
Total DTE Gas
(1,635
)
 
(1,605
)
Non-utility and other
(867
)
 
(767
)
Total
(9,718
)
 
(9,323
)
Net Property, Plant and Equipment
$
16,820

 
$
15,800


AFUDC and interest capitalized was approximately $37 million and $33 million for the years ended December 31, 2014 and 2013, respectively.

The composite depreciation rate for DTE Electric was approximately 3.4% in 2014 and 2013 and 3.3% in 2012. The composite depreciation rate for DTE Gas was 2.4% in 2014, 2013 and 2012. The average estimated useful life for each major class of utility property, plant and equipment as of December 31, 2014 follows:
 
 
Estimated Useful Lives in Years
Utility
 
Generation
 
Distribution
 
Storage
Electric
 
40
 
41
 
N/A
Gas
 
N/A
 
50
 
53
The estimated useful lives for major classes of non-utility assets and facilities range from 3 to 55 years.
Capitalized software costs are classified as Property, plant and equipment and the related amortization is included in Accumulated depreciation, depletion and amortization on the Consolidated Statements of Financial Position. The Company capitalizes the costs associated with computer software it develops or obtains for use in its business. The Company amortizes capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years.
Capitalized software costs amortization expense was $77 million in 2014, $71 million in 2013 and $68 million in 2012. The gross carrying amount and accumulated amortization of capitalized software costs at December 31, 2014 were $668 million and $335 million, respectively. The gross carrying amount and accumulated amortization of capitalized software costs at December 31, 2013 were $611 million and $323 million, respectively.
Gross property under capital leases was $35 million at December 31, 2014 and 2013. Accumulated amortization of property under capital leases was $27 million and $21 million at December 31, 2014 and 2013, respectively.
Jointly Owned Utility Plant (Notes)
Jointly Owned Utility Plant
JOINTLY OWNED UTILITY PLANT
DTE Electric has joint ownership interest in two power plants, Belle River and Ludington Hydroelectric Pumped Storage. DTE Electric’s share of direct expenses of the jointly owned plants are included in Fuel, purchased power and gas and Operation and maintenance expenses in the Consolidated Statements of Operations. Ownership information of the two utility plants as of December 31, 2014 was as follows:
 
Belle River
 
Ludington
Hydroelectric
Pumped Storage
In-service date
1984-1985

 
1973

Total plant capacity
1,270
 MW
 
1,872
 MW
Ownership interest
(a)

 
49
%
Investment in property, plant and equipment (in millions)
$
1,742

 
$
412

Accumulated depreciation (in millions)
$
993

 
$
175


_______________________________________
(a)
DTE Electric's ownership interest is 63% in Unit No. 1, 81% of the facilities applicable to Belle River used jointly by the Belle River and St. Clair Power Plants and 75% in common facilities used at Unit No. 2.
Belle River
The Michigan Public Power Agency (MPPA) has an ownership interest in Belle River Unit No. 1 and other related facilities. The MPPA is entitled to 19% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance and capital improvement costs.
Ludington Hydroelectric Pumped Storage
Consumers Energy Company has an ownership interest in the Ludington Hydroelectric Pumped Storage Plant. Consumers Energy is entitled to 51% of the total capacity and energy of the plant and is responsible for the same percentage of the plant’s operation, maintenance and capital improvement costs.
Asset Retirement Obligations (Notes)
Asset Retirement Obligations
ASSET RETIREMENT OBLIGATIONS
The Company has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property and various other operations. The Company has conditional retirement obligations for gas pipelines, asbestos and PCB removal at certain of its power plants and various distribution equipment. The Company recognizes such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at our credit-adjusted risk-free rate. In its regulated operations, the Company recognizes regulatory assets or liabilities for timing differences in expense recognition for legal asset retirement costs that are currently recovered in rates.
If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets.
A reconciliation of the asset retirement obligations for 2014 follows:
 
(In millions)
Asset retirement obligations at December 31, 2013
$
1,827

Accretion
112

Liabilities incurred
11

Liabilities settled
(12
)
Revision in estimated cash flows
24

Asset retirement obligations at December 31, 2014
$
1,962


Approximately $1.7 billion of the asset retirement obligations represent nuclear decommissioning liabilities that are funded through a surcharge to electric customers over the life of the Fermi 2 nuclear plant. The NRC has jurisdiction over the decommissioning of nuclear power plants and requires minimum decommissioning funding based upon a formula. The MPSC and FERC regulate the recovery of costs of decommissioning nuclear power plants and both require the use of external trust funds to finance the decommissioning of Fermi 2. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates. The Company believes the MPSC and FERC collections will be adequate to fund the estimated cost of decommissioning. The decommissioning assets, anticipated earnings thereon and future revenues from decommissioning collections will be used to decommission Fermi 2. The Company expects the liabilities to be reduced to zero at the conclusion of the decommissioning activities. If amounts remain in the trust funds for Fermi 2 following the completion of the decommissioning activities, those amounts will be disbursed based on rulings by the MPSC and FERC.
A portion of the funds recovered through the Fermi 2 decommissioning surcharge and deposited in external trust accounts is designated for the removal of non-radioactive assets and returning the site to greenfield. This removal and greenfielding is not considered a legal liability. Therefore, it is not included in the asset retirement obligation, but is reflected as the Nuclear decommissioning liability. The decommissioning of Fermi 1 is funded by DTE Electric. Contributions to the Fermi 1 trust are discretionary. For additional discussion of Nuclear decommissioning trust fund assets see Note 11 to the Consolidated Financial Statements, "Fair Value".
Regulatory Matters (Notes)
Regulatory Matters
REGULATORY MATTERS
Regulation
DTE Electric and DTE Gas are subject to the regulatory jurisdiction of the MPSC, which issues orders pertaining to rates, recovery of certain costs, including the costs of generating facilities and regulatory assets, conditions of service, accounting and operating-related matters. DTE Electric is also regulated by the FERC with respect to financing authorization and wholesale electric activities. Regulation results in differences in the application of generally accepted accounting principles between regulated and non-regulated businesses.
The Company is unable to predict the outcome of the unresolved regulatory matters discussed herein. Resolution of these matters is dependent upon future MPSC orders and appeals, which may materially impact the financial position, results of operations and cash flows of the Company.
Regulatory Assets and Liabilities
DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of our businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
The following are balances and a brief description of the regulatory assets and liabilities at December 31:
 
2014
 
2013
 
(In millions)
Assets
 
 
 
Recoverable pension and other postretirement costs:
 
 
 
Pension
$
2,284

 
$
1,660

Other postretirement costs
234

 
—

Asset retirement obligation
448

 
394

Recoverable Michigan income taxes
267

 
286

Unamortized loss on reacquired debt
67

 
63

Other recoverable income taxes
66

 
71

Accrued PSCR/GCR revenue
61

 
—

Deferred environmental costs
59

 
59

Cost to achieve Performance Excellence Process
54

 
75

Recoverable income taxes related to securitized regulatory assets
19

 
126

Removal costs asset
15

 
—

Transitional Reconciliation Mechanism
14

 
—

Other
139

 
129

 
3,727

 
2,863

Less amount included in current assets
(76
)
 
(26
)
 
$
3,651

 
$
2,837

 
 
 
 
Securitized regulatory assets
$
34

 
$
231

Liabilities
 
 
 
Removal costs liability
$
308

 
$
351

Renewable energy
227

 
277

Over recovery of Securitization
71

 
72

Refundable revenue decoupling/deferred gain
67

 
127

Negative pension offset
67

 
84

Refundable income taxes
33

 
45

Energy optimization
24

 
31

Fermi 2 refueling outage
16

 
26

Refundable other postretirement costs
—

 
72

Accrued PSCR/GCR refund
—

 
65

Other
7

 
14

 
$
820

 
$
1,164

Less amount included current liabilities
(153
)
 
(302
)
 
$
667

 
$
862


As noted below, certain regulatory assets for which costs have been incurred have been included (or are expected to be included, for costs incurred subsequent to the most recently approved rate case) in DTE Electric's or DTE Gas’s rate base, thereby providing a return on invested costs (except as noted). Certain other regulatory assets are not included in rate base but accrue recoverable carrying charges until surcharges to collect the assets are billed. Certain regulatory assets do not result from cash expenditures and therefore do not represent investments included in rate base or have offsetting liabilities that reduce rate base.
ASSETS
•
Recoverable pension and other postretirement costs — Accounting rules for pension and other postretirement benefit costs require, among other things, the recognition in other comprehensive income of the actuarial gains or losses and the prior service costs that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the impact of actuarial gains or losses and prior service costs as a regulatory asset since the traditional rate setting process allows for the recovery of pension and other postretirement costs. The asset will reverse as the deferred items are amortized and recognized as components of net periodic benefit costs. (a)
•
Asset retirement obligation — This obligation is primarily for Fermi 2 decommissioning costs. The asset captures the timing differences between expense recognition and current recovery in rates and will reverse over the remaining life of the related plant. (a)
•
Recoverable Michigan income taxes — In July 2007, the MBT was enacted by the State of Michigan. State deferred tax liabilities were established for the Company’s utilities, and offsetting regulatory assets were recorded as the impacts of the deferred tax liabilities will be reflected in rates as the related taxable temporary differences reverse and flow through current income tax expense. In May 2011, the MBT was repealed and the MCIT was enacted. The regulatory asset was remeasured to reflect the impact of the MCIT tax rate. (a)
•
Unamortized loss on reacquired debt — The unamortized discount, premium and expense related to debt redeemed with a refinancing are deferred, amortized and recovered over the life of the replacement issue.
•
Other recoverable income taxes — Income taxes receivable from DTE Electric’s customers representing the difference in property-related deferred income taxes and amounts previously reflected in DTE Electric’s rates. This asset will reverse over the remaining life of the related plant. (a)
•
Accrued PSCR/GCR revenue — Receivable for the temporary under-recovery of and carrying costs on fuel and purchased power costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary under-recovery of and carrying costs on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.
•
Deferred environmental costs — The MPSC approved the deferral of investigation and remediation costs associated with DTE Gas's former MGP sites. Amortization of deferred costs is over a ten-year period beginning in the year after costs were incurred, with recovery (net of any insurance proceeds) through base rate filings. (a)
•
Cost to achieve Performance Excellence Process (PEP) — The MPSC authorized the deferral of costs to implement the PEP. These costs consist of employee severance, project management and consultant support. These costs are amortized over a ten-year period beginning with the year subsequent to the year the costs were deferred.
•
Recoverable income taxes related to securitized regulatory assets — Receivable for the recovery of income taxes to be paid on the non-bypassable securitization bond surcharge. A non-bypassable securitization tax surcharge, which ended in December 2014, was in place to recover the income tax over a fourteen-year period. (a)
•
Removal costs asset — Receivable for the recovery of asset removal expenditures in excess of amounts collected from customers.
•
Transitional Reconciliation Mechanism (TRM) — The MPSC approved the recovery of the deferred net incremental revenue requirement associated with the transition of PLD customers to DTE Electric's distribution system, effective July 1, 2014. Annual reconciliations will be filed and surcharges will be implemented to recover approved amounts. (a)
•
Securitized regulatory assets — The net book balance of the Fermi 2 nuclear plant was written off in 1998 and an equivalent regulatory asset was established. In 2001, the Fermi 2 regulatory asset and certain other regulatory assets were securitized pursuant to PA 142 and an MPSC order. A non-bypassable securitization bond surcharge, which ended in December 2014, was in place to recover the securitized regulatory asset over a fourteen-year period.
_________________________________
(a)
Regulatory assets not earning a return or accruing carrying charges.
LIABILITIES
•
Removal costs liability — The amount collected from customers for the funding of future asset removal activities.
•
Renewable energy — Amounts collected in rates in excess of renewable energy expenditures.
•
Over recovery of Securitization — Over recovery of securitization bond expenses.
•
Refundable revenue decoupling / deferred gain — Amounts were originally accrued as refundable to DTE Electric customers for the change in revenue resulting from the difference between actual average sales per customer compared to the base level of average sales per customer established by the MPSC. In 2012, the MCOA issued a decision reversing the MPSC's decision to authorize a RDM for DTE Electric. The revenue decoupling liability was reversed and, after receiving an order from the MPSC to defer the resulting gain for future amortization, DTE Electric created a regulatory liability representing its obligation to refund the gain. The deferred gain is being amortized into earnings in 2014 and 2015.
•
Negative pension offset — DTE Gas's negative pension costs are not included as a reduction to its authorized rates; therefore, the Company is accruing a regulatory liability to eliminate the impact on earnings of the negative pension expense accrued. This regulatory liability will reverse to the extent DTE Gas’s pension expense is positive in future years.
•
Refundable income taxes — Income taxes refundable to DTE Gas’s customers representing the difference in property-related deferred income taxes payable and amounts recognized pursuant to MPSC authorization.
•
Energy optimization (EO) — Amounts collected in rates in excess of energy optimization expenditures.
•
Fermi 2 refueling outage — Accrued liability for refueling outage at Fermi 2 pursuant to MPSC authorization.
•
Refundable other postretirement costs — Accounting rules for other postretirement benefit costs require, among other things, the recognition in other comprehensive income of the actuarial gains or losses and the prior service costs or credits that arise during the period but that are not immediately recognized as components of net periodic benefit costs. DTE Electric and DTE Gas record the favorable impact of actuarial gains or losses and prior service credits as a regulatory liability since the impact will reduce expense in a future rate setting process as the deferred items are recognized as a component of net periodic benefit costs.
•
Accrued PSCR/GCR refund — Liability for the temporary over-recovery of and a return on power supply costs and transmission costs incurred by DTE Electric which are recoverable through the PSCR mechanism and temporary over-recovery of and a return on gas costs incurred by DTE Gas which are recoverable through the GCR mechanism.
2014 Electric Rate Case Filing
DTE Electric filed a rate case with the MPSC on December 19, 2014 requesting an increase in base rates of $370 million based on a projected twelve-month period ending June 30, 2016. The requested increase in base rates is due primarily to an increase in net plant resulting from infrastructure investments, plant acquisitions, environmental compliance and reliability improvement projects. The rate filing also included projected changes in sales, working capital, operation and maintenance expenses, return on equity and capital structure. New rates could be self-implemented in July 2015, with a final order expected in December 2015.
2010 Electric Rate Case Filing - Court of Appeals Decision
In July 2013, the MCOA issued a decision relating to an appeal of the October 2011 MPSC order in DTE Electric's October 2010 rate case filing. The MCOA found that the record of evidence in the 2010 rate case order was insufficient to support the MPSC's authorization to recover costs for the AMI program and remanded this matter to the MPSC. The MPSC had approved an approximately $11 million rate increase related to the AMI program in the October 2011 order. DTE Electric is currently operating its AMI program pursuant to the MPSC's approval set forth in the October 2011 order. In August 2013, the MPSC reopened the 2010 electric rate case for the limited purpose of addressing the MCOA's opinion on AMI. On November 6, 2014, the MPSC issued an order affirming the recovery of costs associated with the AMI program.
Customer360 Accounting Authority
In July 2014, DTE Electric filed an application for accounting authority to defer certain costs associated with implementing Customer360, which is an integrated software application that enables improved interface among customer service, billing, meter reading, credit and collections, device management, account management, and retail access. The estimated implementation cost of Customer360 is approximately $215 million and DTE Electric proposed an amortization period of 15 years. On September 26, 2014, the MPSC approved the accounting request.
Refundable Revenue Decoupling / Deferred Gain Amortization
In September 2012, the MPSC approved DTE Electric's accounting application to defer for future amortization the gain resulting from the reversal of the Company's $127 million regulatory liability associated with the operation of the RDM. The approved application provided for the amortization of the regulatory liability to income, at a monthly rate of approximately $10.6 million, beginning January 2014. On April 1, 2014, the MPSC approved DTE Electric's accounting application to suspend the amortization of the RDM regulatory liability as of June 30, 2014 and to complete the amortization over the period January 2015 to June 2015. If DTE Electric's base rates are increased prior to July 1, 2015, the Company will cease amortization and refund to customers the remaining unamortized balance of the regulatory liability.
Transition of PLD Customers to DTE Electric's Distribution System
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 approximately 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 in 2015.
DTE Gas Infrastructure Recovery Mechanism (IRM)
In November 2014, DTE Gas filed an application with the MPSC for approval of an increased IRM surcharge to recover an additional $47 million of annual capital expenditures in 2016 and 2017 for its gas main renewal program. Resolution of this matter is anticipated in 2015.
Income Taxes (Notes)
Income Taxes
INCOME TAXES
Income Tax Summary
The Company files a consolidated federal income tax return. Total income tax expense varied from the statutory federal income tax rate for the following reasons:
 
2014
 
2013
 
2012
 
(In millions)
Income before income taxes
$
1,275

 
$
922

 
$
960

Income tax expense at 35% statutory rate
$
446

 
$
323

 
$
336

Production tax credits
(119
)
 
(68
)
 
(49
)
Investment tax credits
(6
)
 
(6
)
 
(6
)
Depreciation
(4
)
 
(4
)
 
(4
)
AFUDC - Equity
(7
)
 
(5
)
 
(4
)
Employee Stock Ownership Plan dividends
(4
)
 
(4
)
 
(4
)
Domestic production activities deduction
—

 
(14
)
 
(14
)
State and local income taxes, net of federal benefit
51

 
37

 
37

Enactment of New York Corporate Income Tax Legislation, net of federal benefit
8

 
—

 
—

Other, net
(1
)
 
(5
)
 
(6
)
Income tax expense
$
364

 
$
254

 
$
286

Effective income tax rate
28.5
%
 
27.5
%
 
29.8
%

Components of income tax expense were as follows:
 
2014
 
2013
 
2012
 
(In millions)
Current income tax expense (benefit)
 
 
 
 
 
Federal
$
(16
)
 
$
74

 
$
190

State and other income tax
24

 
16

 
49

Total current income taxes
8

 
90

 
239

Deferred income tax expense
 
 
 
 
 
Federal
289

 
122

 
39

State and other income tax
67

 
42

 
8

Total deferred income taxes
356

 
164

 
47

Total income taxes from continuing operations
364

 
254

 
286

Discontinued operations
—

 
—

 
(29
)
Total
$
364

 
$
254

 
$
257


Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the financial statements. Deferred tax assets and liabilities are classified as current or noncurrent according to the classification of the related assets or liabilities. Deferred tax assets and liabilities not related to assets or liabilities are classified according to the expected reversal date of the temporary differences. Consistent with rate making treatment, deferred taxes are offset in the table below for temporary differences which have related regulatory assets and liabilities.
Deferred tax assets (liabilities) were comprised of the following at December 31:
 
2014
 
2013
 
(In millions)
Property, plant and equipment
$
(3,832
)
 
$
(3,372
)
Securitized regulatory assets
(2
)
 
(127
)
Tax credit carry-forwards
296

 
266

Pension and benefits
(152
)
 
(30
)
State net operating loss and credit carry-forwards
39

 
43

Other
(19
)
 
(92
)
 
(3,670
)
 
(3,312
)
Less valuation allowance
(31
)
 
(37
)
 
$
(3,701
)
 
$
(3,349
)
Current deferred income tax assets (liabilities)
$
75

 
$
(28
)
Long-term deferred income tax liabilities
(3,776
)
 
(3,321
)
 
$
(3,701
)
 
$
(3,349
)
Deferred income tax assets
$
861

 
$
934

Deferred income tax liabilities
(4,562
)
 
(4,283
)
 
$
(3,701
)
 
$
(3,349
)

Tax credit carry forwards include $29 million of general business credits that expire through 2034 and $267 million of alternative minimum tax credits that may be carried forward indefinitely. The alternative minimum tax credits are production tax credits earned prior to 2006 but not utilized. The majority of these alternative minimum tax credits were generated from projects that had received a private letter ruling (PLR) from the IRS. These PLRs provide assurance as to the appropriateness of using these credits to offset taxable income, however, these tax credits are subject to IRS audit and adjustment.
The above table excludes unamortized investment tax credits that are shown separately on the Consolidated Statements of Financial Position. Investment tax credits are deferred and amortized to income over the average life of the related property.
The Company has state deferred tax assets related to net operating loss and credit carry-forwards of $39 million and $43 million at December 31, 2014 and 2013, respectively. The state net operating loss and credit carry-forwards expire from 2015 through 2034. The Company has recorded valuation allowances at December 31, 2014 and 2013 of approximately $31 million and $37 million, respectively, with respect to these deferred tax assets. In assessing the realizability of deferred tax assets, the Company considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible.
Uncertain Tax Positions
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
 
2014
 
2013
 
2012
 
(In millions)
Balance at January 1
$
10

 
$
11

 
$
48

Reductions for tax positions of prior years
—

 
—

 
(2
)
Additions for tax positions of current year
—

 
—

 
1

Settlements
—

 
—

 
(30
)
Lapse of statute of limitations
(1
)
 
(1
)
 
(6
)
Balance at December 31
$
9

 
$
10

 
$
11


The Company had $2 million of unrecognized tax benefits at December 31, 2014 and 2013, that, if recognized, would favorably impact its effective tax rate. During the next twelve months, it is reasonably possible that the statute of limitation will expire on various state tax returns. As a result, the Company believes that it is possible that there will be a decrease in unrecognized tax benefits of up to $6 million within the next twelve months.
The Company recognizes interest and penalties pertaining to income taxes in Interest expense and Other expenses, respectively, on its Consolidated Statements of Operations. Accrued interest pertaining to income taxes totaled $1 million at December 31, 2014 and 2013. The Company had no accrued penalties pertaining to income taxes. The Company recognized interest expense (income) related to income taxes of a nominal amount in 2014 and 2013 and $(1) million in 2012.
In 2014, the Company settled a federal tax audit for the 2012 tax year. The Company's federal income tax returns for 2013 and subsequent years remain subject to examination by the IRS. The Company's MBT and MCIT returns for the year 2008 and subsequent years remain subject to examination by the State of Michigan. The Company also files tax returns in numerous state and local jurisdictions with varying statutes of limitation.
Earnings Per Share (Notes)
Earnings Per Share
EARNINGS PER SHARE
The Company reports both basic and diluted earnings per share. The calculation of diluted earnings per share assumes the issuance of potentially dilutive common shares outstanding during the period from the exercise of stock options. A reconciliation of both calculations is presented in the following table as of December 31:
 
2014
 
2013
 
2012
 
(In millions, expect per share amounts)
Basic Earnings per Share
 
 
 
 
 
Net income attributable to DTE Energy Company
$
905

 
$
661

 
$
610

Average number of common shares outstanding
177

 
175

 
171

Weighted average net restricted shares outstanding
—

 
1

 
1

Dividends declared — common shares
$
475

 
$
453

 
$
413

Dividends declared — net restricted shares
1

 
1

 
1

Total distributed earnings
$
476

 
$
454

 
$
414

Net income less distributed earnings
$
429

 
$
207

 
$
196

Distributed (dividends per common share)
$
2.69

 
$
2.59

 
$
2.42

Undistributed
2.42

 
1.17

 
1.14

Total Basic Earnings per Common Share
$
5.11

 
$
3.76

 
$
3.56

Diluted Earnings per Share
 
 
 
 
 
Net income attributable to DTE Energy Company
$
905

 
$
661

 
$
610

Average number of common shares outstanding
177

 
175

 
171

Average incremental shares from assumed exercise of options
—

 
—

 
1

Common shares for dilutive calculation
177

 
175

 
172

Weighted average net restricted shares outstanding
—

 
1

 
1

Dividends declared — common shares
$
475

 
$
453

 
$
413

Dividends declared — net restricted shares
1

 
1

 
1

Total distributed earnings
$
476

 
$
454

 
$
414

Net income less distributed earnings
$
429

 
$
207

 
$
196

Distributed (dividends per common share)
$
2.69

 
$
2.59

 
$
2.42

Undistributed
2.41

 
1.17

 
1.13

Total Diluted Earnings per Common Share
$
5.10

 
$
3.76

 
$
3.55

Fair Value (Notes)
Fair Value
FAIR VALUE
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated or generally unobservable inputs. The Company makes certain assumptions it believes that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Company and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 2014 and 2013. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.
A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Company classifies fair value balances based on the fair value hierarchy defined as follows:
•
Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date.
•
Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
•
Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.
The following table presents assets and liabilities measured and recorded at fair value on a recurring basis as of December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Netting (a)
 
Net Balance
 
Level 1
 
Level 2
 
Level 3
 
Netting (a)
 
Net Balance
 
(In millions)
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash equivalents (b)
$
13

 
$
99

 
$
—

 
$
—

 
$
112

 
$
10

 
$
115

 
$
—

 
$
—

 
$
125

Nuclear decommissioning trusts
792

 
449

 
—

 
—

 
1,241

 
779

 
412

 
—

 
—

 
1,191

Other investments (c) (d)
100

 
50

 
—

 
—

 
150

 
92

 
44

 
—

 
—

 
136

Derivative assets:
 

 
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 

 
 
Commodity Contracts:
 

 
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 

 
 
Natural Gas
555

 
140

 
92

 
(681
)
 
106

 
273

 
89

 
34

 
(382
)
 
14

Electricity
—

 
295

 
47

 
(280
)
 
62

 
—

 
261

 
139

 
(291
)
 
109

Other
42

 
—

 
3

 
(42
)
 
3

 
33

 
1

 
3

 
(34
)
 
3

Other derivative contracts (e)
—

 
4

 
—

 
(3
)
 
1

 
—

 
—

 
—

 
—

 
—

Total derivative assets
597

 
439

 
142

 
(1,006
)
 
172

 
306

 
351

 
176

 
(707
)
 
126

Total
$
1,502

 
$
1,037

 
$
142

 
$
(1,006
)
 
$
1,675

 
$
1,187

 
$
922

 
$
176

 
$
(707
)
 
$
1,578

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Derivative liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Commodity Contracts:
 

 
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 

 
 
Natural Gas
$
(578
)
 
$
(78
)
 
$
(62
)
 
$
679

 
$
(39
)
 
$
(277
)
 
$
(140
)
 
$
(86
)
 
$
395

 
$
(108
)
Electricity
—

 
(290
)
 
(52
)
 
298

 
(44
)
 
—

 
(272
)
 
(126
)
 
269

 
(129
)
Other
(32
)
 
(9
)
 
(4
)
 
45

 
—

 
(32
)
 
(2
)
 
—

 
34

 
—

Other derivative contracts (e)
—

 
(5
)
 
—

 
3

 
(2
)
 
—

 
(1
)
 
—

 
—

 
(1
)
Total derivative liabilities
(610
)
 
(382
)
 
(118
)
 
1,025

 
(85
)
 
(309
)
 
(415
)
 
(212
)
 
698

 
(238
)
Total
$
(610
)
 
$
(382
)
 
$
(118
)
 
$
1,025

 
$
(85
)
 
$
(309
)
 
$
(415
)
 
$
(212
)
 
$
698

 
$
(238
)
Net Assets (Liabilities) at the end of the period
$
892

 
$
655

 
$
24

 
$
19

 
$
1,590

 
$
878

 
$
507

 
$
(36
)
 
$
(9
)
 
$
1,340

Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
$
582

 
$
504

 
$
109

 
$
(955
)
 
$
240

 
$
277

 
$
400

 
$
139

 
$
(592
)
 
$
224

Noncurrent (f)
920

 
533

 
33

 
(51
)
 
1,435

 
910

 
522

 
37

 
(115
)
 
1,354

Total Assets
$
1,502

 
$
1,037

 
$
142

 
$
(1,006
)
 
$
1,675

 
$
1,187

 
$
922

 
$
176

 
$
(707
)
 
$
1,578

Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
$
(572
)
 
$
(357
)
 
$
(112
)
 
$
964

 
$
(77
)
 
$
(268
)
 
$
(328
)
 
$
(177
)
 
$
578

 
$
(195
)
Noncurrent
(38
)
 
(25
)
 
(6
)
 
61

 
(8
)
 
(41
)
 
(87
)
 
(35
)
 
120

 
(43
)
Total Liabilities
$
(610
)
 
$
(382
)
 
$
(118
)
 
$
1,025

 
$
(85
)
 
$
(309
)
 
$
(415
)
 
$
(212
)
 
$
698

 
$
(238
)
Net Assets (Liabilities) at the end of the period
$
892

 
$
655

 
$
24

 
$
19

 
$
1,590

 
$
878

 
$
507

 
$
(36
)
 
$
(9
)
 
$
1,340


_______________________________________
(a)
Amounts represent the impact of master netting agreements that allow the Company to net gain and loss positions and cash collateral held or placed with the same counterparties.
(b)
At December 31, 2014, available-for-sale securities of $112 million included $105 million and $7 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. At December 31, 2013, available-for-sale securities of $125 million, included $109 million and $16 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively.
(c)
Excludes cash surrender value of life insurance investments.
(d)
Available-for-sale equity securities of $8 million at December 31, 2014 and $7 million at December 31, 2013 are included in Other investments on the Consolidated Statements of Financial Position.
(e)
Primarily includes Foreign currency exchange contracts.
(f)
Includes $150 million and $136 million of Other investments that are included in the Consolidated Statements of Financial Position in Other investments at December 31, 2014 and 2013, respectively.
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 NAVs. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by the Company's Trust Investments Department which reports to the Company's Vice President and Treasurer.
Derivative Assets and Liabilities
Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. DTE Energy considers the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality and basis differential factors. DTE Energy monitors the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. DTE Energy has obtained an understanding of how these prices are derived. Additionally, DTE Energy selectively corroborates the fair value of its transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Company has established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of our forward price curves has been assigned to our Risk Management Department, which is separate and distinct from the trading functions within the Company.
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2014 and 2013:
 
Year Ended December 31, 2014
 
Year Ended December 31, 2013
 
Natural Gas
 
Electricity
 
Other
 
Total
 
Natural Gas
 
Electricity
 
Other
 
Total
 
(In millions)
Net Assets (Liabilities) as of December 31
$
(52
)
 
$
13

 
$
3

 
$
(36
)
 
$
(38
)
 
$
23

 
$
2

 
$
(13
)
Transfers into Level 3 from Level 2
—

 
—

 
—

 
—

 
1

 
—

 
—

 
1

Transfers from Level 3 into Level 2
(2
)
 
—

 
—

 
(2
)
 
—

 
—

 
—

 
—

Total gains (losses):
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Included in earnings
(40
)
 
25

 
(5
)
 
(20
)
 
(32
)
 
75

 
—

 
43

Recorded in regulatory assets/liabilities
—

 
—

 
8

 
8

 
—

 
—

 
5

 
5

Purchases, issuances and settlements:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Purchases
—

 
1

 
—

 
1

 
(8
)
 
1

 
—

 
(7
)
Issuances
—

 
(3
)
 
—

 
(3
)
 
—

 
(1
)
 
—

 
(1
)
Settlements
124

 
(41
)
 
(7
)
 
76

 
25

 
(85
)
 
(4
)
 
(64
)
Net Assets (Liabilities) as of December 31
$
30

 
$
(5
)
 
$
(1
)
 
$
24

 
$
(52
)
 
$
13

 
$
3

 
$
(36
)
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
$
35

 
$
9

 
$
(4
)
 
$
40

 
$
(49
)
 
$
48

 
$
—

 
$
(1
)

Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period. There were no transfers between levels 1 and 2 during the years ended December 31, 2014 and 2013.
The following tables present the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2014 and 2013:
 
 
December 31, 2014
 
 
 
 
 
 
 
 
 
 
Commodity Contracts
 
Derivative Assets
 
Derivative Liabilities
 
Valuation Techniques
 
Unobservable Input
 
Range
 
Weighted Average
 
 
(In millions)
 
 
 
 
 
 
 
 
 
 
Natural Gas
 
$
92

 
$
(62
)
 
Discounted Cash Flow
 
Forward basis price (per MMBtu)
 
$
(2.28
) —
 
$
7.83
/MMBtu
 
$
(0.22
)/MMBtu
Electricity
 
$
47

 
$
(52
)
 
Discounted Cash Flow
 
Forward basis price (per MWh)
 
$
(14
) —
 
$
15
/MWh
 
$
4
/MWh
 
 
December 31, 2013
 
 
 
 
 
 
 
 
 
 
Commodity Contracts
 
Derivative Assets
 
Derivative Liabilities
 
Valuation Techniques
 
Unobservable Input
 
Range
 
Weighted Average
 
 
(In millions)
 
 
 
 
 
 
 
 
 
 
Natural Gas
 
$
34

 
$
(86
)
 
Discounted Cash Flow
 
Forward basis price (per MMBtu)
 
$
(0.88
) —
 
$
5.07
/MMBtu
 
$
(0.16
)/MMBtu
Electricity
 
$
139

 
$
(126
)
 
Discounted Cash Flow
 
Forward basis price (per MWh)
 
$
(7
) —
 
$
15
/MWh
 
$
3
/MWh

The unobservable inputs used in the fair value measurement of the electricity and natural gas commodity types consist of inputs that are less observable due in part to lack of available broker quotes, supported by little, if any, market activity at the measurement date or are based on internally developed models. Certain basis prices (i.e., the difference in pricing between two locations) included in the valuation of natural gas and electricity contracts were deemed unobservable.
The inputs listed above would have a direct impact on the fair values of the above security types if they were adjusted. A significant increase (decrease) in the basis price would result in a higher (lower) fair value for long positions, with offsetting impacts to short positions.
Fair Value of Financial Instruments
The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. DTE Energy has obtained an understanding of how the fair values are derived. DTE Energy also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are estimated using discounted cash flow techniques that incorporate market interest rates as well 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 DTE Energy's Treasury Department which reports to the Company's Vice President and Treasurer.
The following table presents the carrying amount and fair value of financial instruments as of December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Carrying
 
Fair Value
 
Carrying
 
Fair Value
 
Amount
 
Level 1
 
Level 2
 
Level 3
 
Amount
 
Level 1
 
Level 2
 
Level 3
 
(In millions)
Notes receivable, excluding capital leases
$
41

 
$
—

 
$
—

 
$
41

 
$
41

 
$
—

 
$
—

 
$
41

Dividends payable
$
122

 
$
122

 
$
—

 
$
—

 
$
116

 
$
116

 
$
—

 
$
—

Short-term borrowings
$
398

 
$
—

 
$
398

 
$
—

 
$
131

 
$
—

 
$
131

 
$
—

Long-term debt, excluding capital leases
$
8,606

 
$
489

 
$
8,308

 
$
706

 
$
8,094

 
$
425

 
$
7,551

 
$
499


For further fair value information on financial and derivative instruments see Note 12 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments".
Nuclear Decommissioning Trust Funds
DTE Electric has a legal obligation to decommission its nuclear power plants following the expiration of their operating licenses. This obligation is reflected as an asset retirement obligation on the Consolidated Statements of Financial Position. Rates approved by the MPSC provide for the recovery of decommissioning costs of Fermi 2 and the disposal of low-level radioactive waste. DTE Electric is continuing to fund FERC jurisdictional amounts for decommissioning even though explicit provisions are not included in FERC rates. See Note 7 to the Consolidated Financial Statements, "Asset Retirement Obligations".
The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
 
December 31, 2014
 
December 31, 2013
 
(In millions)
Fermi 2
$
1,221

 
$
1,172

Fermi 1
3

 
3

Low level radioactive waste
17

 
16

Total
$
1,241

 
$
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:
 
Year Ended December 31
 
2014
 
2013
 
2012
 
(In millions)
Realized gains
$
54

 
$
83

 
$
37

Realized losses
$
(33
)
 
$
(41
)
 
$
(31
)
Proceeds from sales of securities
$
1,146

 
$
1,118

 
$
759


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:
 
December 31, 2014
 
December 31, 2013
 
Fair
Value
 
Unrealized
Gains
 
Unrealized Losses
 
Fair
Value
 
Unrealized
Gains
 
Unrealized Losses
 
(In millions)
Equity securities
$
756

 
$
204

 
$
(39
)
 
$
730

 
$
201

 
$
(25
)
Debt securities
474

 
21

 
(2
)
 
442

 
12

 
(6
)
Cash and cash equivalents
11

 
—

 
—

 
19

 
—

 
—

 
$
1,241

 
$
225


$
(41
)
 
$
1,191

 
$
213


$
(31
)

At December 31, 2014, investments in the nuclear decommissioning trust funds consisted of approximately 61% in publicly traded equity securities, 38% in fixed debt instruments and 1% in cash equivalents. At December 31, 2013, investments in the nuclear decommissioning trust funds consisted of approximately 61% in publicly traded equity securities, 37% in fixed debt instruments and 2% in cash equivalents.
The debt securities at December 31, 2014 and 2013 had an average maturity of approximately 7 years. Securities held in the nuclear decommissioning trust funds are classified as available-for-sale. As DTE Electric does not have the ability to hold impaired investments for a period of time sufficient to allow for the anticipated recovery of market value, all unrealized losses are considered to be other-than-temporary impairments.
Unrealized losses incurred by the Fermi 2 trust are recognized as a Regulatory asset.
Other Securities
At December 31, 2014 and 2013, these securities are comprised primarily of money-market and equity securities. During the years ended December 31, 2014 and 2013, no amounts of unrealized losses on available-for-sale securities were reclassified out of other comprehensive income and realized into net income for the periods. Gains related to trading securities held at December 31, 2014, 2013 and 2012 were $14 million, $22 million and $11 million, respectively.
Financial and Other Derivative Instruments (Notes)
Financial and Other Derivative Instruments
FINANCIAL AND OTHER DERIVATIVE INSTRUMENTS
The Company recognizes all derivatives at their fair value as Derivative assets or liabilities on the Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge), or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in the fair value are recognized in earnings each period.
The Company’s primary market risk exposure is associated with commodity prices, credit and interest rates. The Company has risk management policies to monitor and manage market risks. The Company uses derivative instruments to manage some of the exposure. The Company uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include electricity, natural gas, oil and certain coal forwards, futures, options and swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits and natural gas storage assets.
DTE Electric — DTE Electric generates, purchases, distributes and sells electricity. DTE Electric uses forward energy contracts to manage changes in the price of electricity and fuel. Substantially all of these contracts meet the normal purchases and sales exemption and are therefore accounted for under the accrual method. Other derivative contracts are 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.
DTE Gas — DTE Gas purchases, stores, transports, distributes and sells natural gas and sells storage and transportation capacity. DTE Gas has fixed-priced contracts for portions of its expected natural gas supply requirements through March 2017. Substantially all of these contracts meet the normal purchases and sales exemption and are therefore accounted for under the accrual method. DTE Gas may also sell forward transportation and storage capacity contracts. Forward transportation and storage contracts are generally not derivatives and are therefore accounted for under the accrual method.
Gas Storage and Pipelines — This segment is primarily engaged in services related to the transportation and storage of natural gas. Primarily fixed-priced contracts are used in the marketing and management of transportation and storage services. Generally these contracts are not derivatives and are therefore accounted for under the accrual method.
Power and Industrial Projects — This segment manages and operates energy and pulverized coal projects, coke batteries, reduced emissions fuel projects, landfill gas recovery and power generation assets. Primarily fixed-price contracts are used in the marketing and management of the segment assets. These contracts are generally not derivatives and are therefore accounted for under the accrual method.
Energy Trading — Commodity Price Risk — Energy Trading markets and trades electricity, natural gas physical products and energy financial instruments, and provides energy and asset management services utilizing energy commodity derivative instruments. Forwards, futures, options and swap agreements are used to manage exposure to the risk of market price and volume fluctuations in its operations. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.
Energy Trading — Foreign Currency Exchange Risk — Energy Trading has foreign currency exchange forward contracts to economically hedge fixed Canadian dollar commitments existing under natural gas and power purchase and sale contracts and natural gas transportation contracts. The Company enters into these contracts to mitigate price volatility with respect to fluctuations of the Canadian dollar relative to the U.S. dollar. These derivatives are accounted for by recording changes in fair value to earnings unless hedge accounting criteria are met.
Corporate and Other — Interest Rate Risk — The Company uses interest rate swaps, treasury locks and other derivatives to hedge the risk associated with interest rate market volatility.
Credit Risk — The utility and non-utility businesses are exposed to credit risk if customers or counterparties do not comply with their contractual obligations. The Company maintains credit policies that significantly minimize overall credit risk. These policies include an evaluation of potential customers’ and counterparties’ financial condition, credit rating, collateral requirements or other credit enhancements such as letters of credit or guarantees. The Company generally uses standardized agreements that allow the netting of positive and negative transactions associated with a single counterparty. The Company maintains a provision for credit losses based on factors surrounding the credit risk of its customers, historical trends, and other information. Based on the Company’s credit policies and its December 31, 2014 and 2013 provision for credit losses, the Company’s exposure to counterparty nonperformance is not expected to have a material adverse effect on the Company’s financial statements.
Derivative Activities
The Company manages its MTM risk on a portfolio basis based upon the delivery period of its contracts and the individual components of the risks within each contract. Accordingly, it records and manages the energy purchase and sale obligations under its contracts in separate components based on the commodity (e.g. electricity or natural gas), the product (e.g. electricity for delivery during peak or off-peak hours), the delivery location (e.g. by region), the risk profile (e.g. forward or option), and the delivery period (e.g. by month and year). The following describes the categories of activities represented by their operating characteristics and key risks:
•
Asset Optimization — Represents derivative activity associated with assets owned and contracted by DTE Energy, including forward natural gas purchases and sales, natural gas transportation and storage capacity. Changes in the value of derivatives in this category typically economically offset changes in the value of underlying non-derivative positions, which do not qualify for fair value accounting. The difference in accounting treatment of derivatives in this category and the underlying non-derivative positions can result in significant earnings volatility.
•
Marketing and Origination — Represents derivative activity transacted by originating substantially hedged positions with wholesale energy marketers, producers, end users, utilities, retail aggregators and alternative energy suppliers.
•
Fundamentals Based Trading — Represents derivative activity transacted with the intent of taking a view, capturing market price changes, or putting capital at risk. This activity is speculative in nature as opposed to hedging an existing exposure.
•
Other — Includes derivative activity at DTE Electric related to FTRs. Changes in the value of derivative contracts at DTE Electric are recorded as Derivative assets or liabilities, with an offset to Regulatory assets or liabilities as the settlement value of these contracts will be included in the PSCR mechanism when realized.
The following tables present the fair value of derivative instruments as of December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Derivative
Assets
 
Derivative Liabilities
 
Derivative
Assets
 
Derivative Liabilities
 
(In millions)
Derivatives not designated as hedging instruments:
 
 
 
 
 
 
 
Foreign currency exchange contracts
$
4

 
$
(5
)
 
$
—

 
$
(1
)
Commodity Contracts:
 
 
 
 
 

 
 

Natural Gas
787

 
(718
)
 
396

 
(503
)
Electricity
342

 
(342
)
 
400

 
(398
)
Other
45

 
(45
)
 
37

 
(34
)
Total derivatives not designated as hedging instruments:
$
1,178

 
$
(1,110
)
 
$
833

 
$
(936
)
Total derivatives:
 
 
 
 
 
 
 
Current
$
1,083

 
$
(1,041
)
 
$
691

 
$
(773
)
Noncurrent
95

 
(69
)
 
142

 
(163
)
Total derivatives
$
1,178

 
$
(1,110
)
 
$
833

 
$
(936
)

Certain of the Company's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, the Company offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces the Company's total assets and liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in accounts receivable and accounts payable as collateral paid or received, respectively.
The Company also provides and receives collateral in the form of letters of credit which can be offset against net derivative assets and liabilities as well as accounts receivable and payable. The Company had issued letters of credit of approximately $7 million and $19 million at December 31, 2014 and 2013, respectively, which could be used to offset net derivative liabilities. Letters of credit received from third parties which could be used to offset our net derivative assets were approximately $5 million and $1 million at December 31, 2014 and 2013, respectively. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in the Consolidated Statements of Financial Position.
For contracts with certain clearing agents the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a derivative asset or liability or 2) an account receivable or payable. Other than certain clearing agents, accounts receivable and accounts payable that are subject to netting arrangements have not been offset against the fair value of derivative assets and liabilities. Certain contracts that have netting arrangements have not been offset in the Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below.
The total cash collateral posted, net of cash collateral received, was $61 million and $12 million as of December 31, 2014 and 2013, respectively. There was no cash collateral related to unrealized positions to net against derivative assets while derivative liabilities are shown net of cash collateral of $19 million as of December 31, 2014. As of December 31, 2013, derivative assets and derivative liabilities are shown net of cash collateral of $26 million and $17 million, respectively. The Company recorded cash collateral paid of $44 million and cash collateral received of $2 million not related to unrealized derivative positions as of December 31, 2014. The Company recorded cash collateral paid of $34 million and cash collateral received of $13 million not related to unrealized derivative positions as of December 31, 2013. These amounts are included in accounts receivable and accounts payable and are recorded net by counterparty.
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Gross Amounts of Recognized Assets (Liabilities)
 
Gross Amounts Offset in the Consolidated Statements of Financial Position
 
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
 
Gross Amounts of Recognized Assets (Liabilities)
 
Gross Amounts Offset in the Consolidated Statements of Financial Position
 
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
 
(In millions)
Derivative assets:
 
 
 
 
 
 
 
 
 
 
 
Commodity Contracts:
 
 
 
 
 
 
 
 
 
 
 
Natural Gas
$
787

 
$
(681
)
 
$
106

 
$
396

 
$
(382
)
 
$
14

Electricity
342

 
(280
)
 
62

 
400

 
(291
)
 
109

Other
45

 
(42
)
 
3

 
37

 
(34
)
 
3

Other derivative contracts (a)
4

 
(3
)
 
1

 
—

 
—

 
—

Total derivative assets
$
1,178

 
$
(1,006
)
 
$
172

 
$
833

 
$
(707
)
 
$
126

 
 
 
 
 
 
 
 
 
 
 
 
Derivative liabilities:
 
 
 
 
 
 
 
 
 
 
 
Commodity Contracts:
 
 
 
 
 
 
 
 
 
 
 
Natural Gas
$
(718
)
 
$
679

 
$
(39
)
 
$
(503
)
 
$
395

 
$
(108
)
Electricity
(342
)
 
298

 
(44
)
 
(398
)
 
269

 
(129
)
Other
(45
)
 
45

 
—

 
(34
)
 
34

 
—

Other derivative contracts (a)
(5
)
 
3

 
(2
)
 
(1
)
 
—

 
(1
)
Total derivative liabilities
$
(1,110
)
 
$
1,025

 
$
(85
)
 
$
(936
)
 
$
698

 
$
(238
)

_______________________________________
(a)
Primarily includes Foreign currency exchange contracts
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Derivative Assets
 
Derivative Liabilities
 
Derivative Assets
 
Derivative Liabilities
 
Current
 
Noncurrent
 
Current
 
Noncurrent
 
Current
 
Noncurrent
 
Current
 
Noncurrent
 
(In millions)
Reconciliation of derivative instruments to Consolidated Statements of Financial Position:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total fair value of derivatives
$
1,083

 
$
95

 
$
(1,041
)
 
$
(69
)
 
$
691

 
$
142

 
$
(773
)
 
$
(163
)
Counterparty netting
(955
)
 
(51
)
 
955

 
51

 
(566
)
 
(115
)
 
566

 
115

Collateral adjustment
—

 
—

 
9

 
10

 
(26
)
 
—

 
12

 
5

Total derivatives as reported
$
128

 
$
44

 
$
(77
)
 
$
(8
)
 
$
99

 
$
27

 
$
(195
)
 
$
(43
)

The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for years ended December 31, 2014 and 2013 is as follows:
 
 
Location of Gain (Loss) Recognized in Income on Derivatives
 
Gain (Loss) Recognized in
Income on Derivatives for
Years Ended December 31,
Derivatives not Designated as Hedging Instruments
 
 
2014
 
2013
 
 
 
 
(In millions)
Foreign currency exchange contracts
 
Operating Revenue
 
$
(2
)
 
$
(1
)
Commodity Contracts:
 
 
 
 
 
 
Natural Gas
 
Operating Revenue
 
(30
)
 
(48
)
Natural Gas
 
Fuel, purchased power and gas
 
(5
)
 
(44
)
Electricity
 
Operating Revenue
 
123

 
82

Other
 
Operating Revenue
 
(7
)
 
—

Total
 
 
 
$
79

 
$
(11
)

Revenues and energy costs related to trading contracts are presented on a net basis in the Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating revenues. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating revenue and purchases recorded in Fuel, purchased power and gas.
The following represents the cumulative gross volume of derivative contracts outstanding as of December 31, 2014:
Commodity
 
Number of Units
Natural Gas (MMBtu)
 
895,599,953
Electricity (MWh)
 
11,296,153
Foreign Currency Exchange (Canadian dollars)
 
63,022,462

Various subsidiaries of the Company have entered into contracts which contain ratings triggers and are guaranteed by DTE Energy. These contracts contain provisions which allow the counterparties to require that the Company post cash or letters of credit as collateral in the event that DTE Energy’s credit rating is downgraded below investment grade. Certain of these provisions (known as “hard triggers”) state specific circumstances under which the Company can be required to post collateral upon the occurrence of a credit downgrade, while other provisions (known as “soft triggers”) are not as specific. For contracts with soft triggers, it is difficult to estimate the amount of collateral which may be requested by counterparties and/or which the Company may ultimately be required to post. The amount of such collateral which could be requested fluctuates based on commodity prices (primarily natural gas, power and coal) and the provisions and maturities of the underlying transactions. As of December 31, 2014, DTE Energy's contractual obligation to post collateral in the form of cash or letter of credit in the event of a downgrade to below investment grade, under both hard trigger and soft trigger provisions, was approximately $349 million.
As of December 31, 2014, the Company had approximately $1,058 million of derivatives in net liability positions, for which hard triggers exist. Collateral of approximately $12 million has been posted against such liabilities, including cash and letters of credit. Associated derivative net asset positions for which contractual offset exists were approximately $973 million. The net remaining amount of approximately $73 million is derived from the $349 million noted above.
Long-Term Debt (Notes)
Long-Term Debt
LONG-TERM DEBT
Long-Term Debt
The Company’s long-term debt outstanding and weighted average interest rates (a) of debt outstanding at December 31 were:
 
2014
 
2013
 
(In millions)
Mortgage bonds, notes and other
 
 
 
DTE Energy Debt, Unsecured
 
 
 
4.6% due 2016 to 2033
$
1,647

 
$
1,297

DTE Electric Taxable Debt, Principally Secured
 
 
 
4.5% due 2016 to 2044
4,824

 
4,286

DTE Electric Tax-Exempt Revenue Bonds (b)
 
 
 
5.2% due 2020 to 2030
330

 
558

DTE Gas Taxable Debt, Principally Secured
 
 
 
5.2% due 2015 to 2044
1,099

 
1,029

Other Long-Term Debt, Including Non-Recourse Debt
121

 
142

 
8,021

 
7,312

Less amount due within one year
(161
)
 
(694
)
 
$
7,860

 
$
6,618

Securitization bonds
 
 
 
6.6% due 2015
$
105

 
$
302

Less amount due within one year
(105
)
 
(197
)
 
$
—

 
$
105

Junior Subordinated Debentures
 
 
 
6.5% due 2061
$
280

 
$
280

5.25% due 2062
200

 
200

 
$
480

 
$
480


_______________________________________
(a)
Weighted average interest rates as of December 31, 2014 are shown below the description of each category of debt.
(b)
DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.
Debt Issuances
In 2014, the following debt was issued:
Company
 
Month Issued
 
Type
 
Interest Rate
 
Maturity
 
Amount
 
 
 
 
 
 
 
 
 
 
(In millions)
DTE Energy
 
May
 
Senior Notes (a)
 
3.50
%
 
2024
 
$
350

DTE Electric
 
June
 
Mortgage Bonds (a)
 
3.77
%
 
2026
 
100

DTE Electric
 
June
 
Mortgage Bonds (a)
 
4.60
%
 
2044
 
150

DTE Electric
 
July
 
Mortgage Bonds (a)
 
3.375
%
 
2025
 
350

DTE Electric
 
July
 
Mortgage Bonds (a)
 
4.30
%
 
2044
 
350

DTE Energy
 
November
 
Senior Notes (a)
 
2.40
%
 
2019
 
300

DTE Gas
 
December
 
Mortgage Bonds (a)
 
4.35
%
 
2044
 
150

 
 
 
 
 
 
 
 
 
 
$
1,750


_______________________________________
(a)
Proceeds were used for the redemption of long-term debt, repayment of short-term borrowings and general corporate purposes.
Debt Redemptions
In 2014, the following debt was redeemed:
Company
 
Month
 
Type
 
Interest Rate
 
Maturity
 
Amount
 
 
 
 
 
 
 
 
 
 
(In millions)
DTE Electric
 
March
 
Mortgage Bonds
 
Various

 
2014
 
$
13

DTE Electric
 
March
 
Securitization Bonds
 
6.62
%
 
2014
 
100

DTE Electric
 
April
 
Tax Exempt Revenue Bonds (a)
 
2.35
%
 
2024
 
31

DTE Electric
 
April
 
Tax Exempt Revenue Bonds (a)
 
4.65
%
 
2028
 
32

DTE Gas
 
May
 
Mortgage Bonds
 
8.25
%
 
2014
 
80

DTE Energy
 
May
 
Senior Notes
 
7.625
%
 
2014
 
300

DTE Electric
 
June
 
Tax Exempt Revenue Bonds (a)
 
4.875
%
 
2029
 
36

DTE Electric
 
June
 
Tax Exempt Revenue Bonds (a)
 
6.00
%
 
2036
 
69

DTE Electric
 
July
 
Senior Notes
 
4.80
%
 
2015
 
200

DTE Electric
 
August
 
Senior Notes
 
5.40
%
 
2014
 
200

DTE Electric
 
August
 
Tax Exempt Revenue Bonds (a)
 
5.25
%
 
2029
 
60

DTE Electric
 
September
 
Securitization Bonds
 
6.62
%
 
2014
 
96

DTE Energy
 
Various
 
Other Long Term Debt
 
Various

 
2014
 
20

 
 
 
 
 
 
 
 
 
 
$
1,237

_______________________________________
(a)
DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.
The following table shows the scheduled debt maturities, excluding any unamortized discount or premium on debt:
 
2015
 
2016
 
2017
 
2018
 
2019
 
2020 and Thereafter
 
Total
 
(In millions)
Amount to mature
$
266

 
$
465

 
$
9

 
$
407

 
$
427

 
$
7,046

 
$
8,620


Junior Subordinated Debentures
At December 31, 2014, DTE Energy had $280 million of 6.5% Junior Subordinated Debentures due 2061 and $200 million of 5.25% Junior Subordinated Debentures due 2062. DTE Energy has the right to defer interest payments on the debt securities. Should DTE Energy exercise this right, it cannot declare or pay dividends on, or redeem, purchase or acquire, any of its capital stock during the deferral period. Any deferred interest payments will bear additional interest at the rate associated with the related debt issue. As of December 31, 2014, no interest payments have been deferred on the debt securities.
Cross Default Provisions
Substantially all of the net utility properties of DTE Electric and DTE Gas are subject to the lien of mortgages. Should DTE Electric or DTE Gas fail to timely pay their indebtedness under these mortgages, such failure may create cross defaults in the indebtedness of DTE Energy.
Preferred and Preferenced Securities (Notes)
Preferred and Preference Securities
PREFERRED AND PREFERENCE SECURITIES
As of December 31, 2014, the amount of authorized and unissued stock is as follows:
Company
 
Type of Stock
 
Par Value
 
Shares Authorized
DTE Energy
 
Preferred
 
$
—

 
5,000,000

DTE Electric
 
Preferred
 
$
100

 
6,747,484

DTE Electric
 
Preference
 
$
1

 
30,000,000

DTE Gas
 
Preferred
 
$
1

 
7,000,000

DTE Gas
 
Preference
 
$
1

 
4,000,000

Short-Term Credit Arrangements and Borrowings (Notes)
Short-Term Credit Arrangements and Borrowings
SHORT-TERM CREDIT ARRANGEMENTS AND BORROWINGS
DTE Energy and its wholly owned subsidiaries, DTE Electric and DTE Gas, have unsecured revolving credit agreements that can be used for general corporate borrowings, but are intended to provide liquidity support for each of the companies’ commercial paper programs. Borrowings under the facilities are available at prevailing short-term interest rates. Additionally, DTE Energy has other facilities to support letter of credit issuance.
The agreements require the Company to maintain a total funded debt to capitalization ratio of no more than 0.65 to 1. At December 31, 2014, the total funded debt to total capitalization ratios for DTE Energy, DTE Electric and DTE Gas are 0.50 to 1, 0.51 to 1 and 0.48 to 1, respectively, and are in compliance with this financial covenant. The availability under the facilities in place at December 31, 2014 is shown in the following table:
 
DTE Energy
 
DTE Electric
 
DTE Gas
 
Total
 
(In millions)
Unsecured letter of credit facility, expiring in February 2015
$
100

 
$
—

 
$
—

 
$
100

Unsecured letter of credit facility, expiring in August 2015
125

 
—

 
—

 
125

Unsecured revolving credit facility, expiring April 2018
1,200

 
300

 
300

 
1,800

 
1,425

 
300

 
300

 
2,025

Amounts outstanding at December 31, 2014:
 
 
 
 
 
 
 
Commercial paper issuances
203

 
50

 
145

 
398

Letters of credit
204

 
—

 
—

 
204

 
407

 
50

 
145

 
602

Net availability at December 31, 2014
$
1,018

 
$
250

 
$
155

 
$
1,423


The Company has other outstanding letters of credit which are not included in the above described facilities totaling approximately $35 million which are used for various corporate purposes.
The weighted average interest rate for short-term borrowings was 0.4% and 0.2% at December 31, 2014 and 2013, respectively.
In conjunction with maintaining certain exchange traded risk management positions, the Company may be required to post cash collateral with its clearing agent. The Company has a demand financing agreement for up to $100 million with its clearing agent. The agreement, as amended, also allows for up to $50 million of additional margin financing provided that the Company posts a letter of credit for the incremental amount. At December 31, 2014, a $50 million letter of credit was in place, raising the capacity under this facility to $150 million. The $50 million letter of credit is included in the table above. The amount outstanding under this agreement was $37 million and $138 million at December 31, 2014 and 2013, respectively.
Dividend Restrictions
Certain of the Company’s credit facilities contain a provision requiring the Company to maintain a total funded debt to capitalization ratio, as defined in the agreements, of no more than 0.65 to 1, which has the effect of limiting the amount of dividends the Company can pay in order to maintain compliance with this provision. The effect of this provision was to restrict the payment of approximately $730 million at December 31, 2014 of total retained earnings of approximately $4.6 billion. There are no other effective limitations with respect to the Company’s ability to pay dividends.
Capital and Operating Leases (Notes)
Capital and Operating Leases
CAPITAL AND OPERATING LEASES
Lessee  - Operating Lease — The Company leases various assets under operating leases, including coal railcars, office buildings, a warehouse, computers, vehicles and other equipment. The lease arrangements expire at various dates through 2046.
Future minimum lease payments under non-cancelable leases at December 31, 2014 were:
 
Operating
Leases
 
(In millions)
2015
$
42

2016
34

2017
28

2018
23

2019
14

Thereafter
78

Total minimum lease payments
$
219


Rental expense for operating leases was $38 million in 2014, $34 million in 2013 and $36 million in 2012.
Lessor - Capital Lease — The Company leases a portion of its pipeline system to the Vector Pipeline through a capital lease contract that expires in 2020, with renewal options extending for five years. The Company owns a 40% interest in the Vector Pipeline. In addition, the Company has two energy services agreements, a portion of which are accounted for as capital leases. One agreement expires in 2021. The other agreement expires in 2019, with a three or five year renewal option. The components of the net investment in the capital leases at December 31, 2014, were as follows:
 
Capital
Leases
 
(In millions)
2015
$
12

2016
13

2017
13

2018
13

2019
10

Thereafter
9

Total minimum future lease receipts
70

Residual value of leased pipeline
40

Less unearned income
(34
)
Net investment in capital lease
76

Less current portion
(5
)
 
$
71

Commitments and Contingencies (Notes)
Commitments and Contingencies
COMMITMENTS AND CONTINGENCIES
Environmental
Electric
Air — DTE Electric is subject to the EPA ozone and fine particulate transport and acid rain regulations that limit power plant emissions of sulfur dioxide and nitrogen oxides. The EPA and the State of Michigan have issued emission reduction regulations relating to ozone, fine particulate, regional haze, mercury, and other air pollution. These rules have led to 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 $2.2 billion through 2014. The Company estimates DTE Electric will make capital expenditures of approximately $100 million in 2015 and up to approximately $30 million of additional capital expenditures through 2019 based on current regulations.
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), requires further reductions of sulfur dioxide and nitrogen oxides emissions effective January 2015. DTE Electric expects to meet its obligations under CSAPR beginning in 2015.
The Mercury and Air Toxics Standard (MATS) rule, formerly known as the Electric Generating Unit Maximum Achievable Control Technology (EGU MACT) Rule was finalized in December 2011. The MATS rule requires reductions of mercury and other hazardous air pollutants beginning in April 2015, with a potential extension to April 2016. DTE Electric has requested and been granted compliance date extensions for all relevant units to April 2016. DTE Electric has tested technologies to determine technological and economic feasibility as MATS compliance alternatives to Flue Gas Desulfurization (FGD) systems. Implementation of Dry Sorbent Injection (DSI) and Activated Carbon Injection (ACI) technologies will allow several units that would not have been economical for FGD installations to continue operation in compliance with MATS. In November 2014, the Supreme Court agreed to review a challenge to the MATS rule based on a narrowly focused question of how the EPA considered costs in regulating air pollutants emitted by electric utilities. DTE Electric cannot predict the financial impact or outcome of this Supreme Court case, or the timing of its resolution.
The EPA proposed revised air quality standards for ground level ozone in November 2014 and the standards are expected to be finalized by October 2015. DTE Electric will engage with the EPA and other stakeholders in commenting on this rule. DTE Electric cannot predict the financial impact of the proposed ozone standards at this time.
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.
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. In August 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. In October 2011, the EPA caused to be filed a Notice of Appeal to the U.S. Court of Appeals for the Sixth Circuit. In March 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. In September 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. In March 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. In April 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 that were brought by the Sierra Club. In June 2014, the EPA filed a motion requesting certification for appeal of the March 2014 summary judgment decision. In October 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 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.
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. A final rule was issued in May 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.
In April 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. It is not possible at this time to quantify the impacts of these developing requirements.
Contaminated and Other Sites — Prior to the construction of major interstate natural gas pipelines, gas for heating and other uses was manufactured locally from processes involving coal, coke or oil. The facilities, which produced gas, have been designated as 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 December 31, 2014 and 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.
In December 2014, the EPA released a pre-publication version of a rule to regulate coal ash. This rule is based on the continued listing of ash as a non-hazardous waste, and relies on various self-implementation design and performance standards. The rule is still being evaluated and it is not possible to quantify its impact at this time. DTE Electric owns and operates three permitted engineered ash storage facilities to dispose of fly ash from coal fired power plants and operates a number of smaller impoundments at its power plants.
Gas
Contaminated and Other Sites — Gas segment, owns or previously owned, 15 former MGP sites. Investigations have revealed contamination related to the by-products of gas manufacturing at each site. Cleanup of three of the MGP sites is complete and the sites were closed. We completed partial closure of two sites in 2014. Cleanup activities associated with the remaining sites will be continued over the next several years. The MPSC has established a cost deferral and rate recovery mechanism for investigation and remediation costs incurred at former MGP sites. In addition to the MGP sites, the Company is also in the process of cleaning up other contaminated sites, including gate stations, gas pipeline releases and underground storage tank locations. As of December 31, 2014 and 2013, the Company had $24 million and $28 million accrued for remediation, respectively. Any change in assumptions, such as remediation techniques, nature and extent of contamination and regulatory requirements, could impact the estimate of remedial action costs for the sites and affect the Company’s financial position and cash flows. The Company anticipates the cost amortization methodology approved by the MPSC for DTE Gas, which allows DTE Gas to amortize the MGP costs over a ten-year period beginning with the year subsequent to the year the MGP costs were incurred, will prevent environmental costs from having a material adverse impact on the Company’s results of operations.
Non-utility
The Company’s non-utility businesses are subject to a number of environmental laws and regulations dealing with the protection of the environment from various pollutants.
The Michigan coke battery facility received and responded to information requests from the EPA that resulted in the issuance of a NOV in June 2007 alleging potential maximum achievable control technologies and new source review violations. The EPA is in the process of reviewing the Company’s position of demonstrated compliance and has not initiated escalated enforcement. At this time, the Company cannot predict the impact of this issue. Furthermore, the Michigan coke battery facility is the subject of an investigation by the MDEQ concerning visible emissions readings that resulted from the Company self reporting to MDEQ questionable activities by an employee of a contractor hired by the Company to perform the visible emissions readings. At this time, the Company cannot predict the impact of this investigation.
The Company received two NOVs from the Pennsylvania Department of Environmental Protection (PADEP) in 2010 alleging violations of the permit for the Pennsylvania coke battery facility in connection with coal pile storm water runoff. The Company settled the alleged violations by implementing best management practices to address the issues and repair/upgrade their wastewater treatment plant. The Company recently received a permit to upgrade its existing waste water treatment system and is currently seeking a permit from the PADEP to further upgrade its wastewater treatment technology to a biological treatment facility. The Company expects to spend $1 million on the existing waste water treatment system to comply with existing water discharge requirements and to upgrade its coal pile storm water runoff management program. The Company will also spend up to an additional $13 million over the next few years to upgrade the treatment technology to biological treatment to meet future regulatory requirements and gain other operational improvement savings.
The Company received an NOV from the Allegheny County (PA) Health Department pertaining to excessive opacity readings from fugitive sources (mainly pushing emissions) in excess of its opacity standards for the Pennsylvania coke battery facility. Fugitive sources at the plant are in full compliance with the applicable Federal Opacity Standards. In February 2014, the Company received from the Group Against Smog & Pollution (GASP) a 60 day Notice of Intent to sue letter under the Federal Clean Air Act and/or Article XXI of the Allegheny County (PA) Health Department's Rules and Regulations. GASP alleged in the letter that the Company's coke battery facility in Pennsylvania was in violation of visible emissions limits from charging activities, door leaks, the combustion stack and pushing operations and hydrogen sulfide emission limits on flared, mixed or combusted coke oven gas. To resolve these issues, the Company agreed to a Consent Order and Agreement with Allegheny County pursuant to which the Company paid a fine of $300,000 and will spend $300,000 for a supplemental environmental project to enhance particulate collection efficiency from the coke battery's quench tower. Notwithstanding the agreement reached with the County, GASP proceeded with the filing of their complaint in May 2014. The Company believes that the GASP suit is without merit and filed a motion to dismiss in July 2014.
Other
In 2010, the EPA finalized a new 1-hour sulfur dioxide ambient air quality standard that requires states to submit plans for non-attainment areas to be in compliance by 2017. Michigan's non-attainment area includes DTE Energy facilities in southwest Detroit and areas of Wayne County. Preliminary modeling runs by the MDEQ suggest that emission reductions may be required by significant sources of sulfur dioxide emissions in these areas, including DTE Electric power plants and our Michigan coke battery. The state implementation plan process is in the information gathering stage, and DTE Energy 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. 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 $328 million of coverage for extra expenses over a two-year period.
On January 13, 2015, the Terrorism Risk Insurance Program Reauthorization Act of 2015 was signed, extending TRIA through December 31, 2020. 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 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 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 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 was 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 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's 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 1 mill per kWh DOE fee was reduced to zero effective May 16, 2014.
DTE Electric currently employs a spent nuclear fuel storage strategy utilizing a fuel pool and a newly completed dry cask storage facility. The initial dry cask loading campaign planned for 2014 has been 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.
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.
Synthetic Fuel Guarantees
The Company discontinued the operations of its synthetic fuel production facilities throughout the United States as of December 31, 2007. The Company provided certain guarantees and indemnities in conjunction with the sales of interests in its synfuel facilities. The guarantees cover potential commercial, environmental, oil price and tax-related obligations and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at December 31, 2014 is approximately $1 billion. Payment under these guarantees is considered remote.
REF Guarantees
The Company has provided certain guarantees and indemnities in conjunction with the sales of interests in its REF facilities. The guarantees cover potential commercial, environmental, and tax-related obligations and will survive until 90 days after expiration of all applicable statutes of limitations. The Company estimates that its maximum potential liability under these guarantees at December 31, 2014 is approximately $172 million. Payment under these guarantees is considered remote.
Other Guarantees
In certain limited circumstances, the Company enters into contractual guarantees. The Company may guarantee another entity’s obligation in the event it fails to perform. The Company may provide guarantees in certain indemnification agreements. Finally, the Company may provide indirect guarantees for the indebtedness of others. The Company’s guarantees are not individually material with maximum potential payments totaling $60 million at December 31, 2014. Payment under these guarantees is considered remote.
The Company is periodically required to obtain performance surety bonds in support of obligations to various governmental entities and other companies in connection with its operations. As of December 31, 2014, the Company had approximately $49 million of performance bonds outstanding. In the event that such bonds are called for nonperformance, the Company would be obligated to reimburse the issuer of the performance bond. The Company is released from the performance bonds as the contractual performance is completed and does not believe that a material amount of any currently outstanding performance bonds will be called.
Labor Contracts
There are several bargaining units for the Company's approximately 4,900 represented employees. The majority of the represented employees are under contracts that expire in 2016 and 2017.
Purchase Commitments
As of December 31, 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 $9.0 billion from 2015 through 2051 as detailed in the following table:
 
(In millions)
2015
$
2,384

2016
1,258

2017
742

2018
477

2019
431

2020 and thereafter
3,723

 
$
9,015


The Company also estimates that 2015 capital expenditures and contributions to equity method investments will be approximately $2.6 billion. The Company has made certain commitments in connection with expected capital expenditures.
Bankruptcies
The Company purchases and sells electricity, natural gas, coal, coke and other energy products from and to governmental entities and numerous companies operating in the steel, automotive, energy, retail, financial and other industries. Certain of its customers have filed for bankruptcy protection under the U.S. Bankruptcy Code. The Company regularly reviews contingent matters relating to these customers and its purchase and sale contracts and records provisions for amounts considered at risk of probable loss. The Company believes its accrued amounts are adequate for probable loss.
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.
For a discussion of contingencies related to regulatory matters and derivatives see Notes 8 and 12 to the Consolidated Financial Statements, "Regulatory Matters" and "Financial and Other Derivative Instruments".
Retirement Benefits and Trusteed Assets (Notes)
Retirement Benefits and Trusteed Assets
RETIREMENT BENEFITS AND TRUSTEED ASSETS
Pension Plan Benefits
The Company has qualified defined benefit retirement plans for eligible represented and non-represented employees. The plans are noncontributory, and provide traditional retirement benefits based on the employees’ years of benefit service, average final compensation and age at retirement. In addition, certain represented and non-represented employees are covered under cash balance provisions that determine benefits on annual employer contributions and interest credits. The Company also maintains supplemental nonqualified, noncontributory, retirement benefit plans for selected management employees. These plans provide for benefits that supplement those provided by DTE Energy’s other retirement plans.
Effective January 1, 2012 for non-represented employees, and in June 2011 and March 2013 for the majority of represented employees, the Company discontinued offering a defined benefit retirement plan to newly hired employees. In its place, the Company will annually contribute an amount equivalent to 4% (8% for certain DTE Gas represented employees) of an employee's eligible pay to the employee's defined contribution retirement savings plan.
The Company’s policy is to fund pension costs by contributing amounts consistent with the provisions of the Pension Protection Act of 2006 and additional amounts when it deems appropriate. The Company contributed $188 million to its qualified pension plans in 2014. At the discretion of management, and depending upon financial market conditions, the Company anticipates making up to $180 million in contributions to the pension plans in 2015.
Net pension cost includes the following components:
 
2014
 
2013
 
2012
 
(In millions)
Service cost
$
83

 
$
94

 
$
82

Interest cost
212

 
192

 
204

Expected return on plan assets
(273
)
 
(266
)
 
(244
)
Amortization of:
 
 
 
 
 
Net loss
157

 
208

 
176

Special termination benefits
—

 
—

 
2

Net pension cost
$
179

 
$
228

 
$
220

 
2014
 
2013
 
(In millions)
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income
 
 
 
Net actuarial (gain) loss
$
805

 
$
(581
)
Amortization of net actuarial loss
(157
)
 
(208
)
Prior service cost
(7
)
 
—

Total recognized in Regulatory assets and Other comprehensive income
$
641

 
$
(789
)
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income
$
820

 
$
(561
)
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
 
 
 
Net actuarial loss
$
206

 
$
151


The following table reconciles the obligations, assets and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in the Consolidated Statements of Financial Position at December 31:
 
2014
 
2013
 
(In millions)
Accumulated benefit obligation, end of year
$
4,853

 
$
4,068

Change in projected benefit obligation
 
 
 
Projected benefit obligation, beginning of year
$
4,380

 
$
4,729

Service cost
83

 
94

Interest cost
212

 
192

Plan amendments
(7
)
 
(3
)
Actuarial (gain) loss
836

 
(400
)
Benefits paid
(235
)
 
(232
)
Projected benefit obligation, end of year
$
5,269

 
$
4,380

Change in plan assets
 
 
 
Plan assets at fair value, beginning of year
$
3,720

 
$
3,223

Actual return on plan assets
301

 
445

Company contributions
195

 
284

Benefits paid
(235
)
 
(232
)
Plan assets at fair value, end of year
$
3,981

 
$
3,720

Funded status of the plans
$
(1,288
)
 
$
(660
)
Amount recorded as:
 
 
 
Current liabilities
$
(8
)
 
$
(7
)
Noncurrent liabilities
(1,280
)
 
(653
)
 
$
(1,288
)
 
$
(660
)
Amounts recognized in Accumulated other comprehensive loss, pre-tax
 
 
 
Net actuarial loss
$
194

 
$
174

Prior service (credit)
(1
)
 
(1
)
 
$
193

 
$
173

Amounts recognized in Regulatory assets (see Note 8)
 
 
 
Net actuarial loss
$
2,285

 
$
1,654

Prior service (credit) cost
(1
)
 
6

 
$
2,284

 
$
1,660


At December 31, 2014, the benefits related to the Company’s qualified and nonqualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
 
(In millions)
2015
$
269

2016
277

2017
286

2018
298

2019
309

2020-2024
1,634

Total
$
3,073


Assumptions used in determining the projected benefit obligation and net pension costs are listed below:
 
2014
 
2013
 
2012
Projected benefit obligation
 
 
 
 
 
Discount rate
4.12%
 
4.95%
 
4.15%
Rate of compensation increase
4.65%
 
4.20%
 
4.20%
Net pension costs
 
 
 
 
 
Discount rate
4.95%
 
4.15%
 
5.00%
Rate of compensation increase
4.20%
 
4.20%
 
4.20%
Expected long-term rate of return on plan assets
7.75%
 
8.25%
 
8.25%

The Company employs a formal process in determining the long-term rate of return for various asset classes. Management reviews historic financial market risks and returns and long-term historic relationships between the asset classes of equities, fixed income and other assets, consistent with the widely accepted capital market principle that asset classes with higher volatility generate a greater return over the long-term. Current market factors such as inflation, interest rates, asset class risks and asset class returns are evaluated and considered before long-term capital market assumptions are determined. The long-term portfolio return is also established employing a consistent formal process, with due consideration of diversification, active investment management and rebalancing. Peer data is reviewed to check for reasonableness. As a result of this process, the Company has long-term rate of return assumptions for its pension plans of 7.75% and other postretirement benefit plans of 8.00%, for 2015. The Company believes these rates are a reasonable assumption for the long-term rate of return on its plan assets for 2015 given its investment strategy.
The Company employs a total return investment approach whereby a mix of equities, fixed income and other investments are used to maximize the long-term return on plan assets consistent with prudent levels of risk, with consideration given to the liquidity needs of the plan. Risk tolerance is established through consideration of future plan cash flows, plan funded status and corporate financial considerations. The investment portfolio contains a diversified blend of equity, fixed income and other investments. Furthermore, equity investments are diversified across U.S. and non-U.S. stocks, growth and value stocks, and large and small market capitalizations. Fixed income securities generally include market and long duration bonds of companies from diversified industries, mortgage-backed securities, non-U.S. securities, bank loans and U.S. Treasuries. Other assets such as private markets and hedge funds are used to enhance long-term returns while improving portfolio diversification. Derivatives may be utilized in a risk controlled manner, to potentially increase the portfolio beyond the market value of invested assets and/or reduce portfolio investment risk. Investment risk is measured and monitored on an ongoing basis through annual liability measurements, periodic asset/liability studies and quarterly investment portfolio reviews.
Target allocations for pension plan assets as of December 31, 2014 are listed below:
U.S. Large Cap Equity Securities
22
%
U.S. Small Cap and Mid Cap Equity Securities
5

Non U.S. Equity Securities
20

Fixed Income Securities
25

Hedge Funds and Similar Investments
20

Private Equity and Other
8

 
100
%

Fair Value Measurements for pension plan assets at December 31, 2014 and 2013 (a):
 
December 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Total
 
(In millions)
Asset category:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Short-term investments (b)
$
46

 
$
—

 
$
—

 
$
46

 
$
22

 
$
—

 
$
—

 
$
22

Equity securities
 

 
 

 
 

 
 
 
 

 
 

 
 

 


U.S. large cap (c)
899

 
—

 
—

 
899

 
896

 
—

 
—

 
896

U.S. small/mid cap (d)
225

 
—

 
—

 
225

 
221

 
—

 
—

 
221

Non U.S. (e)
526

 
219

 
—

 
745

 
611

 
130

 
—

 
741

Fixed income securities (f)
7

 
1,113

 
—

 
1,120

 
16

 
921

 
—

 
937

Hedge funds and similar investments (g)
226

 
95

 
438

 
759

 
268

 
70

 
395

 
733

Private equity and other (h)
—

 
—

 
187

 
187

 
—

 
—

 
170

 
170

Securities lending (i)
(189
)
 
(50
)
 
—

 
(239
)
 
—

 
—

 
—

 
—

Securities lending collateral (i)
189

 
50

 
—

 
239

 
—

 
—

 
—

 
—

Total
$
1,929

 
$
1,427

 
$
625

 
$
3,981

 
$
2,034

 
$
1,121

 
$
565

 
$
3,720

_______________________________________
(a)
For a description of levels within the fair value hierarchy see Note 11 to the Consolidated Financial Statements, "Fair Value".
(b)
This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
(c)
This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(d)
This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(e)
This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(f)
This category includes corporate bonds from diversified industries, U.S. Treasuries, and mortgage-backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
(g)
This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
(h)
This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.
(i)
In 2014, DTE Energy began a securities lending program with a third party agent. The program allows the agent to lend certain securities from the Company's pension trusts to selected entities against receipt of collateral (in the form of cash) as provided for and determined in accordance with its securities lending agency agreement.
The pension trust holds debt and equity securities directly and indirectly through commingled funds and institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds and institutional mutual funds hold exchange-traded equity or debt securities and are valued based on stated NAVs. Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee challenges an assigned price and determines that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair values of securities by comparison of market-based price sources.
Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
 
Year Ended December 31, 2014
 
Year Ended December 31, 2013
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
(In millions)
Beginning Balance at January 1
$
395

 
$
170

 
$
565

 
$
339

 
$
179

 
$
518

Total realized/unrealized gains (losses)
22

 
16

 
38

 
40

 
4

 
44

Purchases, sales and settlements:
 
 
 
 
 
 
 
 
 
 
 
Purchases
22

 
31

 
53

 
16

 
15

 
31

Sales
(1
)
 
(30
)
 
(31
)
 
—

 
(28
)
 
(28
)
Ending Balance at December 31
$
438

 
$
187

 
$
625

 
$
395

 
$
170

 
$
565

The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period
$
21

 
$
11

 
$
32

 
$
38

 
$
3

 
$
41

There were no transfers between Level 3 and Level 2 and there were no significant transfers between Level 2 and Level 1 in the years ended December 31, 2014 and 2013.
Other Postretirement Benefits
The Company participates in defined benefit plans sponsored by the LLC that provide certain other postretirement health care and life insurance benefits for employees who are eligible for these benefits. The Company’s policy is to fund certain trusts to meet its other postretirement benefit obligations. Separate qualified VEBA and other benefit trusts exist. The Company contributed $24 million to these trusts for its defined benefit other postretirement medical and life insurance benefit plans during 2014. At the discretion of management, the Company anticipates making up to $200 million of contributions to the trusts in 2015.
Starting in 2012, in lieu of offering future employees defined benefit post-employment health care and life insurance benefits, the Company allocates a fixed amount per year to an account in a defined contribution VEBA for each employee. These accounts are managed either by the Company (for non-represented and certain represented groups), or by the Utility Workers of America (UWUA) for Local 223 employees. The contributions to the VEBA for these accounts were $4 million in 2014, $2 million in 2013 and less than $1 million in 2012.
Beginning in 2013, the Company replaced the defined benefit employer-sponsored retiree medical, prescription drug and dental coverage with a notional allocation to a Retiree Reimbursement Account. This change applies to both current and future Medicare eligible non-represented and future represented retirees, spouses, surviving spouses or same sex domestic partners when the youngest of the retiree's covered household turns age 65. The amount of the annual allocation to each participant is determined by the employee's retirement date: for employees who retired on or before January 1, 2013, the base allocation is $3,500, which increased to $3,570 in 2014 and for employees who retire after January 1, 2013, the base allocation is $3,250, which increased to $3,315 in 2014. The amount of the allocation will increase each year at the lower of the rate of medical inflation or 2%.
Net other postretirement cost includes the following components:
 
2014
 
2013
 
2012
 
(In millions)
Service cost
$
34

 
$
47

 
$
68

Interest cost
89

 
88

 
120

Expected return on plan assets
(122
)
 
(110
)
 
(92
)
Amortization of:
 

 
 

 
 

Net loss
20

 
64

 
80

Prior service credit
(144
)
 
(131
)
 
(25
)
Net other postretirement cost (credit)
$
(123
)
 
$
(42
)
 
$
151

 
2014
 
2013
 
(In millions)
Other changes in plan assets and APBO recognized in Regulatory assets (liabilities) and Other comprehensive income
 
 
 
Net actuarial (gain) loss
$
192

 
$
(353
)
Amortization of net actuarial loss
(20
)
 
(64
)
Prior service credit
—

 
(218
)
Amortization of prior service credit
144

 
131

Total recognized in Regulatory assets (liabilities) and Other comprehensive income
$
316

 
$
(504
)
Total recognized in net periodic benefit cost, Regulatory assets (liabilities) and Other comprehensive income
$
193

 
$
(546
)
Estimated amounts to be amortized from Regulatory assets (liabilities) and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
 
 
 
Net actuarial loss
$
43

 
$
21

Prior service credit
$
(126
)
 
$
(144
)

The following table reconciles the obligations, assets and funded status of the plans including amounts recorded as Accrued postretirement liability in the Consolidated Statements of Financial Position at December 31:
 
2014
 
2013
 
(In millions)
Change in accumulated postretirement benefit obligation
 
 
 
Accumulated postretirement benefit obligation, beginning of year
$
1,878

 
$
2,315

Service cost
34

 
47

Interest cost
89

 
88

Plan amendments
—

 
(218
)
Actuarial (gain) loss
131

 
(267
)
Medicare Part D subsidy
—

 
1

Benefits paid
(88
)
 
(88
)
Accumulated postretirement benefit obligation, end of year
$
2,044

 
$
1,878

Change in plan assets
 
 
 
Plan assets at fair value, beginning of year
$
1,527

 
$
1,153

Actual return on plan assets
62

 
196

Company contributions
24

 
264

Benefits paid
(85
)
 
(86
)
Plan assets at fair value, end of year
$
1,528

 
$
1,527

Funded status, end of year
$
(516
)
 
$
(351
)
Amount recorded as:
 
 
 
Current liabilities
$
(1
)
 
$
(1
)
Noncurrent liabilities
(515
)
 
(350
)
 
$
(516
)
 
$
(351
)
Amounts recognized in Accumulated other comprehensive loss, pre-tax
 
 
 
Net actuarial loss
$
34

 
$
29

Prior service credit
(5
)
 
(10
)
 
$
29

 
$
19

Amounts recognized in Regulatory assets (liabilities) (see Note 8)
 
 
 
Net actuarial loss
$
488

 
$
321

Prior service credit
(254
)
 
(393
)
 
$
234

 
$
(72
)

At December 31, 2014, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
 
(In millions)
2015
$
101

2016
107

2017
111

2018
117

2019
122

2020-2024
660

Total
$
1,218


Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs are listed below:
 
2014
 
2013
 
2012
Accumulated postretirement benefit obligation
 
 
 
 
 
Discount rate
4.10%
 
4.95%
 
4.15%
Health care trend rate pre- and post- 65
7.50 / 6.50%
 
7.50 / 6.50%
 
7.00%
Ultimate health care trend rate
4.50%
 
4.50%
 
5.00%
Year in which ultimate reached pre- and post- 65
2025 / 2024
 
2025 / 2024
 
2021
Other postretirement benefit costs
 
 
 
 
 
Discount rate (prior to interim remeasurement)
4.95%
 
4.15%
 
5.00%
Discount rate (post interim remeasurement)
N/A
 
4.30%
 
N/A
Expected long-term rate of return on plan assets
8.00%
 
8.25%
 
8.25%
Health care trend rate pre- and post- 65
7.50 / 6.50%
 
7.00%
 
7.00%
Ultimate health care trend rate
4.50%
 
5.00%
 
5.00%
Year in which ultimate reached pre- and post- 65
2025 / 2024
 
2021
 
2020

A one percentage point increase in health care cost trend rates would have increased the total service cost and interest cost components of benefit costs by $8 million in 2014 and increased the accumulated benefit obligation by $108 million at December 31, 2014. A one percentage point decrease in the health care cost trend rates would have decreased the total service and interest cost components of benefit costs by $7 million in 2014 and would have decreased the accumulated benefit obligation by $94 million at December 31, 2014.
The process used in determining the long-term rate of return for assets and the investment approach for the Company’s other postretirement benefits plans is similar to those previously described for its pension plans.
Target allocations for other postretirement benefit plan assets as of December 31, 2014 are listed below:
U.S. Large Cap Equity Securities
17
%
U.S. Small Cap and Mid Cap Equity Securities
4

Non U.S. Equity Securities
20

Fixed Income Securities
25

Hedge Funds and Similar Investments
20

Private Equity and Other
14

 
100
%

Fair Value Measurements for other postretirement benefit plan assets at December 31, 2014 and 2013 (a):
 
December 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Total
Asset category:
(In millions)
Short-term investments (b)
$
6

 
$
—

 
$
—

 
$
6

 
$
5

 
$
—

 
$
—

 
$
5

Equity securities
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 
U.S. large cap (c)
266

 
—

 
—

 
266

 
302

 
—

 
—

 
302

U.S. small/mid cap (d)
149

 
—

 
—

 
149

 
147

 
—

 
—

 
147

Non U.S. (e)
222

 
59

 
—

 
281

 
282

 
9

 
—

 
291

Fixed income securities (f)
15

 
360

 
—

 
375

 
17

 
350

 
—

 
367

Hedge funds and similar investments (g)
107

 
45

 
168

 
320

 
130

 
25

 
159

 
314

Private equity and other (h)
—

 
—

 
131

 
131

 
—

 
—

 
101

 
101

Securities lending (i)
(141
)
 
(17
)
 
—

 
(158
)
 
—

 
—

 
—

 
—

Securities lending collateral (i)
141

 
17

 
—

 
158

 
—

 
—

 
—

 
—

Total
$
765

 
$
464

 
$
299

 
$
1,528

 
$
883

 
$
384

 
$
260

 
$
1,527

_______________________________________
(a)
For a description of levels within the fair value hierarchy see Note 11 to the Consolidated Financial Statements, "Fair Value".
(b)
This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
(c)
This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(d)
This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(e)
This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(f)
This category includes corporate bonds from diversified industries, U.S. Treasuries, bank loans and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
(g)
This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
(h)
This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.
(i)
In 2014, DTE Energy began a securities lending program with a third party agent. The program allows the agent to lend certain securities from the Company's VEBA trust to selected entities against receipt of collateral (in the form of cash) as provided for and determined in accordance with its securities lending agency agreement.
The VEBA trust holds debt and equity securities directly and indirectly through commingled funds and institutional mutual funds. Exchange-traded debt and equity securities held directly are valued using quoted market prices in actively traded markets. The commingled funds and institutional mutual funds hold exchange-traded equity or debt securities and are valued based on NAVs. Non-exchange traded fixed income securities are valued by the trustee based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee challenges an assigned price and determines that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair values of securities by comparison of market-based price sources.
Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
 
Year Ended December 31, 2014
 
Year Ended December 31, 2013
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
(In millions)
Beginning Balance at January 1
$
159

 
$
101

 
$
260

 
$
119

 
$
86

 
$
205

Total realized/unrealized gains (losses)
8

 
9

 
17

 
14

 
9

 
23

Purchases, sales and settlements:
 
 
 
 
 
 
 
 
 
 
 
Purchases
9

 
33

 
42

 
26

 
15

 
41

Sales
(8
)
 
(12
)
 
(20
)
 
—

 
(9
)
 
(9
)
Ending Balance at December 31
$
168

 
$
131

 
$
299

 
$
159

 
$
101

 
$
260

The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period
$
7

 
$
8

 
$
15

 
$
14

 
$
9

 
$
23

There were no transfers between Level 3 and Level 2 and there were no significant transfers between Level 2 and Level 1 in the years ended December 31, 2014 and 2013.
Interim Re-Measurement of Other Postretirement Benefit Obligation
In March 2013, the Company reached agreements on new four-year labor contracts with certain represented employees under several bargaining units. As a term of the agreements, the Company replaced the defined benefit employer-sponsored retiree medical, prescription drug and dental coverage for future Medicare eligible retirees and their covered dependents with an allocation to a Retiree Reimbursement Account, when the youngest of the retiree's covered household turns age 65. The amount of the allocation is $3,250 per year for each eligible participant, which increased to $3,315 in 2014. The amount of the allocation will increase each year at the lower of the rate of medical inflation or 2%. The modification in retiree health coverage will reduce future other postretirement benefit costs.
Based on the impact of such benefit cost savings on the Consolidated Financial Statements, the Company re-measured its retiree health plan as of March 31, 2013. In performing the re-measurement, the Company updated its significant actuarial assumptions, including an adjustment to the discount rate from 4.15% at December 31, 2012 to 4.30% at March 31, 2013. Plan assets were also updated to reflect fair value as of the re-measurement date. Beginning April 2013, net other postretirement benefit costs were recorded based on the updated actuarial assumptions and benefit changes resulting from the new labor contracts.
Grantor Trust
DTE Gas maintains a Grantor Trust that invests in life insurance contracts and income securities to fund other postretirement benefit obligations. Employees and retirees have no right, title or interest in the assets of the Grantor Trust, and DTE Gas can revoke the trust subject to providing the MPSC with prior notification. The Company accounts for its investment at fair value, which approximated $18 million and $17 million at December 31, 2014 and 2013, respectively, with unrealized gains and losses recorded to earnings. The Grantor Trust investment is included in Other investments on the Consolidated Statements of Financial Position.
Defined Contribution Plans
The Company also sponsors defined contribution retirement savings plans. Participation in one of these plans is available to substantially all represented and non-represented employees. The Company matches employee contributions up to certain predefined limits based upon eligible compensation, the employee’s contribution rate and, in some cases, years of credited service. The cost of these plans was $48 million, $41 million and $37 million in each of the years 2014, 2013 and 2012, respectively.
Stock-Based Compensation (Notes)
Stock-based Compensation
STOCK-BASED COMPENSATION
The Company’s stock incentive program permits the grant of incentive stock options, non-qualifying stock options, stock awards, performance shares and performance units to employees and members of its Board of Directors. As a result of a stock award, a settlement of an award of performance shares, or by exercise of a participant’s stock option, the Company may deliver common stock from the Company’s authorized but unissued common stock and/or from outstanding common stock acquired by or on behalf of the Company in the name of the participant. Key provisions of the stock incentive program are:
•
Authorized limit is 14,500,000 shares of common stock;
•
Prohibits the grant of a stock option with an exercise price that is less than the fair market value of the Company’s stock on the date of the grant; and
•
Imposes the following award limits to a single participant in a single calendar year, (1) options for more than 500,000 shares of common stock; (2) stock awards for more than 150,000 shares of common stock; (3) performance share awards for more than 300,000 shares of common stock (based on the maximum payout under the award); or (4) more than 1,000,000 performance units, which have a face amount of $1.00 each.
The Company records compensation expense at fair value over the vesting period for all awards it grants.
The following table summarizes the components of stock-based compensation:
 
2014
 
2013
 
2012
 
(In millions)
Stock-based compensation expense
$
103

 
$
99

 
$
83

Tax benefit
40

 
38

 
33

Stock-based compensation cost capitalized in property, plant and equipment
16

 
15

 
5


Stock Options
Options are exercisable according to the terms of the individual stock option award agreements and expire 10 years after the date of the grant. The option exercise price equals the fair value of the stock on the date that the option was granted. Stock options vest ratably over a 3-year period.
The following table summarizes our stock option activity for the year ended December 31, 2014:
 
Number of Options
 
Weighted Average Exercise Price
 
Aggregate Intrinsic
Value
(In millions)
Options outstanding at December 31, 2013
723,697

 
$
42.60

 
 
Granted
—

 
$
—

 
 
Exercised
(268,689
)
 
$
41.14

 
 
Forfeited or expired
(10,730
)
 
$
39.41

 
 
Options outstanding and exercisable at December 31, 2014
444,278

 
$
43.56

 
$
17


As of December 31, 2014, the weighted average remaining contractual life for the exercisable shares is 3.41 years. As of December 31, 2014, all options were vested. No options vested during 2014.
There were no options granted during 2014, 2013 or 2012. The intrinsic value of options exercised for the years ended December 31, 2014, 2013 and 2012 was $11 million, $12 million and $25 million, respectively. Total option expense recognized was zero for 2014 and 2013 and $0.7 million for 2012.
The number, weighted average exercise price and weighted average remaining contractual life of options outstanding were as follows:
Range of Exercise Prices
 
Number of Options
 
Weighted Average
Exercise Price
 
Weighted Average
Remaining Contractual Life (Years)
$
27.00
 —
 
$
38.00

 
25,857

 
$
27.70

 
4.16
$
38.01
 —
 
$
42.00

 
82,834

 
$
41.77

 
3.16
$
42.01
 —
 
$
45.00

 
221,487

 
$
43.93

 
4.06
$
45.01
 —
 
$
50.00

 
114,100

 
$
47.75

 
2.15
 
 
 
 
444,278

 
$
43.56

 
3.41

Restricted Stock Awards
Stock awards granted under the plan are restricted for varying periods, generally for three years. Participants have all rights of a shareholder with respect to a stock award, including the right to receive dividends and vote the shares. Prior to vesting in stock awards, the participant: (i) may not sell, transfer, pledge, exchange or otherwise dispose of shares; (ii) shall not retain custody of the share certificates; and (iii) will deliver to the Company a stock power with respect to each stock award upon request.
The stock awards are recorded at cost that approximates fair value on the date of grant. The cost is amortized to compensation expense over the vesting period.
Stock award activity for the years ended December 31 was:
 
2014
 
2013
 
2012
Fair value of awards vested (in millions)
$
11

 
$
8

 
$
9

Restricted common shares awarded
159,590

 
127,785

 
167,320

Weighted average market price of shares awarded
$
70.09

 
$
64.72

 
$
53.71

Compensation cost charged against income (in millions)
$
10

 
$
23

 
$
12


The following table summarizes the Company’s restricted stock awards activity for the year ended December 31, 2014:
 
Restricted
Stock
 
Weighted Average
Grant Date
Fair Value
Balance at December 31, 2013
492,329

 
$
53.76

Grants
159,590

 
$
70.09

Forfeitures
(16,841
)
 
$
62.41

Vested and issued
(218,760
)
 
$
47.77

Balance at December 31, 2014
416,318

 
$
62.82


Performance Share Awards
Performance shares awarded under the plan are for a specified number of shares of common stock that entitle the holder to receive a cash payment, shares of common stock or a combination thereof. The final value of the award is determined by the achievement of certain performance objectives and market conditions. The awards vest at the end of a specified period, usually three years. Awards granted in 2014 were primarily deemed to be equity awards. The stock price and number of probable shares attributable to market conditions for such equity awards are fair valued only at the grant date. Performance shares awarded prior to 2014 are liability awards and are remeasured to fair value at each reporting period. The Company accounts for performance share awards by accruing compensation expense over the vesting period based on: (i) the number of shares expected to be paid which is based on the probable achievement of performance objectives; and (ii) the closing stock price market value. The settlement of the award is based on the closing price at the settlement date.
The Company recorded compensation expense for performance share awards as follows:
 
2014
 
2013
 
2012
 
(In millions)
Compensation expense
$
93

 
$
77

 
$
71

Cash settlements (a)
$
11

 
$
9

 
$
4

Stock settlements (a)
$
61

 
$
56

 
$
41


_______________________________________
(a)
Sum of cash and stock settlements approximates the intrinsic value of the liability.
During the vesting period, the recipient of a performance share award has no shareholder rights. During the period beginning on the date the performance shares are awarded and ending on the certification date of the performance objectives, the number of performance shares awarded will be increased, assuming full dividend reinvestment at the fair market value on the dividend payment date. The cumulative number of performance shares will be adjusted to determine the final payment based on the performance objectives achieved. Performance share awards are nontransferable and are subject to risk of forfeiture.
The following table summarizes the Company’s performance share activity for the period ended December 31, 2014:
 
 Performance Shares
 
Weighted Average
Grant Date
Fair Value
Balance at December 31, 2013
1,608,789

 
$
—

Grants
561,335

 
$
69.32

Forfeitures
(44,250
)
 
$
69.16

Payouts
(571,177
)
 
$
—

Balance at December 31, 2014
1,554,697

 
$
69.32


Unrecognized Compensation Costs
As of December 31, 2014, the total unrecognized compensation cost related to non-vested stock incentive plan arrangements and the weighted average recognition period was as follows:
 
Unrecognized
Compensation
Cost
 
Weighted Average
to be Recognized
 
(In millions)
 
(In years)
Stock awards
$
10

 
1.06
Performance shares
48

 
0.98
 
$
58

 
0.99
Segment and Related Information (Notes)
Segment and Related Information
SEGMENT AND RELATED INFORMATION
The Company sets strategic goals, allocates resources and evaluates performance based on the following structure:
Electric segment consists principally of DTE Electric, which is engaged in the generation, purchase, distribution and sale of electricity to approximately 2.1 million residential, commercial and industrial customers in southeastern Michigan.
Gas segment consists principally of DTE Gas, which is engaged in the purchase, storage, transportation, distribution and sale of natural gas to approximately 1.2 million residential, commercial and industrial customers throughout Michigan and the sale of storage and transportation capacity.
Gas Storage and Pipelines consists of natural gas pipeline, gathering and storage businesses.
Power and Industrial Projects is comprised primarily of projects that deliver energy and utility-type products and services to industrial, commercial and institutional customers; produce REF and sell electricity from renewable energy projects.
Energy Trading consists of energy marketing and trading operations.
Corporate and Other, includes various holding company activities, holds certain non-utility debt and energy-related investments.
The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of production tax credits and net operating losses if applicable. The state and local income tax provisions of the utility subsidiaries are determined on an individual company basis and recognize the tax benefit of various tax credits and net operating losses, if applicable. The subsidiaries record federal, state and local income taxes payable to or receivable from DTE Energy based on the federal, state and local tax provisions of each company.
Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales and natural gas sales in the following segments:
 
2014
 
2013
 
2012
 
(In millions)
Electric
$
29

 
$
26

 
$
29

Gas
6

 
4

 
4

Power and Industrial Projects
794

 
816

 
801

Gas Storage and Pipelines
9

 
3

 
6

Energy Trading
33

 
43

 
43

Corporate and Other
3

 
(24
)
 
(37
)
Discontinued Operations
—

 
—

 
2

 
$
874

 
$
868

 
$
848


Financial data of the business segments follows:
 
Operating
Revenue
 
Depreciation,
Depletion &
Amortization
 
Interest
Income
 
Interest
Expense
 
Income
Tax Expense (Benefit)
 
Net Income (Loss)
Attributable
to DTE
Energy
Company
 
Total
Assets
 
Goodwill
 
Capital
Expenditures and Acquisitions
 
(In millions)
2014
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric
$
5,283

 
$
933

 
$
(1
)
 
$
250

 
$
296

 
$
528

 
$
18,715

 
$
1,208

 
$
1,561

Gas
1,636

 
99

 
(7
)
 
57

 
78

 
140

 
4,283

 
743

 
224

Power and Industrial Projects
2,289

 
77

 
(5
)
 
28

 
(100
)
 
90

 
1,009

 
26

 
77

Gas Storage and Pipelines
203

 
34

 
(6
)
 
22

 
53

 
82

 
884

 
24

 
184

Energy Trading
3,762

 
1

 
—

 
7

 
77

 
122

 
755

 
17

 
3

Corporate and Other
2

 
1

 
(48
)
 
122

 
(40
)
 
(57
)
 
3,209

 
—

 
—

Reclassifications and Eliminations
(874
)
 
—

 
57

 
(57
)
 
—

 
—

 
(881
)
 
—

 
—

Total
$
12,301

 
$
1,145

 
$
(10
)
 
$
429

 
$
364

 
$
905

 
$
27,974

 
$
2,018

 
$
2,049

 
Operating
Revenue
 
Depreciation,
Depletion &
Amortization
 
Interest
Income
 
Interest
Expense
 
Income
Tax Expense (Benefit)
 
Net Income (Loss)
Attributable
to DTE
Energy
Company
 
Total
Assets
 
Goodwill
 
Capital
Expenditures and Acquisitions
 
(In millions)
2013
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric
$
5,199

 
$
902

 
$
(1
)
 
$
268

 
$
252

 
$
484

 
$
17,508

 
$
1,208

 
$
1,325

Gas
1,474

 
95

 
(7
)
 
58

 
77

 
143

 
3,938

 
743

 
209

Power and Industrial Projects
1,950

 
72

 
(6
)
 
27

 
(45
)
 
66

 
1,067

 
26

 
93

Gas Storage and Pipelines
132

 
23

 
(7
)
 
18

 
45

 
70

 
824

 
24

 
245

Energy Trading
1,771

 
1

 
—

 
8

 
(38
)
 
(58
)
 
623

 
17

 
3

Corporate and Other
3

 
1

 
(51
)
 
120

 
(37
)
 
(44
)
 
2,945

 
—

 
1

Reclassifications and Eliminations
(868
)
 
—

 
63

 
(63
)
 
—

 
—

 
(970
)
 
—

 
—

Total
$
9,661

 
$
1,094

 
$
(9
)
 
$
436

 
$
254

 
$
661

 
$
25,935

 
$
2,018

 
$
1,876

 
Operating
Revenue
 
Depreciation,
Depletion &
Amortization
 
Interest
Income
 
Interest
Expense
 
Income
Tax Expense (Benefit)
 
Net Income (Loss)
Attributable
to DTE
Energy
Company
 
Total
Assets
 
Goodwill
 
Capital
Expenditures and Acquisitions
 
(In millions)
2012
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric
$
5,293

 
$
827

 
$
(1
)
 
$
272

 
$
280

 
$
483

 
$
17,755

 
$
1,208

 
$
1,230

Gas
1,315

 
92

 
(7
)
 
59

 
50

 
115

 
4,059

 
745

 
221

Power and Industrial Projects
1,823

 
65

 
(7
)
 
37

 
(44
)
 
42

 
991

 
26

 
281

Gas Storage and Pipelines
96

 
8

 
(8
)
 
8

 
39

 
61

 
668

 
22

 
233

Energy Trading
1,109

 
2

 
—

 
8

 
7

 
12

 
629

 
17

 
1

Corporate and Other
3

 
1

 
(52
)
 
121

 
(46
)
 
(47
)
 
3,074

 
—

 
3

Reclassifications and Eliminations
(848
)
 
—

 
65

 
(65
)
 
—

 
—

 
(837
)
 
—

 
—

Total from Continuing Operations
$
8,791

 
$
995

 
$
(10
)
 
$
440

 
$
286

 
$
666

 
$
26,339

 
$
2,018

 
$
1,969

Discontinued Operations (Note 4)
 
 
 
 
 
 
 
 
 
 
(56
)
 
—

 
—

 
49

Total
 
 
 
 
 
 
 
 
 
 
$
610

 
$
26,339

 
$
2,018

 
$
2,018

Supplementary Quarterly Financial Information (Unaudited)
Supplemental Quarterly Financial Information (Unaudited)
SUPPLEMENTARY QUARTERLY FINANCIAL INFORMATION (UNAUDITED)
Quarterly earnings per share may not equal full year totals, since quarterly computations are based on weighted average common shares outstanding during each quarter.
 
First
Quarter
 
Second
Quarter
 
Third
Quarter
 
Fourth
Quarter
 
Year
 
(In millions, except per share amounts)
2014
 

 
 

 
 

 
 

 
 

Operating Revenues
$
3,930

 
$
2,698

 
$
2,595

 
$
3,078

 
$
12,301

Operating Income
$
560

 
$
249

 
$
239

 
$
542

 
$
1,590

Net Income Attributable to DTE Energy Company
$
326

 
$
124

 
$
156

 
$
299

 
$
905

Basic Earnings per Share
$
1.84

 
$
0.70

 
$
0.88

 
$
1.68

 
$
5.11

Diluted Earnings per Share
$
1.84

 
$
0.70

 
$
0.88

 
$
1.68

 
$
5.10

2013
 

 
 

 
 

 
 

 
 

Operating Revenues
$
2,516

 
$
2,225

 
$
2,387

 
$
2,533

 
$
9,661

Operating Income
$
410

 
$
223

 
$
329

 
$
241

 
$
1,203

Net Income Attributable to DTE Energy Company
$
234

 
$
105

 
$
198

 
$
124

 
$
661

Basic Earnings per Share
$
1.35

 
$
0.60

 
$
1.13

 
$
0.70

 
$
3.76

Diluted Earnings per Share
$
1.34

 
$
0.60

 
$
1.13

 
$
0.70

 
$
3.76

Subsequent Event (Notes)
Subsequent Event
SUBSEQUENT EVENT
In October 2014, DTE Electric executed an agreement to purchase a 732 MW simple-cycle natural gas facility in Carson City, Michigan from The LS Power Group for a total purchase price of approximately $240 million paid in cash. This facility will serve to meet the needs of approximately 260,000 additional households during peak demand. DTE Electric closed on the acquisition on January 21, 2015.
Effective upon closing, DTE Electric obtained control over and applied acquisition accounting to the acquired business. Due to the limited time since the acquisition date, the initial accounting for the business combination is incomplete. As a result, DTE Electric is unable to provide amounts recognized as of the acquisition date for major classes of assets and liabilities acquired. DTE Electric will include required information in the Quarterly Report on Form 10-Q for the period ending March 31, 2015.
Valuation and Qualifying Accounts (Notes)
Schedule II Valuation and Qualifying Accounts
Valuation and Qualifying Accounts
 
Year Ending December 31,
 
2014
 
2013
 
2012
 
(In millions)
Allowance for Doubtful Accounts (shown as deduction from Accounts Receivable in the Consolidated Statements of Financial Position)
 
 
 
 
 
Balance at Beginning of Period
$
55

 
$
62

 
$
162

Additions:
 
 
 
 
 
Charged to costs and expenses
95

 
94

 
79

Charged to other accounts (a)
20

 
23

 
16

Deductions (b)
(116
)
 
(124
)
 
(195
)
Balance at End of Period
$
54

 
$
55

 
$
62

_______________________________________
(a)
Collection of accounts previously written off.
(b)
Uncollectible accounts written off.
Significant Accounting Policies (Policies)
Basis of Presentation 
Basis of Presentation
The accompanying Consolidated Financial Statements are prepared using accounting principles generally accepted in the United States of America. These accounting principles require management to use estimates and assumptions that impact reported amounts of assets, liabilities, revenues and expenses, and the disclosure of contingent assets and liabilities. Actual results may differ from the Company’s estimates.
Principles of Consolidation 
Principles of Consolidation
The Company consolidates all majority-owned subsidiaries and investments in entities in which it has controlling influence. Non-majority owned investments are accounted for using the equity method when the Company is able to influence the operating policies of the investee. When the Company does not influence the operating policies of an investee, the cost method is used. These Consolidated Financial Statements also reflect the Company's proportionate interests in certain jointly owned utility plants. The Company eliminates all intercompany balances and transactions.
The Company evaluates whether an entity is a VIE whenever reconsideration events occur. The Company consolidates VIEs for which it is the primary beneficiary. If the Company is not the primary beneficiary and an ownership interest is held, the VIE is accounted for under the equity method of accounting. When assessing the determination of the primary beneficiary, the Company considers all relevant facts and circumstances, including: the power, through voting or similar rights, to direct the activities of the VIE that most significantly impact the VIE's economic performance and the obligation to absorb the expected losses and/or the right to receive the expected returns of the VIE. The Company performs ongoing reassessments of all VIEs to determine if the primary beneficiary status has changed.
Legal entities within the Company's Power and Industrial Projects segment enter into long-term contractual arrangements with customers to supply energy-related products or services. The entities are generally designed to pass-through the commodity risk associated with these contracts to the customers, with the Company retaining operational and customer default risk. These entities generally are VIEs and consolidated when the Company is the primary beneficiary. In addition, we have interests in certain VIEs through which we share control of all significant activities for those entities with our partners, and therefore are accounted for under the equity method.
The Company has variable interests in VIEs through certain of its long-term purchase and sale contracts. As of December 31, 2014, the carrying amount of assets and liabilities in the Consolidated Statements of Financial Position that relate to its variable interests under long-term purchase and sale contracts are predominately related to working capital accounts and generally represent the amounts owed by or to 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 and sale contracts.
In 2001, DTE Electric financed a regulatory asset related to Fermi 2 and certain other regulatory assets through the sale of rate reduction bonds by a wholly-owned special purpose entity, Securitization. DTE Electric performs servicing activities including billing and collecting surcharge revenue for Securitization. This entity is a VIE and is consolidated by the Company.
The maximum risk exposure for consolidated VIEs is reflected on the Company's Consolidated Statements of Financial Position. For non-consolidated VIEs, the maximum risk exposure is generally limited to its investment and amounts which it has guaranteed.
The following table summarizes the major balance sheet items for consolidated VIEs as of December 31, 2014 and 2013. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. VIEs, in which the Company holds a majority voting interest and is the primary beneficiary, that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIE's obligations have been excluded from the table below.
Revenues 
Revenues
Revenues from the sale and delivery of electricity, and the sale, delivery and storage of natural gas are recognized as services are provided. DTE Electric and DTE Gas record revenues for electricity and gas provided but unbilled at the end of each month. Rates for DTE Electric and DTE Gas include provisions to adjust billings for fluctuations in fuel and purchased power costs, cost of natural gas and certain other costs. Revenues are adjusted for differences between actual costs subject to reconciliation and the amounts billed in current rates. Under or over recovered revenues related to these cost recovery mechanisms are recorded on the Consolidated Statements of Financial Position and are recovered or returned to customers through adjustments to the billing factors.
For further discussion of recovery mechanisms authorized by the MPSC see Note 8 to the Consolidated Financial Statements, "Regulatory Matters".
Non-utility businesses recognize revenues as services are provided and products are delivered. For discussion of derivative contracts see Note 12 to the Consolidated Financial Statements, "Financial and Other Derivative Instruments".
Accounting For ISO Transactions 
Accounting for ISO Transactions
DTE Electric participates in the energy market through MISO. MISO requires that we submit hourly day-ahead, real- time and FTR bids and offers for energy at locations across the MISO region. DTE Electric accounts for MISO transactions on a net hourly basis in each of the day-ahead, real-time and FTR markets and net transactions across all MISO energy market locations. In any single hour DTE Electric records net purchases in Fuel, purchased power and gas and net sales in Operating revenues on the Consolidated Statements of Operations.
Energy Trading participates in the energy markets through various independent system operators and regional transmission organizations (ISOs and RTOs). These markets require that Energy Trading submits hourly day-ahead, real-time bids and offers for energy at locations across each region. Energy Trading submits bids in the annual and monthly auction revenue rights and FTR auctions to the regional transmission organizations. Energy Trading accounts for these transactions on a net hourly basis for the day-ahead, real-time and FTR markets. These transactions are related to trading contracts which are presented on a net basis in Operating Revenues in the Consolidated Statements of Operations.
DTE Electric and Energy Trading record accruals for future net purchases adjustments based on historical experience, and reconcile accruals to actual costs when invoices are received from MISO, and other ISOs and RTOs.
Changes in Accumulated Other Comprehensive Loss 
Changes in Accumulated Other Comprehensive Loss
Comprehensive income (loss) is the change in common shareholders’ equity during a period from transactions and events from non-owner sources, including net income. The amounts recorded to accumulated other comprehensive loss include unrealized gains and losses from derivatives accounted for as cash flow hedges, unrealized gains and losses on available-for-sale securities and the Company’s interest in other comprehensive income of equity investees, which comprise the net unrealized gains and losses on investments, changes in benefit obligations, consisting of deferred actuarial losses, prior service costs, and foreign currency translation adjustments.
Cash, Cash Equivalents and Restricted Cash 
Cash, Cash Equivalents and Restricted Cash
Cash and cash equivalents include cash on hand, cash in banks and temporary investments purchased with remaining maturities of three months or less. Restricted cash consists of funds held to satisfy requirements of certain debt, primarily Securitization bonds, and partnership operating agreements. Restricted cash designated for interest and principal payments within one year is classified as a current asset.
Receivables 
Receivables
Accounts receivable are primarily composed of trade receivables and unbilled revenue. Our accounts receivable are stated at net realizable value.
The allowance for doubtful accounts for DTE Electric and DTE Gas is generally calculated using the aging approach that utilizes rates developed in reserve studies. We establish an allowance for uncollectible accounts based on historical losses and management’s assessment of existing economic conditions, customer trends, and other factors. Customer accounts are generally considered delinquent if the amount billed is not received by the due date, which is typically in 21 days, however, factors such as assistance programs may delay aggressive action. We assess late payment fees on trade receivables based on past-due terms with customers. Customer accounts are written off when collection efforts have been exhausted. The time period for write-off is 150 days after service has been terminated.
The customer allowance for doubtful accounts for our other businesses is calculated based on specific review of probable future collections based on receivable balances in excess of 30 days.
Unbilled revenues of $773 million and $815 million are included in customer accounts receivable at December 31, 2014 and 2013, respectively.
Notes Receivable
Notes receivable, or financing receivables, are primarily comprised of capital lease receivables and loans and are included in Notes receivable and Other current assets on the Company’s Consolidated Statements of Financial Position.
Notes receivable are typically considered delinquent when payment is not received for periods ranging from 60 to 120 days. The Company ceases accruing interest (nonaccrual status), considers a note receivable impaired, and establishes an allowance for credit loss when it is probable that all principal and interest amounts due will not be collected in accordance with the contractual terms of the note receivable. Cash payments received on nonaccrual status notes receivable, that do not bring the account contractually current, are first applied to contractually owed past due interest, with any remainder applied to principal. Accrual of interest is generally resumed when the note receivable becomes contractually current.
In determining the allowance for credit losses for notes receivable, we consider the historical payment experience and other factors that are expected to have a specific impact on the counterparty’s ability to pay. In addition, the Company monitors the credit ratings of the counterparties from which we have notes receivable.
Inventories 
Inventories
The Company generally values inventory at average cost.
Natural gas inventory of $43 million and $4 million as of December 31, 2014 and 2013, respectively, at DTE Gas is determined using the last-in, first-out (LIFO) method. At December 31, 2014, the replacement cost of gas remaining in storage exceeded the LIFO cost by $110 million. At December 31, 2013, the replacement cost of gas remaining in storage exceeded the LIFO cost by $170 million.
Property, Retirement and Maintenance, Depreciation, Depletion and Amortization 
Property, Retirement and Maintenance, and Depreciation, Depletion and Amortization
Property is stated at cost and includes construction-related labor, materials, overheads and AFUDC for utility property. The cost of utility properties retired is charged to accumulated depreciation. Expenditures for maintenance and repairs are charged to expense when incurred, except for Fermi 2.
Utility property at DTE Electric and DTE Gas is depreciated over its estimated useful life using straight-line rates approved by the MPSC.
Non-utility property is depreciated over its estimated useful life using the straight-line and units of production methods.
Depreciation, depletion and amortization expense also includes the amortization of certain regulatory assets.
Approximately $16 million and $26 million of expenses related to Fermi 2 refueling outages were accrued at December 31, 2014 and 2013, respectively. Amounts are accrued on a pro-rata basis, generally over an 18-month period, that coincides with scheduled refueling outages at Fermi 2. This accrual of outage costs matches the regulatory recovery of these costs in rates set by the MPSC. See Note 8 to the Consolidated Financial Statements, "Regulatory Matters".
The cost of nuclear fuel is capitalized. The amortization of nuclear fuel is included within Fuel, purchased power, and gas in the Consolidated Statements of Operations and is recorded using the units-of-production method.
Capitalized software costs are classified as Property, plant and equipment and the related amortization is included in Accumulated depreciation, depletion and amortization on the Consolidated Statements of Financial Position. The Company capitalizes the costs associated with computer software it develops or obtains for use in its business. The Company amortizes capitalized software costs on a straight-line basis over the expected period of benefit, ranging from 3 to 15 years.
Long-Lived Assets 
Long-Lived Assets
Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of an asset may not be recoverable. If the carrying amount of the asset exceeds the expected discounted future cash flows generated by the asset, an impairment loss is recognized resulting in the asset being written down to its estimated fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value, less costs to sell.
Intangible Assets 
Emission allowances and renewable energy credits are charged to expense, using average cost, as the allowances and credits are consumed in the operation of the business. The Company amortizes contract intangible assets on a straight-line basis over the expected period of benefit, ranging from 1 to 27 years.
Deferred Debt Costs 
Deferred Debt Costs
The costs related to the issuance of long-term debt are deferred and amortized over the life of each debt issue. In accordance with MPSC regulations applicable to the Company’s electric and gas utilities, the unamortized discount, premium and expense related to utility debt redeemed with a refinancing are amortized over the life of the replacement issue. Discount, premium and expense on early redemptions of debt associated with non-utility operations are charged to earnings.
Investments in Debt and Equity Securities 
Investments in Debt and Equity Securities
The Company generally classifies investments in debt and equity securities as either trading or available-for-sale and has recorded such investments at market value with unrealized gains or losses included in earnings or in other comprehensive income or loss, respectively. Changes in the fair value of Fermi 2 nuclear decommissioning investments are recorded as adjustments to regulatory assets or liabilities, due to a recovery mechanism from customers. The Company’s equity investments are reviewed for impairment each reporting period. If the assessment indicates that the impairment is other than temporary, a loss is recognized resulting in the equity investment being written down to its estimated fair value. See Note 11 of the Consolidated Financial Statements, "Fair Value".
Government Grants 
Government Grants
Grants are recognized when there is reasonable assurance that the grant will be received and that any conditions associated with the grant will be met. When grants are received related to Property, plant and equipment, the Company reduces the cost of the assets on the Consolidated Statements of Financial Position, resulting in lower depreciation expense over the life of the associated asset. Grants received related to expenses are reflected as a reduction of the associated expense in the period in which the expense is incurred.
Foundation Related Party 
The DTE Energy Foundation is a non-consolidated not-for-profit private foundation, the purpose of which is to contribute to and assist charitable organizations
Asset Retirement Obligations 
The Company has a legal retirement obligation for the decommissioning costs for its Fermi 1 and Fermi 2 nuclear plants, dismantlement of facilities located on leased property and various other operations. The Company has conditional retirement obligations for gas pipelines, asbestos and PCB removal at certain of its power plants and various distribution equipment. The Company recognizes such obligations as liabilities at fair market value when they are incurred, which generally is at the time the associated assets are placed in service. Fair value is measured using expected future cash outflows discounted at our credit-adjusted risk-free rate. In its regulated operations, the Company recognizes regulatory assets or liabilities for timing differences in expense recognition for legal asset retirement costs that are currently recovered in rates.
If a reasonable estimate of fair value cannot be made in the period in which the retirement obligation is incurred, such as for assets with indeterminate lives, the liability is recognized when a reasonable estimate of fair value can be made. Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets.
Regulatory Matters 
DTE Electric and DTE Gas are required to record regulatory assets and liabilities for certain transactions that would have been treated as revenue or expense in non-regulated businesses. Continued applicability of regulatory accounting treatment requires that rates be designed to recover specific costs of providing regulated services and be charged to and collected from customers. Future regulatory changes or changes in the competitive environment could result in the discontinuance of this accounting treatment for regulatory assets and liabilities for some or all of our businesses and may require the write-off of the portion of any regulatory asset or liability that was no longer probable of recovery through regulated rates. Management believes that currently available facts support the continued use of regulatory assets and liabilities and that all regulatory assets and liabilities are recoverable or refundable in the current regulatory environment.
Income Taxes 

Excise and Sales Taxes
The Company records the billing of excise and sales taxes as a receivable with an offsetting payable to the applicable taxing authority, with no net impact on the Consolidated Statements of Operations.
Deferred tax assets and liabilities are recognized for the estimated future tax effect of temporary differences between the tax basis of assets or liabilities and the reported amounts in the financial statements. Deferred tax assets and liabilities are classified as current or noncurrent according to the classification of the related assets or liabilities. Deferred tax assets and liabilities not related to assets or liabilities are classified according to the expected reversal date of the temporary differences. Consistent with rate making treatment, deferred taxes are offset in the table below for temporary differences which have related regulatory assets and liabilities.
The federal income tax provisions or benefits of DTE Energy’s subsidiaries are determined on an individual company basis and recognize the tax benefit of production tax credits and net operating losses if applicable. The state and local income tax provisions of the utility subsidiaries are determined on an individual company basis and recognize the tax benefit of various tax credits and net operating losses, if applicable. The subsidiaries record federal, state and local income taxes payable to or receivable from DTE Energy based on the federal, state and local tax provisions of each company.
Fair Value Measurement 
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or liabilities. These inputs can be readily observable, market corroborated or generally unobservable inputs. The Company makes certain assumptions it believes that market participants would use in pricing assets or liabilities, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. Credit risk of the Company and its counterparties is incorporated in the valuation of assets and liabilities through the use of credit reserves, the impact of which was immaterial at December 31, 2014 and 2013. The Company believes it uses valuation techniques that maximize the use of observable market-based inputs and minimize the use of unobservable inputs.
A fair value hierarchy has been established that prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The fair value hierarchy gives the highest priority to quoted prices (unadjusted) in active markets for identical assets or liabilities (Level 1) and the lowest priority to unobservable inputs (Level 3). In some cases, the inputs used to measure fair value might fall in different levels of the fair value hierarchy. All assets and liabilities are required to be classified in their entirety based on the lowest level of input that is significant to the fair value measurement in its entirety. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and its placement within the fair value hierarchy. The Company classifies fair value balances based on the fair value hierarchy defined as follows:
•
Level 1 — Consists of unadjusted quoted prices in active markets for identical assets or liabilities that the Company has the ability to access as of the reporting date.
•
Level 2 — Consists of inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.
•
Level 3 — Consists of unobservable inputs for assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost-benefit constraints.
Nuclear Decommissioning Trust and Other Investments 
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 NAVs. Non-exchange-traded fixed income securities are valued based upon quotations available from brokers or pricing services. A primary price source is identified by asset type, class or issue for each security. The trustee monitors prices supplied by pricing services and may use a supplemental price source or change the primary price source of a given security if the trustee determines that another price source is considered to be preferable. DTE Energy has obtained an understanding of how these prices are derived, including the nature and observability of the inputs used in deriving such prices. Additionally, DTE Energy selectively corroborates the fair value of securities by comparison of market-based price sources. Investment policies and procedures are determined by the Company's Trust Investments Department which reports to the Company's Vice President and Treasurer.
Derivatives Reporting of Derivative Activity 
Derivative assets and liabilities are comprised of physical and financial derivative contracts, including futures, forwards, options and swaps that are both exchange-traded and over-the-counter traded contracts. Various inputs are used to value derivatives depending on the type of contract and availability of market data. Exchange-traded derivative contracts are valued using quoted prices in active markets. DTE Energy considers the following criteria in determining whether a market is considered active: frequency in which pricing information is updated, variability in pricing between sources or over time and the availability of public information. Other derivative contracts are valued based upon a variety of inputs including commodity market prices, broker quotes, interest rates, credit ratings, default rates, market-based seasonality and basis differential factors. DTE Energy monitors the prices that are supplied by brokers and pricing services and may use a supplemental price source or change the primary price source of an index if prices become unavailable or another price source is determined to be more representative of fair value. DTE Energy has obtained an understanding of how these prices are derived. Additionally, DTE Energy selectively corroborates the fair value of its transactions by comparison of market-based price sources. Mathematical valuation models are used for derivatives for which external market data is not readily observable, such as contracts which extend beyond the actively traded reporting period. The Company has established a Risk Management Committee whose responsibilities include directly or indirectly ensuring all valuation methods are applied in accordance with predefined policies. The development and maintenance of our forward price curves has been assigned to our Risk Management Department, which is separate and distinct from the trading functions within the Company.
Fair Value Transfer 
Derivatives are transferred between levels primarily due to changes in the source data used to construct price curves as a result of changes in market liquidity. Transfers in and transfers out are reflected as if they had occurred at the beginning of the period.
Fair Value of Financial Instruments 
The fair value of financial instruments included in the table below is determined by using quoted market prices when available. When quoted prices are not available, pricing services may be used to determine the fair value with reference to observable interest rate indexes. DTE Energy has obtained an understanding of how the fair values are derived. DTE Energy also selectively corroborates the fair value of its transactions by comparison of market-based price sources. Discounted cash flow analyses based upon estimated current borrowing rates are also used to determine fair value when quoted market prices are not available. The fair values of notes receivable, excluding capital leases, are estimated using discounted cash flow techniques that incorporate market interest rates as well 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 DTE Energy's Treasury Department which reports to the Company's Vice President and Treasurer.
Derivatives 
The Company recognizes all derivatives at their fair value as Derivative assets or liabilities on the Consolidated Statements of Financial Position unless they qualify for certain scope exceptions, including the normal purchases and normal sales exception. Further, derivatives that qualify and are designated for hedge accounting are classified as either hedges of a forecasted transaction or the variability of cash flows to be received or paid related to a recognized asset or liability (cash flow hedge), or as hedges of the fair value of a recognized asset or liability or of an unrecognized firm commitment (fair value hedge). For cash flow hedges, the portion of the derivative gain or loss that is effective in offsetting the change in the value of the underlying exposure is deferred in Accumulated other comprehensive income and later reclassified into earnings when the underlying transaction occurs. Gains or losses from the ineffective portion of cash flow hedges are recognized in earnings immediately. For fair value hedges, changes in fair values for the derivative and hedged item are recognized in earnings each period. For derivatives that do not qualify or are not designated for hedge accounting, changes in the fair value are recognized in earnings each period.
The Company’s primary market risk exposure is associated with commodity prices, credit and interest rates. The Company has risk management policies to monitor and manage market risks. The Company uses derivative instruments to manage some of the exposure. The Company uses derivative instruments for trading purposes in its Energy Trading segment. Contracts classified as derivative instruments include electricity, natural gas, oil and certain coal forwards, futures, options and swaps, and foreign currency exchange contracts. Items not classified as derivatives include natural gas inventory, pipeline transportation contracts, renewable energy credits and natural gas storage assets.
Derivatives, Offsetting Fair Value Amounts 
Certain of the Company's derivative positions are subject to netting arrangements which provide for offsetting of asset and liability positions as well as related cash collateral. Such netting arrangements generally do not have restrictions. Under such netting arrangements, the Company offsets the fair value of derivative instruments with cash collateral received or paid for those contracts executed with the same counterparty, which reduces the Company's total assets and liabilities. Cash collateral is allocated between the fair value of derivative instruments and customer accounts receivable and payable with the same counterparty on a pro rata basis to the extent there is exposure. Any cash collateral remaining, after the exposure is netted to zero, is reflected in accounts receivable and accounts payable as collateral paid or received, respectively.
The Company also provides and receives collateral in the form of letters of credit which can be offset against net derivative assets and liabilities as well as accounts receivable and payable. The Company had issued letters of credit of approximately $7 million and $19 million at December 31, 2014 and 2013, respectively, which could be used to offset net derivative liabilities. Letters of credit received from third parties which could be used to offset our net derivative assets were approximately $5 million and $1 million at December 31, 2014 and 2013, respectively. Such balances of letters of credit are excluded from the tables below and are not netted with the recognized assets and liabilities in the Consolidated Statements of Financial Position.
For contracts with certain clearing agents the fair value of derivative instruments is netted against realized positions with the net balance reflected as either 1) a derivative asset or liability or 2) an account receivable or payable. Other than certain clearing agents, accounts receivable and accounts payable that are subject to netting arrangements have not been offset against the fair value of derivative assets and liabilities. Certain contracts that have netting arrangements have not been offset in the Consolidated Statements of Financial Position. The impact of netting these derivative instruments and cash collateral related to such contracts is not material. Only the gross amounts for these derivative instruments are included in the table below.
Derivatives, Methods of Accounting, Derivatives Not Designated or Qualifying as Hedges 
Revenues and energy costs related to trading contracts are presented on a net basis in the Consolidated Statements of Operations. Commodity derivatives used for trading purposes, and financial non-trading commodity derivatives, are accounted for using the MTM method with unrealized and realized gains and losses recorded in Operating revenues. Non-trading physical commodity sale and purchase derivative contracts are generally accounted for using the MTM method with unrealized and realized gains and losses for sales recorded in Operating revenue and purchases recorded in Fuel, purchased power and gas.
Stock-Based Compensation 
The Company records compensation expense at fair value over the vesting period for all awards it grants.
Organization and Basis of Presentation (Tables)
Schedule of Variable Interest Entities 
The following table summarizes the major balance sheet items for consolidated VIEs as of December 31, 2014 and 2013. All assets and liabilities of a consolidated VIE are presented where it has been determined that a consolidated VIE has either (1) assets that can be used only to settle obligations of the VIE or (2) liabilities for which creditors do not have recourse to the general credit of the primary beneficiary. VIEs, in which the Company holds a majority voting interest and is the primary beneficiary, that meet the definition of a business and whose assets can be used for purposes other than the settlement of the VIE's obligations have been excluded from the table below.
 
December 31, 2014
 
December 31, 2013
 
Securitization
 
Other
 
Total
 
Securitization
 
Other
 
Total
 
(In millions)
ASSETS
 
 
 
 
 
 
 
 
 
 
 
Cash and cash equivalents
$
—

 
$
7

 
$
7

 
$
—

 
$
12

 
$
12

Restricted cash
96

 
8

 
104

 
100

 
8

 
108

Accounts receivable
26

 
15

 
41

 
34

 
16

 
50

Inventories
—

 
67

 
67

 
—

 
118

 
118

Property, plant and equipment, net
—

 
81

 
81

 
—

 
99

 
99

Securitized regulatory assets
34

 
—

 
34

 
231

 
—

 
231

Other current and long-term assets
1

 
6

 
7

 
4

 
9

 
13

 
$
157

 
$
184

 
$
341

 
$
369

 
$
262

 
$
631

LIABILITIES
 
 
 
 
 
 
 
 
 
 
 
Accounts payable and accrued current liabilities
$
3

 
$
8

 
$
11

 
$
7

 
$
23

 
$
30

Current portion long-term debt, including capital leases
105

 
10

 
115

 
196

 
9

 
205

Current regulatory liabilities
32

 
—

 
32

 
43

 
—

 
43

Mortgage bonds, notes and other
—

 
15

 
15

 
—

 
21

 
21

Securitization bonds
—

 
—

 
—

 
105

 
—

 
105

Capital lease obligations
—

 
3

 
3

 
—

 
7

 
7

Other current and long-term liabilities
9

 
6

 
15

 
8

 
6

 
14

 
$
149

 
$
42

 
$
191

 
$
359

 
$
66

 
$
425


Summary of Amounts For Nonconsolidated Variable Interest Entities 
Amounts for non-consolidated VIEs as of December 31, 2014 and 2013 are as follows:
 
December 31, 2014
 
December 31, 2013
 
(In millions)
Other investments
$
134

 
$
141

Notes receivable
$
15

 
$
8

Significant Accounting Policies (Tables)
Schedule of Accumulated Other Comprehensive Income (Loss) 
The following table summarizes the changes in Accumulated other comprehensive loss by component for the years ended December 31, 2014 and 2013:
 
Changes in Accumulated Other Comprehensive Loss by Component (a)
 
Net
Unrealized
Gain/(Loss)
on Derivatives
 
Net
Unrealized
Gain/(Loss)
on Investments
 
Benefit
Obligations
(b)
 
Foreign
Currency
Translation
 
Total
 
(In millions)
Balance, January 1, 2013
$
(4
)
 
$
(8
)
 
$
(148
)
 
$
2

 
$
(158
)
Other comprehensive income (loss) before reclassifications
—

 
2

 
13

 
(2
)
 
13

Amounts reclassified from accumulated other comprehensive income
—

 
—

 
9

 
—

 
9

Net current-period other comprehensive income (loss)
—

 
2


22


(2
)

22

Balance, December 31, 2013
$
(4
)
 
$
(6
)

$
(126
)

$
—


$
(136
)
Other comprehensive income (loss) before reclassifications
—

 
1

 
(25
)
 
(2
)
 
(26
)
Amounts reclassified from accumulated other comprehensive income
—

 
—

 
7

 
—

 
7

Net current-period other comprehensive income (loss)
—

 
1


(18
)

(2
)

(19
)
Balance, December 31, 2014
$
(4
)
 
$
(5
)

$
(144
)

$
(2
)

$
(155
)
______________________________________
(a)All amounts are net of tax.
(b)
The amounts reclassified from accumulated other comprehensive income (loss) are included in the computation of the net periodic pension and other postretirement benefit costs (see Note 18 to the Consolidated Financial Statements "Retirement Benefits and Trusteed Assets").
Schedule of Finite-Lived Intangible Assets by Major Class 
The Company has certain intangible assets relating to emission allowances, renewable energy credits and non-utility contracts as shown below:
 
December 31, 2014
 
December 31, 2013
 
(In millions)
Emission allowances
$
1

 
$
2

Renewable energy credits
45

 
51

Contract intangible assets
122

 
126

 
168

 
179

Less accumulated amortization
57

 
45

Intangible assets, net
111

 
134

Less current intangible assets
9

 
12

 
$
102

 
$
122

Schedule of Finite-Lived Intangible Assets, Future Amortization Expense 
The following table summarizes the estimated amortization expense expected to be recognized during each year through 2019:
Estimated amortization expense
(In millions)
2015
$
12

2016
$
11

2017
$
8

2018
$
8

2019
$
6

Discontinued Operations (Tables)
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures
The activity of the discontinued business is shown below. The amounts exclude general corporate overhead costs, and related tax effects, and no portion of corporate interest costs were allocated to discontinued operations.
 
2012
 
(In millions)
Operating Revenues
$
55

 
 
Operation and maintenance
24

Depreciation, depletion and amortization
23

Taxes other than income
4

Asset (gains) losses, net
83

 
134

Operating Loss
(79
)
Other (Income) and Deductions
6

Loss Before Income Taxes
(85
)
Income Tax Benefit
(29
)
Net Loss Attributable to DTE Energy Company
$
(56
)
Property, Plant and Equipment (Tables)
Schedule of Property, Plant and Equipment
Summary of property by classification as of December 31:
 
2014
 
2013
 
(In millions)
Property, Plant and Equipment
 
 
 
DTE Electric
 
 
 
Generation
$
11,641

 
$
11,127

Distribution
8,164

 
7,603

Total DTE Electric
19,805

 
18,730

DTE Gas
 
 
 
Distribution
2,946

 
2,834

Storage
448

 
431

Other
863

 
836

Total DTE Gas
4,257

 
4,101

Non-utility and other
2,476

 
2,292

Total
26,538

 
25,123

Less Accumulated Depreciation, Depletion and Amortization
 
 
 
DTE Electric
 
 
 
Generation
(4,149
)
 
(4,004
)
Distribution
(3,067
)
 
(2,947
)
Total DTE Electric
(7,216
)
 
(6,951
)
DTE Gas
 
 
 
Distribution
(1,130
)
 
(1,129
)
Storage
(142
)
 
(138
)
Other
(363
)
 
(338
)
Total DTE Gas
(1,635
)
 
(1,605
)
Non-utility and other
(867
)
 
(767
)
Total
(9,718
)
 
(9,323
)
Net Property, Plant and Equipment
$
16,820

 
$
15,800

The average estimated useful life for each major class of utility property, plant and equipment as of December 31, 2014 follows:
 
 
Estimated Useful Lives in Years
Utility
 
Generation
 
Distribution
 
Storage
Electric
 
40
 
41
 
N/A
Gas
 
N/A
 
50
 
53
Jointly Owned Utility Plant (Tables)
Schedule of Jointly Owned Utility Plants
Ownership information of the two utility plants as of December 31, 2014 was as follows:
 
Belle River
 
Ludington
Hydroelectric
Pumped Storage
In-service date
1984-1985

 
1973

Total plant capacity
1,270
 MW
 
1,872
 MW
Ownership interest
(a)

 
49
%
Investment in property, plant and equipment (in millions)
$
1,742

 
$
412

Accumulated depreciation (in millions)
$
993

 
$
175


_______________________________________
(a)
DTE Electric's ownership interest is 63% in Unit No. 1, 81% of the facilities applicable to Belle River used jointly by the Belle River and St. Clair Power Plants and 75% in common facilities used at Unit No. 2.
Asset Retirement Obligations (Tables)
Schedule of Change in Asset Retirement Obligation
A reconciliation of the asset retirement obligations for 2014 follows:
 
(In millions)
Asset retirement obligations at December 31, 2013
$
1,827

Accretion
112

Liabilities incurred
11

Liabilities settled
(12
)
Revision in estimated cash flows
24

Asset retirement obligations at December 31, 2014
$
1,962

Regulatory Matters (Tables)
Schedule of Regulatory Assets 
The following are balances and a brief description of the regulatory assets and liabilities at December 31:
 
2014
 
2013
 
(In millions)
Assets
 
 
 
Recoverable pension and other postretirement costs:
 
 
 
Pension
$
2,284

 
$
1,660

Other postretirement costs
234

 
—

Asset retirement obligation
448

 
394

Recoverable Michigan income taxes
267

 
286

Unamortized loss on reacquired debt
67

 
63

Other recoverable income taxes
66

 
71

Accrued PSCR/GCR revenue
61

 
—

Deferred environmental costs
59

 
59

Cost to achieve Performance Excellence Process
54

 
75

Recoverable income taxes related to securitized regulatory assets
19

 
126

Removal costs asset
15

 
—

Transitional Reconciliation Mechanism
14

 
—

Other
139

 
129

 
3,727

 
2,863

Less amount included in current assets
(76
)
 
(26
)
 
$
3,651

 
$
2,837

 
 
 
 
Securitized regulatory assets
$
34

 
$
231

Schedule of Regulatory Liabilities 
Liabilities
 
 
 
Removal costs liability
$
308

 
$
351

Renewable energy
227

 
277

Over recovery of Securitization
71

 
72

Refundable revenue decoupling/deferred gain
67

 
127

Negative pension offset
67

 
84

Refundable income taxes
33

 
45

Energy optimization
24

 
31

Fermi 2 refueling outage
16

 
26

Refundable other postretirement costs
—

 
72

Accrued PSCR/GCR refund
—

 
65

Other
7

 
14

 
$
820

 
$
1,164

Less amount included current liabilities
(153
)
 
(302
)
 
$
667

 
$
862

Income Taxes (Tables)
Schedule of Effective Income Tax Rate Reconciliation 
Total income tax expense varied from the statutory federal income tax rate for the following reasons:
 
2014
 
2013
 
2012
 
(In millions)
Income before income taxes
$
1,275

 
$
922

 
$
960

Income tax expense at 35% statutory rate
$
446

 
$
323

 
$
336

Production tax credits
(119
)
 
(68
)
 
(49
)
Investment tax credits
(6
)
 
(6
)
 
(6
)
Depreciation
(4
)
 
(4
)
 
(4
)
AFUDC - Equity
(7
)
 
(5
)
 
(4
)
Employee Stock Ownership Plan dividends
(4
)
 
(4
)
 
(4
)
Domestic production activities deduction
—

 
(14
)
 
(14
)
State and local income taxes, net of federal benefit
51

 
37

 
37

Enactment of New York Corporate Income Tax Legislation, net of federal benefit
8

 
—

 
—

Other, net
(1
)
 
(5
)
 
(6
)
Income tax expense
$
364

 
$
254

 
$
286

Effective income tax rate
28.5
%
 
27.5
%
 
29.8
%
Schedule of Components of Income Tax Expense (Benefit) 
Components of income tax expense were as follows:
 
2014
 
2013
 
2012
 
(In millions)
Current income tax expense (benefit)
 
 
 
 
 
Federal
$
(16
)
 
$
74

 
$
190

State and other income tax
24

 
16

 
49

Total current income taxes
8

 
90

 
239

Deferred income tax expense
 
 
 
 
 
Federal
289

 
122

 
39

State and other income tax
67

 
42

 
8

Total deferred income taxes
356

 
164

 
47

Total income taxes from continuing operations
364

 
254

 
286

Discontinued operations
—

 
—

 
(29
)
Total
$
364

 
$
254

 
$
257

Schedule of Deferred Tax Assets and Liabilities 
Deferred tax assets (liabilities) were comprised of the following at December 31:
 
2014
 
2013
 
(In millions)
Property, plant and equipment
$
(3,832
)
 
$
(3,372
)
Securitized regulatory assets
(2
)
 
(127
)
Tax credit carry-forwards
296

 
266

Pension and benefits
(152
)
 
(30
)
State net operating loss and credit carry-forwards
39

 
43

Other
(19
)
 
(92
)
 
(3,670
)
 
(3,312
)
Less valuation allowance
(31
)
 
(37
)
 
$
(3,701
)
 
$
(3,349
)
Current deferred income tax assets (liabilities)
$
75

 
$
(28
)
Long-term deferred income tax liabilities
(3,776
)
 
(3,321
)
 
$
(3,701
)
 
$
(3,349
)
Deferred income tax assets
$
861

 
$
934

Deferred income tax liabilities
(4,562
)
 
(4,283
)
 
$
(3,701
)
 
$
(3,349
)
Schedule of Unrecognized Tax Benefits Roll Forward 
A reconciliation of the beginning and ending amount of unrecognized tax benefits is as follows:
 
2014
 
2013
 
2012
 
(In millions)
Balance at January 1
$
10

 
$
11

 
$
48

Reductions for tax positions of prior years
—

 
—

 
(2
)
Additions for tax positions of current year
—

 
—

 
1

Settlements
—

 
—

 
(30
)
Lapse of statute of limitations
(1
)
 
(1
)
 
(6
)
Balance at December 31
$
9

 
$
10

 
$
11

Earnings Per Share (Tables)
Schedule of Earnings Per Share, Basic and Diluted
A reconciliation of both calculations is presented in the following table as of December 31:
 
2014
 
2013
 
2012
 
(In millions, expect per share amounts)
Basic Earnings per Share
 
 
 
 
 
Net income attributable to DTE Energy Company
$
905

 
$
661

 
$
610

Average number of common shares outstanding
177

 
175

 
171

Weighted average net restricted shares outstanding
—

 
1

 
1

Dividends declared — common shares
$
475

 
$
453

 
$
413

Dividends declared — net restricted shares
1

 
1

 
1

Total distributed earnings
$
476

 
$
454

 
$
414

Net income less distributed earnings
$
429

 
$
207

 
$
196

Distributed (dividends per common share)
$
2.69

 
$
2.59

 
$
2.42

Undistributed
2.42

 
1.17

 
1.14

Total Basic Earnings per Common Share
$
5.11

 
$
3.76

 
$
3.56

Diluted Earnings per Share
 
 
 
 
 
Net income attributable to DTE Energy Company
$
905

 
$
661

 
$
610

Average number of common shares outstanding
177

 
175

 
171

Average incremental shares from assumed exercise of options
—

 
—

 
1

Common shares for dilutive calculation
177

 
175

 
172

Weighted average net restricted shares outstanding
—

 
1

 
1

Dividends declared — common shares
$
475

 
$
453

 
$
413

Dividends declared — net restricted shares
1

 
1

 
1

Total distributed earnings
$
476

 
$
454

 
$
414

Net income less distributed earnings
$
429

 
$
207

 
$
196

Distributed (dividends per common share)
$
2.69

 
$
2.59

 
$
2.42

Undistributed
2.41

 
1.17

 
1.13

Total Diluted Earnings per Common Share
$
5.10

 
$
3.76

 
$
3.55

Fair Value (Tables)
Assets and Liabilities Recorded at Fair Value on a Recurring Basis 
The following table presents assets and liabilities measured and recorded at fair value on a recurring basis as of December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Netting (a)
 
Net Balance
 
Level 1
 
Level 2
 
Level 3
 
Netting (a)
 
Net Balance
 
(In millions)
Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Cash equivalents (b)
$
13

 
$
99

 
$
—

 
$
—

 
$
112

 
$
10

 
$
115

 
$
—

 
$
—

 
$
125

Nuclear decommissioning trusts
792

 
449

 
—

 
—

 
1,241

 
779

 
412

 
—

 
—

 
1,191

Other investments (c) (d)
100

 
50

 
—

 
—

 
150

 
92

 
44

 
—

 
—

 
136

Derivative assets:
 

 
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 

 
 
Commodity Contracts:
 

 
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 

 
 
Natural Gas
555

 
140

 
92

 
(681
)
 
106

 
273

 
89

 
34

 
(382
)
 
14

Electricity
—

 
295

 
47

 
(280
)
 
62

 
—

 
261

 
139

 
(291
)
 
109

Other
42

 
—

 
3

 
(42
)
 
3

 
33

 
1

 
3

 
(34
)
 
3

Other derivative contracts (e)
—

 
4

 
—

 
(3
)
 
1

 
—

 
—

 
—

 
—

 
—

Total derivative assets
597

 
439

 
142

 
(1,006
)
 
172

 
306

 
351

 
176

 
(707
)
 
126

Total
$
1,502

 
$
1,037

 
$
142

 
$
(1,006
)
 
$
1,675

 
$
1,187

 
$
922

 
$
176

 
$
(707
)
 
$
1,578

 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Derivative liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Commodity Contracts:
 

 
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 

 
 
Natural Gas
$
(578
)
 
$
(78
)
 
$
(62
)
 
$
679

 
$
(39
)
 
$
(277
)
 
$
(140
)
 
$
(86
)
 
$
395

 
$
(108
)
Electricity
—

 
(290
)
 
(52
)
 
298

 
(44
)
 
—

 
(272
)
 
(126
)
 
269

 
(129
)
Other
(32
)
 
(9
)
 
(4
)
 
45

 
—

 
(32
)
 
(2
)
 
—

 
34

 
—

Other derivative contracts (e)
—

 
(5
)
 
—

 
3

 
(2
)
 
—

 
(1
)
 
—

 
—

 
(1
)
Total derivative liabilities
(610
)
 
(382
)
 
(118
)
 
1,025

 
(85
)
 
(309
)
 
(415
)
 
(212
)
 
698

 
(238
)
Total
$
(610
)
 
$
(382
)
 
$
(118
)
 
$
1,025

 
$
(85
)
 
$
(309
)
 
$
(415
)
 
$
(212
)
 
$
698

 
$
(238
)
Net Assets (Liabilities) at the end of the period
$
892

 
$
655

 
$
24

 
$
19

 
$
1,590

 
$
878

 
$
507

 
$
(36
)
 
$
(9
)
 
$
1,340

Assets:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
$
582

 
$
504

 
$
109

 
$
(955
)
 
$
240

 
$
277

 
$
400

 
$
139

 
$
(592
)
 
$
224

Noncurrent (f)
920

 
533

 
33

 
(51
)
 
1,435

 
910

 
522

 
37

 
(115
)
 
1,354

Total Assets
$
1,502

 
$
1,037

 
$
142

 
$
(1,006
)
 
$
1,675

 
$
1,187

 
$
922

 
$
176

 
$
(707
)
 
$
1,578

Liabilities:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Current
$
(572
)
 
$
(357
)
 
$
(112
)
 
$
964

 
$
(77
)
 
$
(268
)
 
$
(328
)
 
$
(177
)
 
$
578

 
$
(195
)
Noncurrent
(38
)
 
(25
)
 
(6
)
 
61

 
(8
)
 
(41
)
 
(87
)
 
(35
)
 
120

 
(43
)
Total Liabilities
$
(610
)
 
$
(382
)
 
$
(118
)
 
$
1,025

 
$
(85
)
 
$
(309
)
 
$
(415
)
 
$
(212
)
 
$
698

 
$
(238
)
Net Assets (Liabilities) at the end of the period
$
892

 
$
655

 
$
24

 
$
19

 
$
1,590

 
$
878

 
$
507

 
$
(36
)
 
$
(9
)
 
$
1,340


_______________________________________
(a)
Amounts represent the impact of master netting agreements that allow the Company to net gain and loss positions and cash collateral held or placed with the same counterparties.
(b)
At December 31, 2014, available-for-sale securities of $112 million included $105 million and $7 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively. At December 31, 2013, available-for-sale securities of $125 million, included $109 million and $16 million of cash equivalents included in Restricted cash and Other investments on the Consolidated Statements of Financial Position, respectively.
(c)
Excludes cash surrender value of life insurance investments.
(d)
Available-for-sale equity securities of $8 million at December 31, 2014 and $7 million at December 31, 2013 are included in Other investments on the Consolidated Statements of Financial Position.
(e)
Primarily includes Foreign currency exchange contracts.
(f)
Includes $150 million and $136 million of Other investments that are included in the Consolidated Statements of Financial Position in Other investments at December 31, 2014 and 2013, respectively.
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis Level 3 Roll Forward 
The following table presents the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis for the years ended December 31, 2014 and 2013:
 
Year Ended December 31, 2014
 
Year Ended December 31, 2013
 
Natural Gas
 
Electricity
 
Other
 
Total
 
Natural Gas
 
Electricity
 
Other
 
Total
 
(In millions)
Net Assets (Liabilities) as of December 31
$
(52
)
 
$
13

 
$
3

 
$
(36
)
 
$
(38
)
 
$
23

 
$
2

 
$
(13
)
Transfers into Level 3 from Level 2
—

 
—

 
—

 
—

 
1

 
—

 
—

 
1

Transfers from Level 3 into Level 2
(2
)
 
—

 
—

 
(2
)
 
—

 
—

 
—

 
—

Total gains (losses):
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Included in earnings
(40
)
 
25

 
(5
)
 
(20
)
 
(32
)
 
75

 
—

 
43

Recorded in regulatory assets/liabilities
—

 
—

 
8

 
8

 
—

 
—

 
5

 
5

Purchases, issuances and settlements:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Purchases
—

 
1

 
—

 
1

 
(8
)
 
1

 
—

 
(7
)
Issuances
—

 
(3
)
 
—

 
(3
)
 
—

 
(1
)
 
—

 
(1
)
Settlements
124

 
(41
)
 
(7
)
 
76

 
25

 
(85
)
 
(4
)
 
(64
)
Net Assets (Liabilities) as of December 31
$
30

 
$
(5
)
 
$
(1
)
 
$
24

 
$
(52
)
 
$
13

 
$
3

 
$
(36
)
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
$
35

 
$
9

 
$
(4
)
 
$
40

 
$
(49
)
 
$
48

 
$
—

 
$
(1
)
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques 
The following tables present the unobservable inputs related to Level 3 assets and liabilities as of December 31, 2014 and 2013:
 
 
December 31, 2014
 
 
 
 
 
 
 
 
 
 
Commodity Contracts
 
Derivative Assets
 
Derivative Liabilities
 
Valuation Techniques
 
Unobservable Input
 
Range
 
Weighted Average
 
 
(In millions)
 
 
 
 
 
 
 
 
 
 
Natural Gas
 
$
92

 
$
(62
)
 
Discounted Cash Flow
 
Forward basis price (per MMBtu)
 
$
(2.28
) —
 
$
7.83
/MMBtu
 
$
(0.22
)/MMBtu
Electricity
 
$
47

 
$
(52
)
 
Discounted Cash Flow
 
Forward basis price (per MWh)
 
$
(14
) —
 
$
15
/MWh
 
$
4
/MWh
 
 
December 31, 2013
 
 
 
 
 
 
 
 
 
 
Commodity Contracts
 
Derivative Assets
 
Derivative Liabilities
 
Valuation Techniques
 
Unobservable Input
 
Range
 
Weighted Average
 
 
(In millions)
 
 
 
 
 
 
 
 
 
 
Natural Gas
 
$
34

 
$
(86
)
 
Discounted Cash Flow
 
Forward basis price (per MMBtu)
 
$
(0.88
) —
 
$
5.07
/MMBtu
 
$
(0.16
)/MMBtu
Electricity
 
$
139

 
$
(126
)
 
Discounted Cash Flow
 
Forward basis price (per MWh)
 
$
(7
) —
 
$
15
/MWh
 
$
3
/MWh
Fair Value of Financial Instruments 
The following table presents the carrying amount and fair value of financial instruments as of December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Carrying
 
Fair Value
 
Carrying
 
Fair Value
 
Amount
 
Level 1
 
Level 2
 
Level 3
 
Amount
 
Level 1
 
Level 2
 
Level 3
 
(In millions)
Notes receivable, excluding capital leases
$
41

 
$
—

 
$
—

 
$
41

 
$
41

 
$
—

 
$
—

 
$
41

Dividends payable
$
122

 
$
122

 
$
—

 
$
—

 
$
116

 
$
116

 
$
—

 
$
—

Short-term borrowings
$
398

 
$
—

 
$
398

 
$
—

 
$
131

 
$
—

 
$
131

 
$
—

Long-term debt, excluding capital leases
$
8,606

 
$
489

 
$
8,308

 
$
706

 
$
8,094

 
$
425

 
$
7,551

 
$
499

Fair Value of Nuclear Decommissioning Trust Fund Assets Text Block 
The following table summarizes the fair value of the nuclear decommissioning trust fund assets:
 
December 31, 2014
 
December 31, 2013
 
(In millions)
Fermi 2
$
1,221

 
$
1,172

Fermi 1
3

 
3

Low level radioactive waste
17

 
16

Total
$
1,241

 
$
1,191

Schedule of Realized Gain (Loss) 
The following table sets forth the gains and losses and proceeds from the sale of securities by the nuclear decommissioning trust funds:
 
Year Ended December 31
 
2014
 
2013
 
2012
 
(In millions)
Realized gains
$
54

 
$
83

 
$
37

Realized losses
$
(33
)
 
$
(41
)
 
$
(31
)
Proceeds from sales of securities
$
1,146

 
$
1,118

 
$
759

Fair Value and Unrealized Gains and Losses for Nuclear Decommissioning Trust Fund Table 
The following table sets forth the fair value and unrealized gains for the nuclear decommissioning trust funds:
 
December 31, 2014
 
December 31, 2013
 
Fair
Value
 
Unrealized
Gains
 
Unrealized Losses
 
Fair
Value
 
Unrealized
Gains
 
Unrealized Losses
 
(In millions)
Equity securities
$
756

 
$
204

 
$
(39
)
 
$
730

 
$
201

 
$
(25
)
Debt securities
474

 
21

 
(2
)
 
442

 
12

 
(6
)
Cash and cash equivalents
11

 
—

 
—

 
19

 
—

 
—

 
$
1,241

 
$
225


$
(41
)
 
$
1,191

 
$
213


$
(31
)
Financial and Other Derivative Instruments (Tables)
Fair Value of Derivative Instruments 
The following tables present the fair value of derivative instruments as of December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Derivative
Assets
 
Derivative Liabilities
 
Derivative
Assets
 
Derivative Liabilities
 
(In millions)
Derivatives not designated as hedging instruments:
 
 
 
 
 
 
 
Foreign currency exchange contracts
$
4

 
$
(5
)
 
$
—

 
$
(1
)
Commodity Contracts:
 
 
 
 
 

 
 

Natural Gas
787

 
(718
)
 
396

 
(503
)
Electricity
342

 
(342
)
 
400

 
(398
)
Other
45

 
(45
)
 
37

 
(34
)
Total derivatives not designated as hedging instruments:
$
1,178

 
$
(1,110
)
 
$
833

 
$
(936
)
Total derivatives:
 
 
 
 
 
 
 
Current
$
1,083

 
$
(1,041
)
 
$
691

 
$
(773
)
Noncurrent
95

 
(69
)
 
142

 
(163
)
Total derivatives
$
1,178

 
$
(1,110
)
 
$
833

 
$
(936
)
Netting Offsets of Derivative Assets and Liabilities 
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Gross Amounts of Recognized Assets (Liabilities)
 
Gross Amounts Offset in the Consolidated Statements of Financial Position
 
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
 
Gross Amounts of Recognized Assets (Liabilities)
 
Gross Amounts Offset in the Consolidated Statements of Financial Position
 
Net Amounts of Assets (Liabilities) Presented in the Consolidated Statements of Financial Position
 
(In millions)
Derivative assets:
 
 
 
 
 
 
 
 
 
 
 
Commodity Contracts:
 
 
 
 
 
 
 
 
 
 
 
Natural Gas
$
787

 
$
(681
)
 
$
106

 
$
396

 
$
(382
)
 
$
14

Electricity
342

 
(280
)
 
62

 
400

 
(291
)
 
109

Other
45

 
(42
)
 
3

 
37

 
(34
)
 
3

Other derivative contracts (a)
4

 
(3
)
 
1

 
—

 
—

 
—

Total derivative assets
$
1,178

 
$
(1,006
)
 
$
172

 
$
833

 
$
(707
)
 
$
126

 
 
 
 
 
 
 
 
 
 
 
 
Derivative liabilities:
 
 
 
 
 
 
 
 
 
 
 
Commodity Contracts:
 
 
 
 
 
 
 
 
 
 
 
Natural Gas
$
(718
)
 
$
679

 
$
(39
)
 
$
(503
)
 
$
395

 
$
(108
)
Electricity
(342
)
 
298

 
(44
)
 
(398
)
 
269

 
(129
)
Other
(45
)
 
45

 
—

 
(34
)
 
34

 
—

Other derivative contracts (a)
(5
)
 
3

 
(2
)
 
(1
)
 
—

 
(1
)
Total derivative liabilities
$
(1,110
)
 
$
1,025

 
$
(85
)
 
$
(936
)
 
$
698

 
$
(238
)

_______________________________________
(a)
Primarily includes Foreign currency exchange contracts
Netting Offsets of Derivative Assets and Liabilities Reconciliation to the Statements of Financial Position 
The following table presents the netting offsets of derivative assets and liabilities at December 31, 2014 and 2013:
 
December 31, 2014
 
December 31, 2013
 
Derivative Assets
 
Derivative Liabilities
 
Derivative Assets
 
Derivative Liabilities
 
Current
 
Noncurrent
 
Current
 
Noncurrent
 
Current
 
Noncurrent
 
Current
 
Noncurrent
 
(In millions)
Reconciliation of derivative instruments to Consolidated Statements of Financial Position:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Total fair value of derivatives
$
1,083

 
$
95

 
$
(1,041
)
 
$
(69
)
 
$
691

 
$
142

 
$
(773
)
 
$
(163
)
Counterparty netting
(955
)
 
(51
)
 
955

 
51

 
(566
)
 
(115
)
 
566

 
115

Collateral adjustment
—

 
—

 
9

 
10

 
(26
)
 
—

 
12

 
5

Total derivatives as reported
$
128

 
$
44

 
$
(77
)
 
$
(8
)
 
$
99

 
$
27

 
$
(195
)
 
$
(43
)
Gain (Loss) Recognized in Income on Derivative 
The effect of derivatives not designated as hedging instruments on the Consolidated Statements of Operations for years ended December 31, 2014 and 2013 is as follows:
 
 
Location of Gain (Loss) Recognized in Income on Derivatives
 
Gain (Loss) Recognized in
Income on Derivatives for
Years Ended December 31,
Derivatives not Designated as Hedging Instruments
 
 
2014
 
2013
 
 
 
 
(In millions)
Foreign currency exchange contracts
 
Operating Revenue
 
$
(2
)
 
$
(1
)
Commodity Contracts:
 
 
 
 
 
 
Natural Gas
 
Operating Revenue
 
(30
)
 
(48
)
Natural Gas
 
Fuel, purchased power and gas
 
(5
)
 
(44
)
Electricity
 
Operating Revenue
 
123

 
82

Other
 
Operating Revenue
 
(7
)
 
—

Total
 
 
 
$
79

 
$
(11
)
Volume of Commodity Contracts 
The following represents the cumulative gross volume of derivative contracts outstanding as of December 31, 2014:
Commodity
 
Number of Units
Natural Gas (MMBtu)
 
895,599,953
Electricity (MWh)
 
11,296,153
Foreign Currency Exchange (Canadian dollars)
 
63,022,462
Long-Term Debt (Tables)
Schedule of Long-term Debt Instruments 
The Company’s long-term debt outstanding and weighted average interest rates (a) of debt outstanding at December 31 were:
 
2014
 
2013
 
(In millions)
Mortgage bonds, notes and other
 
 
 
DTE Energy Debt, Unsecured
 
 
 
4.6% due 2016 to 2033
$
1,647

 
$
1,297

DTE Electric Taxable Debt, Principally Secured
 
 
 
4.5% due 2016 to 2044
4,824

 
4,286

DTE Electric Tax-Exempt Revenue Bonds (b)
 
 
 
5.2% due 2020 to 2030
330

 
558

DTE Gas Taxable Debt, Principally Secured
 
 
 
5.2% due 2015 to 2044
1,099

 
1,029

Other Long-Term Debt, Including Non-Recourse Debt
121

 
142

 
8,021

 
7,312

Less amount due within one year
(161
)
 
(694
)
 
$
7,860

 
$
6,618

Securitization bonds
 
 
 
6.6% due 2015
$
105

 
$
302

Less amount due within one year
(105
)
 
(197
)
 
$
—

 
$
105

Junior Subordinated Debentures
 
 
 
6.5% due 2061
$
280

 
$
280

5.25% due 2062
200

 
200

 
$
480

 
$
480


_______________________________________
(a)
Weighted average interest rates as of December 31, 2014 are shown below the description of each category of debt.
(b)
DTE Electric Tax-Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.
Schedule of Issued Debt 
In 2014, the following debt was issued:
Company
 
Month Issued
 
Type
 
Interest Rate
 
Maturity
 
Amount
 
 
 
 
 
 
 
 
 
 
(In millions)
DTE Energy
 
May
 
Senior Notes (a)
 
3.50
%
 
2024
 
$
350

DTE Electric
 
June
 
Mortgage Bonds (a)
 
3.77
%
 
2026
 
100

DTE Electric
 
June
 
Mortgage Bonds (a)
 
4.60
%
 
2044
 
150

DTE Electric
 
July
 
Mortgage Bonds (a)
 
3.375
%
 
2025
 
350

DTE Electric
 
July
 
Mortgage Bonds (a)
 
4.30
%
 
2044
 
350

DTE Energy
 
November
 
Senior Notes (a)
 
2.40
%
 
2019
 
300

DTE Gas
 
December
 
Mortgage Bonds (a)
 
4.35
%
 
2044
 
150

 
 
 
 
 
 
 
 
 
 
$
1,750


_______________________________________
(a)
Proceeds were used for the redemption of long-term debt, repayment of short-term borrowings and general corporate purposes.
Schedule of Extinguishment of Debt 
In 2014, the following debt was redeemed:
Company
 
Month
 
Type
 
Interest Rate
 
Maturity
 
Amount
 
 
 
 
 
 
 
 
 
 
(In millions)
DTE Electric
 
March
 
Mortgage Bonds
 
Various

 
2014
 
$
13

DTE Electric
 
March
 
Securitization Bonds
 
6.62
%
 
2014
 
100

DTE Electric
 
April
 
Tax Exempt Revenue Bonds (a)
 
2.35
%
 
2024
 
31

DTE Electric
 
April
 
Tax Exempt Revenue Bonds (a)
 
4.65
%
 
2028
 
32

DTE Gas
 
May
 
Mortgage Bonds
 
8.25
%
 
2014
 
80

DTE Energy
 
May
 
Senior Notes
 
7.625
%
 
2014
 
300

DTE Electric
 
June
 
Tax Exempt Revenue Bonds (a)
 
4.875
%
 
2029
 
36

DTE Electric
 
June
 
Tax Exempt Revenue Bonds (a)
 
6.00
%
 
2036
 
69

DTE Electric
 
July
 
Senior Notes
 
4.80
%
 
2015
 
200

DTE Electric
 
August
 
Senior Notes
 
5.40
%
 
2014
 
200

DTE Electric
 
August
 
Tax Exempt Revenue Bonds (a)
 
5.25
%
 
2029
 
60

DTE Electric
 
September
 
Securitization Bonds
 
6.62
%
 
2014
 
96

DTE Energy
 
Various
 
Other Long Term Debt
 
Various

 
2014
 
20

 
 
 
 
 
 
 
 
 
 
$
1,237

_______________________________________
(a)
DTE Electric Tax Exempt Revenue Bonds are issued by a public body that loans the proceeds to DTE Electric on terms substantially mirroring the Revenue Bonds.
Schedule of Maturities of Long-term Debt 
The following table shows the scheduled debt maturities, excluding any unamortized discount or premium on debt:
 
2015
 
2016
 
2017
 
2018
 
2019
 
2020 and Thereafter
 
Total
 
(In millions)
Amount to mature
$
266

 
$
465

 
$
9

 
$
407

 
$
427

 
$
7,046

 
$
8,620

Preferred and Preferenced Securities (Tables)
Schedule of Preferred and Preference Securities
As of December 31, 2014, the amount of authorized and unissued stock is as follows:
Company
 
Type of Stock
 
Par Value
 
Shares Authorized
DTE Energy
 
Preferred
 
$
—

 
5,000,000

DTE Electric
 
Preferred
 
$
100

 
6,747,484

DTE Electric
 
Preference
 
$
1

 
30,000,000

DTE Gas
 
Preferred
 
$
1

 
7,000,000

DTE Gas
 
Preference
 
$
1

 
4,000,000

Short-Term Credit Arrangements and Borrowings (Tables)
Schedule of Line of Credit Facilities
The availability under the facilities in place at December 31, 2014 is shown in the following table:
 
DTE Energy
 
DTE Electric
 
DTE Gas
 
Total
 
(In millions)
Unsecured letter of credit facility, expiring in February 2015
$
100

 
$
—

 
$
—

 
$
100

Unsecured letter of credit facility, expiring in August 2015
125

 
—

 
—

 
125

Unsecured revolving credit facility, expiring April 2018
1,200

 
300

 
300

 
1,800

 
1,425

 
300

 
300

 
2,025

Amounts outstanding at December 31, 2014:
 
 
 
 
 
 
 
Commercial paper issuances
203

 
50

 
145

 
398

Letters of credit
204

 
—

 
—

 
204

 
407

 
50

 
145

 
602

Net availability at December 31, 2014
$
1,018

 
$
250

 
$
155

 
$
1,423

Capital and Operating Leases (Tables)
Schedule of Future Minimum Rental Payments for Operating Leases 
Future minimum lease payments under non-cancelable leases at December 31, 2014 were:
 
Operating
Leases
 
(In millions)
2015
$
42

2016
34

2017
28

2018
23

2019
14

Thereafter
78

Total minimum lease payments
$
219

Schedule of Future Minimum Lease Receivables for Capital Leases 
The components of the net investment in the capital leases at December 31, 2014, were as follows:
 
Capital
Leases
 
(In millions)
2015
$
12

2016
13

2017
13

2018
13

2019
10

Thereafter
9

Total minimum future lease receipts
70

Residual value of leased pipeline
40

Less unearned income
(34
)
Net investment in capital lease
76

Less current portion
(5
)
 
$
71

Commitments and Contingencies (Tables)
Schedule of Long-term Purchase Commitment
The Company estimates that these commitments will be approximately $9.0 billion from 2015 through 2051 as detailed in the following table:
 
(In millions)
2015
$
2,384

2016
1,258

2017
742

2018
477

2019
431

2020 and thereafter
3,723

 
$
9,015

Retirement Benefits and Trusteed Assets (Tables)
Schedule of Net Benefit Costs 
Net pension cost includes the following components:
 
2014
 
2013
 
2012
 
(In millions)
Service cost
$
83

 
$
94

 
$
82

Interest cost
212

 
192

 
204

Expected return on plan assets
(273
)
 
(266
)
 
(244
)
Amortization of:
 
 
 
 
 
Net loss
157

 
208

 
176

Special termination benefits
—

 
—

 
2

Net pension cost
$
179

 
$
228

 
$
220

Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block] 
 
2014
 
2013
 
(In millions)
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income
 
 
 
Net actuarial (gain) loss
$
805

 
$
(581
)
Amortization of net actuarial loss
(157
)
 
(208
)
Prior service cost
(7
)
 
—

Total recognized in Regulatory assets and Other comprehensive income
$
641

 
$
(789
)
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income
$
820

 
$
(561
)
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
 
 
 
Net actuarial loss
$
206

 
$
151

Schedule of Defined Benefit Plans Disclosures 
The following table reconciles the obligations, assets and funded status of the plans as well as the amounts recognized as prepaid pension cost or pension liability in the Consolidated Statements of Financial Position at December 31:
 
2014
 
2013
 
(In millions)
Accumulated benefit obligation, end of year
$
4,853

 
$
4,068

Change in projected benefit obligation
 
 
 
Projected benefit obligation, beginning of year
$
4,380

 
$
4,729

Service cost
83

 
94

Interest cost
212

 
192

Plan amendments
(7
)
 
(3
)
Actuarial (gain) loss
836

 
(400
)
Benefits paid
(235
)
 
(232
)
Projected benefit obligation, end of year
$
5,269

 
$
4,380

Change in plan assets
 
 
 
Plan assets at fair value, beginning of year
$
3,720

 
$
3,223

Actual return on plan assets
301

 
445

Company contributions
195

 
284

Benefits paid
(235
)
 
(232
)
Plan assets at fair value, end of year
$
3,981

 
$
3,720

Funded status of the plans
$
(1,288
)
 
$
(660
)
Amount recorded as:
 
 
 
Current liabilities
$
(8
)
 
$
(7
)
Noncurrent liabilities
(1,280
)
 
(653
)
 
$
(1,288
)
 
$
(660
)
Amounts recognized in Accumulated other comprehensive loss, pre-tax
 
 
 
Net actuarial loss
$
194

 
$
174

Prior service (credit)
(1
)
 
(1
)
 
$
193

 
$
173

Amounts recognized in Regulatory assets (see Note 8)
 
 
 
Net actuarial loss
$
2,285

 
$
1,654

Prior service (credit) cost
(1
)
 
6

 
$
2,284

 
$
1,660

Schedule of Expected Benefit Payments 
At December 31, 2014, the benefits related to the Company’s qualified and nonqualified pension plans expected to be paid in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
 
(In millions)
2015
$
269

2016
277

2017
286

2018
298

2019
309

2020-2024
1,634

Total
$
3,073

Schedule of Assumptions Used 
Assumptions used in determining the projected benefit obligation and net pension costs are listed below:
 
2014
 
2013
 
2012
Projected benefit obligation
 
 
 
 
 
Discount rate
4.12%
 
4.95%
 
4.15%
Rate of compensation increase
4.65%
 
4.20%
 
4.20%
Net pension costs
 
 
 
 
 
Discount rate
4.95%
 
4.15%
 
5.00%
Rate of compensation increase
4.20%
 
4.20%
 
4.20%
Expected long-term rate of return on plan assets
7.75%
 
8.25%
 
8.25%
Schedule of Allocation of Plan Assets 
Target allocations for pension plan assets as of December 31, 2014 are listed below:
U.S. Large Cap Equity Securities
22
%
U.S. Small Cap and Mid Cap Equity Securities
5

Non U.S. Equity Securities
20

Fixed Income Securities
25

Hedge Funds and Similar Investments
20

Private Equity and Other
8

 
100
%
Fair Value Measurements for pension plan assets at December 31, 2014 and 2013 (a):
 
December 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Total
 
(In millions)
Asset category:
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Short-term investments (b)
$
46

 
$
—

 
$
—

 
$
46

 
$
22

 
$
—

 
$
—

 
$
22

Equity securities
 

 
 

 
 

 
 
 
 

 
 

 
 

 


U.S. large cap (c)
899

 
—

 
—

 
899

 
896

 
—

 
—

 
896

U.S. small/mid cap (d)
225

 
—

 
—

 
225

 
221

 
—

 
—

 
221

Non U.S. (e)
526

 
219

 
—

 
745

 
611

 
130

 
—

 
741

Fixed income securities (f)
7

 
1,113

 
—

 
1,120

 
16

 
921

 
—

 
937

Hedge funds and similar investments (g)
226

 
95

 
438

 
759

 
268

 
70

 
395

 
733

Private equity and other (h)
—

 
—

 
187

 
187

 
—

 
—

 
170

 
170

Securities lending (i)
(189
)
 
(50
)
 
—

 
(239
)
 
—

 
—

 
—

 
—

Securities lending collateral (i)
189

 
50

 
—

 
239

 
—

 
—

 
—

 
—

Total
$
1,929

 
$
1,427

 
$
625

 
$
3,981

 
$
2,034

 
$
1,121

 
$
565

 
$
3,720

_______________________________________
(a)
For a description of levels within the fair value hierarchy see Note 11 to the Consolidated Financial Statements, "Fair Value".
(b)
This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
(c)
This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(d)
This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(e)
This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(f)
This category includes corporate bonds from diversified industries, U.S. Treasuries, and mortgage-backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
(g)
This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
(h)
This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.
(i)
In 2014, DTE Energy began a securities lending program with a third party agent. The program allows the agent to lend certain securities from the Company's pension trusts to selected entities against receipt of collateral (in the form of cash) as provided for and determined in accordance with its securities lending agency agreement.
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets 
Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
 
Year Ended December 31, 2014
 
Year Ended December 31, 2013
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
(In millions)
Beginning Balance at January 1
$
395

 
$
170

 
$
565

 
$
339

 
$
179

 
$
518

Total realized/unrealized gains (losses)
22

 
16

 
38

 
40

 
4

 
44

Purchases, sales and settlements:
 
 
 
 
 
 
 
 
 
 
 
Purchases
22

 
31

 
53

 
16

 
15

 
31

Sales
(1
)
 
(30
)
 
(31
)
 
—

 
(28
)
 
(28
)
Ending Balance at December 31
$
438

 
$
187

 
$
625

 
$
395

 
$
170

 
$
565

The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period
$
21

 
$
11

 
$
32

 
$
38

 
$
3

 
$
41

Schedule of Net Benefit Costs 
Net other postretirement cost includes the following components:
 
2014
 
2013
 
2012
 
(In millions)
Service cost
$
34

 
$
47

 
$
68

Interest cost
89

 
88

 
120

Expected return on plan assets
(122
)
 
(110
)
 
(92
)
Amortization of:
 

 
 

 
 

Net loss
20

 
64

 
80

Prior service credit
(144
)
 
(131
)
 
(25
)
Net other postretirement cost (credit)
$
(123
)
 
$
(42
)
 
$
151

Schedule of Defined Benefit Plan Amounts Recognized in Other Comprehensive Income (Loss) [Table Text Block] 
 
2014
 
2013
 
(In millions)
Other changes in plan assets and APBO recognized in Regulatory assets (liabilities) and Other comprehensive income
 
 
 
Net actuarial (gain) loss
$
192

 
$
(353
)
Amortization of net actuarial loss
(20
)
 
(64
)
Prior service credit
—

 
(218
)
Amortization of prior service credit
144

 
131

Total recognized in Regulatory assets (liabilities) and Other comprehensive income
$
316

 
$
(504
)
Total recognized in net periodic benefit cost, Regulatory assets (liabilities) and Other comprehensive income
$
193

 
$
(546
)
Estimated amounts to be amortized from Regulatory assets (liabilities) and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
 
 
 
Net actuarial loss
$
43

 
$
21

Prior service credit
$
(126
)
 
$
(144
)
Schedule of Defined Benefit Plans Disclosures 
The following table reconciles the obligations, assets and funded status of the plans including amounts recorded as Accrued postretirement liability in the Consolidated Statements of Financial Position at December 31:
 
2014
 
2013
 
(In millions)
Change in accumulated postretirement benefit obligation
 
 
 
Accumulated postretirement benefit obligation, beginning of year
$
1,878

 
$
2,315

Service cost
34

 
47

Interest cost
89

 
88

Plan amendments
—

 
(218
)
Actuarial (gain) loss
131

 
(267
)
Medicare Part D subsidy
—

 
1

Benefits paid
(88
)
 
(88
)
Accumulated postretirement benefit obligation, end of year
$
2,044

 
$
1,878

Change in plan assets
 
 
 
Plan assets at fair value, beginning of year
$
1,527

 
$
1,153

Actual return on plan assets
62

 
196

Company contributions
24

 
264

Benefits paid
(85
)
 
(86
)
Plan assets at fair value, end of year
$
1,528

 
$
1,527

Funded status, end of year
$
(516
)
 
$
(351
)
Amount recorded as:
 
 
 
Current liabilities
$
(1
)
 
$
(1
)
Noncurrent liabilities
(515
)
 
(350
)
 
$
(516
)
 
$
(351
)
Amounts recognized in Accumulated other comprehensive loss, pre-tax
 
 
 
Net actuarial loss
$
34

 
$
29

Prior service credit
(5
)
 
(10
)
 
$
29

 
$
19

Amounts recognized in Regulatory assets (liabilities) (see Note 8)
 
 
 
Net actuarial loss
$
488

 
$
321

Prior service credit
(254
)
 
(393
)
 
$
234

 
$
(72
)
Schedule of Expected Benefit Payments 
At December 31, 2014, the benefits expected to be paid, including prescription drug benefits, in each of the next five years and in the aggregate for the five fiscal years thereafter are as follows:
 
(In millions)
2015
$
101

2016
107

2017
111

2018
117

2019
122

2020-2024
660

Total
$
1,218

Schedule of Assumptions Used 
Assumptions used in determining the accumulated postretirement benefit obligation and net other postretirement benefit costs are listed below:
 
2014
 
2013
 
2012
Accumulated postretirement benefit obligation
 
 
 
 
 
Discount rate
4.10%
 
4.95%
 
4.15%
Health care trend rate pre- and post- 65
7.50 / 6.50%
 
7.50 / 6.50%
 
7.00%
Ultimate health care trend rate
4.50%
 
4.50%
 
5.00%
Year in which ultimate reached pre- and post- 65
2025 / 2024
 
2025 / 2024
 
2021
Other postretirement benefit costs
 
 
 
 
 
Discount rate (prior to interim remeasurement)
4.95%
 
4.15%
 
5.00%
Discount rate (post interim remeasurement)
N/A
 
4.30%
 
N/A
Expected long-term rate of return on plan assets
8.00%
 
8.25%
 
8.25%
Health care trend rate pre- and post- 65
7.50 / 6.50%
 
7.00%
 
7.00%
Ultimate health care trend rate
4.50%
 
5.00%
 
5.00%
Year in which ultimate reached pre- and post- 65
2025 / 2024
 
2021
 
2020
Schedule of Allocation of Plan Assets 
Target allocations for other postretirement benefit plan assets as of December 31, 2014 are listed below:
U.S. Large Cap Equity Securities
17
%
U.S. Small Cap and Mid Cap Equity Securities
4

Non U.S. Equity Securities
20

Fixed Income Securities
25

Hedge Funds and Similar Investments
20

Private Equity and Other
14

 
100
%

Fair Value Measurements for other postretirement benefit plan assets at December 31, 2014 and 2013 (a):
 
December 31, 2014
 
December 31, 2013
 
Level 1
 
Level 2
 
Level 3
 
Total
 
Level 1
 
Level 2
 
Level 3
 
Total
Asset category:
(In millions)
Short-term investments (b)
$
6

 
$
—

 
$
—

 
$
6

 
$
5

 
$
—

 
$
—

 
$
5

Equity securities
 

 
 

 
 

 
 
 
 

 
 

 
 

 
 
U.S. large cap (c)
266

 
—

 
—

 
266

 
302

 
—

 
—

 
302

U.S. small/mid cap (d)
149

 
—

 
—

 
149

 
147

 
—

 
—

 
147

Non U.S. (e)
222

 
59

 
—

 
281

 
282

 
9

 
—

 
291

Fixed income securities (f)
15

 
360

 
—

 
375

 
17

 
350

 
—

 
367

Hedge funds and similar investments (g)
107

 
45

 
168

 
320

 
130

 
25

 
159

 
314

Private equity and other (h)
—

 
—

 
131

 
131

 
—

 
—

 
101

 
101

Securities lending (i)
(141
)
 
(17
)
 
—

 
(158
)
 
—

 
—

 
—

 
—

Securities lending collateral (i)
141

 
17

 
—

 
158

 
—

 
—

 
—

 
—

Total
$
765

 
$
464

 
$
299

 
$
1,528

 
$
883

 
$
384

 
$
260

 
$
1,527

_______________________________________
(a)
For a description of levels within the fair value hierarchy see Note 11 to the Consolidated Financial Statements, "Fair Value".
(b)
This category predominantly represents certain short-term fixed income securities and money market investments that are managed in separate accounts or commingled funds. Pricing for investments in this category are obtained from quoted prices in actively traded markets or valuations from brokers or pricing services.
(c)
This category comprises both actively and not actively managed portfolios that track the S&P 500 low cost equity index funds. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(d)
This category represents portfolios of small and medium capitalization domestic equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(e)
This category primarily consists of portfolios of non-U.S. developed and emerging market equities. Investments in this category are exchange-traded securities whereby unadjusted quote prices can be obtained. Exchange-traded securities held in a commingled fund are classified as Level 2 assets.
(f)
This category includes corporate bonds from diversified industries, U.S. Treasuries, bank loans and mortgage backed securities. Pricing for investments in this category is obtained from quoted prices in actively traded markets and quotations from broker or pricing services. Non-exchange traded securities and exchange-traded securities held in commingled funds are classified as Level 2 assets.
(g)
This category utilizes a diversified group of strategies that attempt to capture financial market inefficiencies and includes publicly traded debt and equity, publicly traded mutual funds, commingled and limited partnership funds and non-exchange traded securities. Pricing for Level 1 and Level 2 assets in this category is obtained from quoted prices in actively traded markets and quoted prices from broker or pricing services. Non-exchange traded securities held in commingled funds are classified as Level 2 assets. Valuations for some Level 3 assets in this category may be based on limited observable inputs as there may be little, if any, publicly available pricing.
(h)
This category includes a diversified group of funds and strategies that primarily invests in private equity partnerships. This category also includes investments in timber and private mezzanine debt. Pricing for investments in this category is based on limited observable inputs as there is little, if any, publicly available pricing. Valuations for assets in this category may be based on discounted cash flow analyses, relevant publicly-traded comparables and comparable transactions.
(i)
In 2014, DTE Energy began a securities lending program with a third party agent. The program allows the agent to lend certain securities from the Company's VEBA trust to selected entities against receipt of collateral (in the form of cash) as provided for and determined in accordance with its securities lending agency agreement.
Target allocations for other postretirement benefit plan assets as of December 31, 2014 are listed below:
U.S. Large Cap Equity Securities
17
%
U.S. Small Cap and Mid Cap Equity Securities
4

Non U.S. Equity Securities
20

Fixed Income Securities
25

Hedge Funds and Similar Investments
20

Private Equity and Other
14

 
100
%
Schedule of Effect of Significant Unobservable Inputs, Changes in Plan Assets 
Fair Value Measurements Using Significant Unobservable Inputs (Level 3):
 
Year Ended December 31, 2014
 
Year Ended December 31, 2013
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
Hedge Funds
and Similar
Investments
 
Private Equity
and Other
 
Total
 
(In millions)
Beginning Balance at January 1
$
159

 
$
101

 
$
260

 
$
119

 
$
86

 
$
205

Total realized/unrealized gains (losses)
8

 
9

 
17

 
14

 
9

 
23

Purchases, sales and settlements:
 
 
 
 
 
 
 
 
 
 
 
Purchases
9

 
33

 
42

 
26

 
15

 
41

Sales
(8
)
 
(12
)
 
(20
)
 
—

 
(9
)
 
(9
)
Ending Balance at December 31
$
168

 
$
131

 
$
299

 
$
159

 
$
101

 
$
260

The amount of total gains for the period attributable to the change in unrealized gains or losses related to assets still held at the end of the period
$
7

 
$
8

 
$
15

 
$
14

 
$
9

 
$
23

Stock-Based Compensation (Tables)
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs [Table Text Block] 
The following table summarizes the components of stock-based compensation:
 
2014
 
2013
 
2012
 
(In millions)
Stock-based compensation expense
$
103

 
$
99

 
$
83

Tax benefit
40

 
38

 
33

Stock-based compensation cost capitalized in property, plant and equipment
16

 
15

 
5

Schedule of Share-based Compensation, Stock Options, Activity 
The following table summarizes our stock option activity for the year ended December 31, 2014:
 
Number of Options
 
Weighted Average Exercise Price
 
Aggregate Intrinsic
Value
(In millions)
Options outstanding at December 31, 2013
723,697

 
$
42.60

 
 
Granted
—

 
$
—

 
 
Exercised
(268,689
)
 
$
41.14

 
 
Forfeited or expired
(10,730
)
 
$
39.41

 
 
Options outstanding and exercisable at December 31, 2014
444,278

 
$
43.56

 
$
17

Schedule of Share-based Compensation, Shares Authorized under Stock Option Plans, by Exercise Price Range 
The number, weighted average exercise price and weighted average remaining contractual life of options outstanding were as follows:
Range of Exercise Prices
 
Number of Options
 
Weighted Average
Exercise Price
 
Weighted Average
Remaining Contractual Life (Years)
$
27.00
 —
 
$
38.00

 
25,857

 
$
27.70

 
4.16
$
38.01
 —
 
$
42.00

 
82,834

 
$
41.77

 
3.16
$
42.01
 —
 
$
45.00

 
221,487

 
$
43.93

 
4.06
$
45.01
 —
 
$
50.00

 
114,100

 
$
47.75

 
2.15
 
 
 
 
444,278

 
$
43.56

 
3.41
Schedule of Share-based Compensation, Restricted Stock Units Award Activity [Table Text Block] 
Stock award activity for the years ended December 31 was:
 
2014
 
2013
 
2012
Fair value of awards vested (in millions)
$
11

 
$
8

 
$
9

Restricted common shares awarded
159,590

 
127,785

 
167,320

Weighted average market price of shares awarded
$
70.09

 
$
64.72

 
$
53.71

Compensation cost charged against income (in millions)
$
10

 
$
23

 
$
12

Schedule of Share-based Compensation, Restricted Stock and Restricted Stock Units Activity [Table Text Block] 
The following table summarizes the Company’s restricted stock awards activity for the year ended December 31, 2014:
 
Restricted
Stock
 
Weighted Average
Grant Date
Fair Value
Balance at December 31, 2013
492,329

 
$
53.76

Grants
159,590

 
$
70.09

Forfeitures
(16,841
)
 
$
62.41

Vested and issued
(218,760
)
 
$
47.77

Balance at December 31, 2014
416,318

 
$
62.82

Share Based Compensation Expense [Table Text Block] 
The Company recorded compensation expense for performance share awards as follows:
 
2014
 
2013
 
2012
 
(In millions)
Compensation expense
$
93

 
$
77

 
$
71

Cash settlements (a)
$
11

 
$
9

 
$
4

Stock settlements (a)
$
61

 
$
56

 
$
41


_______________________________________
(a)
Sum of cash and stock settlements approximates the intrinsic value of the liability.
Disclosure of Share-based Compensation Arrangements by Share-based Payment Award 
The following table summarizes the Company’s performance share activity for the period ended December 31, 2014:
 
 Performance Shares
 
Weighted Average
Grant Date
Fair Value
Balance at December 31, 2013
1,608,789

 
$
—

Grants
561,335

 
$
69.32

Forfeitures
(44,250
)
 
$
69.16

Payouts
(571,177
)
 
$
—

Balance at December 31, 2014
1,554,697

 
$
69.32

Schedule of Unrecognized Compensation Cost, Nonvested Awards 
As of December 31, 2014, the total unrecognized compensation cost related to non-vested stock incentive plan arrangements and the weighted average recognition period was as follows:
 
Unrecognized
Compensation
Cost
 
Weighted Average
to be Recognized
 
(In millions)
 
(In years)
Stock awards
$
10

 
1.06
Performance shares
48

 
0.98
 
$
58

 
0.99
Segment and Related Information (Tables)
Schedule of Segment Reporting Information, by Segment
Inter-segment billing for goods and services exchanged between segments is based upon tariffed or market-based prices of the provider and primarily consists of the sale of reduced emissions fuel, power sales and natural gas sales in the following segments:
 
2014
 
2013
 
2012
 
(In millions)
Electric
$
29

 
$
26

 
$
29

Gas
6

 
4

 
4

Power and Industrial Projects
794

 
816

 
801

Gas Storage and Pipelines
9

 
3

 
6

Energy Trading
33

 
43

 
43

Corporate and Other
3

 
(24
)
 
(37
)
Discontinued Operations
—

 
—

 
2

 
$
874

 
$
868

 
$
848


Financial data of the business segments follows:
 
Operating
Revenue
 
Depreciation,
Depletion &
Amortization
 
Interest
Income
 
Interest
Expense
 
Income
Tax Expense (Benefit)
 
Net Income (Loss)
Attributable
to DTE
Energy
Company
 
Total
Assets
 
Goodwill
 
Capital
Expenditures and Acquisitions
 
(In millions)
2014
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric
$
5,283

 
$
933

 
$
(1
)
 
$
250

 
$
296

 
$
528

 
$
18,715

 
$
1,208

 
$
1,561

Gas
1,636

 
99

 
(7
)
 
57

 
78

 
140

 
4,283

 
743

 
224

Power and Industrial Projects
2,289

 
77

 
(5
)
 
28

 
(100
)
 
90

 
1,009

 
26

 
77

Gas Storage and Pipelines
203

 
34

 
(6
)
 
22

 
53

 
82

 
884

 
24

 
184

Energy Trading
3,762

 
1

 
—

 
7

 
77

 
122

 
755

 
17

 
3

Corporate and Other
2

 
1

 
(48
)
 
122

 
(40
)
 
(57
)
 
3,209

 
—

 
—

Reclassifications and Eliminations
(874
)
 
—

 
57

 
(57
)
 
—

 
—

 
(881
)
 
—

 
—

Total
$
12,301

 
$
1,145

 
$
(10
)
 
$
429

 
$
364

 
$
905

 
$
27,974

 
$
2,018

 
$
2,049

 
Operating
Revenue
 
Depreciation,
Depletion &
Amortization
 
Interest
Income
 
Interest
Expense
 
Income
Tax Expense (Benefit)
 
Net Income (Loss)
Attributable
to DTE
Energy
Company
 
Total
Assets
 
Goodwill
 
Capital
Expenditures and Acquisitions
 
(In millions)
2013
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric
$
5,199

 
$
902

 
$
(1
)
 
$
268

 
$
252

 
$
484

 
$
17,508

 
$
1,208

 
$
1,325

Gas
1,474

 
95

 
(7
)
 
58

 
77

 
143

 
3,938

 
743

 
209

Power and Industrial Projects
1,950

 
72

 
(6
)
 
27

 
(45
)
 
66

 
1,067

 
26

 
93

Gas Storage and Pipelines
132

 
23

 
(7
)
 
18

 
45

 
70

 
824

 
24

 
245

Energy Trading
1,771

 
1

 
—

 
8

 
(38
)
 
(58
)
 
623

 
17

 
3

Corporate and Other
3

 
1

 
(51
)
 
120

 
(37
)
 
(44
)
 
2,945

 
—

 
1

Reclassifications and Eliminations
(868
)
 
—

 
63

 
(63
)
 
—

 
—

 
(970
)
 
—

 
—

Total
$
9,661

 
$
1,094

 
$
(9
)
 
$
436

 
$
254

 
$
661

 
$
25,935

 
$
2,018

 
$
1,876

 
Operating
Revenue
 
Depreciation,
Depletion &
Amortization
 
Interest
Income
 
Interest
Expense
 
Income
Tax Expense (Benefit)
 
Net Income (Loss)
Attributable
to DTE
Energy
Company
 
Total
Assets
 
Goodwill
 
Capital
Expenditures and Acquisitions
 
(In millions)
2012
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Electric
$
5,293

 
$
827

 
$
(1
)
 
$
272

 
$
280

 
$
483

 
$
17,755

 
$
1,208

 
$
1,230

Gas
1,315

 
92

 
(7
)
 
59

 
50

 
115

 
4,059

 
745

 
221

Power and Industrial Projects
1,823

 
65

 
(7
)
 
37

 
(44
)
 
42

 
991

 
26

 
281

Gas Storage and Pipelines
96

 
8

 
(8
)
 
8

 
39

 
61

 
668

 
22

 
233

Energy Trading
1,109

 
2

 
—

 
8

 
7

 
12

 
629

 
17

 
1

Corporate and Other
3

 
1

 
(52
)
 
121

 
(46
)
 
(47
)
 
3,074

 
—

 
3

Reclassifications and Eliminations
(848
)
 
—

 
65

 
(65
)
 
—

 
—

 
(837
)
 
—

 
—

Total from Continuing Operations
$
8,791

 
$
995

 
$
(10
)
 
$
440

 
$
286

 
$
666

 
$
26,339

 
$
2,018

 
$
1,969

Discontinued Operations (Note 4)
 
 
 
 
 
 
 
 
 
 
(56
)
 
—

 
—

 
49

Total
 
 
 
 
 
 
 
 
 
 
$
610

 
$
26,339

 
$
2,018

 
$
2,018

Supplementary Quarterly Financial Information (Unaudited ) (Tables)
Schedule of Quarterly Financial Information
Quarterly earnings per share may not equal full year totals, since quarterly computations are based on weighted average common shares outstanding during each quarter.
 
First
Quarter
 
Second
Quarter
 
Third
Quarter
 
Fourth
Quarter
 
Year
 
(In millions, except per share amounts)
2014
 

 
 

 
 

 
 

 
 

Operating Revenues
$
3,930

 
$
2,698

 
$
2,595

 
$
3,078

 
$
12,301

Operating Income
$
560

 
$
249

 
$
239

 
$
542

 
$
1,590

Net Income Attributable to DTE Energy Company
$
326

 
$
124

 
$
156

 
$
299

 
$
905

Basic Earnings per Share
$
1.84

 
$
0.70

 
$
0.88

 
$
1.68

 
$
5.11

Diluted Earnings per Share
$
1.84

 
$
0.70

 
$
0.88

 
$
1.68

 
$
5.10

2013
 

 
 

 
 

 
 

 
 

Operating Revenues
$
2,516

 
$
2,225

 
$
2,387

 
$
2,533

 
$
9,661

Operating Income
$
410

 
$
223

 
$
329

 
$
241

 
$
1,203

Net Income Attributable to DTE Energy Company
$
234

 
$
105

 
$
198

 
$
124

 
$
661

Basic Earnings per Share
$
1.35

 
$
0.60

 
$
1.13

 
$
0.70

 
$
3.76

Diluted Earnings per Share
$
1.34

 
$
0.60

 
$
1.13

 
$
0.70

 
$
3.76

Valuation and Qualifying Accounts (Tables)
Summary of Valuation Allowance
Valuation and Qualifying Accounts
 
Year Ending December 31,
 
2014
 
2013
 
2012
 
(In millions)
Allowance for Doubtful Accounts (shown as deduction from Accounts Receivable in the Consolidated Statements of Financial Position)
 
 
 
 
 
Balance at Beginning of Period
$
55

 
$
62

 
$
162

Additions:
 
 
 
 
 
Charged to costs and expenses
95

 
94

 
79

Charged to other accounts (a)
20

 
23

 
16

Deductions (b)
(116
)
 
(124
)
 
(195
)
Balance at End of Period
$
54

 
$
55

 
$
62

_______________________________________
(a)
Collection of accounts previously written off.
(b)
Uncollectible accounts written off.
Organization and Basis of Presentation (Details Textuals) (USD $)
Dec. 31, 2014
customers
Organization, Consolidation and Presentation of Financial Statements [Abstract]
 
Number of electric utility customers
2,100,000 
Number of gas utility customers
1,200,000 
Significant potential exposure to loss due to VIE long-term purchase contracts
$ 0 
Organization and Basis of Presentation (Consolidated Variable Interest Entities) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Dec. 31, 2011
Assets [Abstract]
 
 
 
 
Cash and cash equivalents
$ 48 
$ 52 
$ 65 
$ 68 
Restricted cash
120 
123 
 
 
Accounts receivable
1,504 
1,542 
 
 
Property, plant and equipment, net
16,820 
15,800 
 
 
Securitized regulatory assets
34 
231 
 
 
Total Assets
27,974 
25,935 
26,339 
 
Liabilities [Abstract]
 
 
 
 
Current portion long-term debt, including capital leases
274 
898 
 
 
Current regulatory liabilities
153 
302 
 
 
Mortgage bonds, notes and other
7,860 
6,618 
 
 
Securitization bonds
0 
105 
 
 
Capital lease obligations
3 
11 
 
 
Variable Interest Entity, Primary Beneficiary Securitization [Member]
 
 
 
 
Assets [Abstract]
 
 
 
 
Cash and cash equivalents
0 
0 
 
 
Restricted cash
96 
100 
 
 
Accounts receivable
26 
34 
 
 
Inventories
0 
0 
 
 
Property, plant and equipment, net
0 
0 
 
 
Securitized regulatory assets
34 
231 
 
 
Other current and long term assets
1 
4 
 
 
Total Assets
157 
369 
 
 
Liabilities [Abstract]
 
 
 
 
Accounts payable and accrued current liabilities
3 
7 
 
 
Current portion long-term debt, including capital leases
105 
196 
 
 
Current regulatory liabilities
32 
43 
 
 
Mortgage bonds, notes and other
0 
0 
 
 
Securitization bonds
0 
105 
 
 
Capital lease obligations
0 
0 
 
 
Other current and long term liabilities
9 
8 
 
 
Total Liabilities
149 
359 
 
 
Variable Interest Entity, Primary Beneficiary Other, Restricted [Member]
 
 
 
 
Assets [Abstract]
 
 
 
 
Cash and cash equivalents
7 
12 
 
 
Restricted cash
8 
8 
 
 
Accounts receivable
15 
16 
 
 
Inventories
67 
118 
 
 
Property, plant and equipment, net
81 
99 
 
 
Securitized regulatory assets
0 
0 
 
 
Other current and long term assets
6 
9 
 
 
Total Assets
184 
262 
 
 
Liabilities [Abstract]
 
 
 
 
Accounts payable and accrued current liabilities
8 
23 
 
 
Current portion long-term debt, including capital leases
10 
9 
 
 
Current regulatory liabilities
0 
0 
 
 
Mortgage bonds, notes and other
15 
21 
 
 
Securitization bonds
0 
0 
 
 
Capital lease obligations
3 
7 
 
 
Other current and long term liabilities
6 
6 
 
 
Total Liabilities
42 
66 
 
 
Variable Interest Entity, Primary Beneficiary, Restricted [Member]
 
 
 
 
Assets [Abstract]
 
 
 
 
Cash and cash equivalents
7 
12 
 
 
Restricted cash
104 
108 
 
 
Accounts receivable
41 
50 
 
 
Inventories
67 
118 
 
 
Property, plant and equipment, net
81 
99 
 
 
Securitized regulatory assets
34 
231 
 
 
Other current and long term assets
7 
13 
 
 
Total Assets
341 
631 
 
 
Liabilities [Abstract]
 
 
 
 
Accounts payable and accrued current liabilities
11 
30 
 
 
Current portion long-term debt, including capital leases
115 
205 
 
 
Current regulatory liabilities
32 
43 
 
 
Mortgage bonds, notes and other
15 
21 
 
 
Securitization bonds
0 
105 
 
 
Capital lease obligations
3 
7 
 
 
Other current and long term liabilities
15 
14 
 
 
Total Liabilities
$ 191 
$ 425 
 
 
Organization and Basis of Presentation (Non Consolidated Variable Interest Entities) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Variable Interest Entity [Line Items]
 
 
Notes receivable
$ 90 
$ 102 
Variable Interest Entity, NonConsolidated [Member]
 
 
Variable Interest Entity [Line Items]
 
 
Other investments
134 
141 
Notes receivable
$ 15 
$ 8 
Significant Accounting Policies Significant Accounting Policics (Accumulated Other Comprehensive Loss) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
 
 
 
Beginning balance
$ (136)
$ (158)
 
Other comprehensive income (loss) before reclassifications
(26)
13 
 
Amounts reclassified from accumulated other comprehensive income
7 
9 
 
Other comprehensive income
(19)
22 
0 
Ending balance
(155)
(136)
(158)
Net Unrealized Gain/(Loss) on Derivatives [Member]
 
 
 
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
 
 
 
Beginning balance
(4)
(4)
 
Other comprehensive income (loss) before reclassifications
0 
0 
 
Amounts reclassified from accumulated other comprehensive income
0 
0 
 
Other comprehensive income
0 
0 
 
Ending balance
(4)
(4)
 
Net Unrealized Gain/(Loss) on Investments [Member]
 
 
 
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
 
 
 
Beginning balance
(6)
(8)
 
Other comprehensive income (loss) before reclassifications
1 
2 
 
Amounts reclassified from accumulated other comprehensive income
0 
0 
 
Other comprehensive income
1 
2 
 
Ending balance
(5)
(6)
 
Benefit Obligations [Member]
 
 
 
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
 
 
 
Beginning balance
(126)
(148)
 
Other comprehensive income (loss) before reclassifications
(25)
13 
 
Amounts reclassified from accumulated other comprehensive income
7 
9 
 
Other comprehensive income
(18)
22 
 
Ending balance
(144)
(126)
 
Foreign Currency Translation [Member]
 
 
 
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward]
 
 
 
Beginning balance
0 
2 
 
Other comprehensive income (loss) before reclassifications
(2)
(2)
 
Amounts reclassified from accumulated other comprehensive income
0 
0 
 
Other comprehensive income
(2)
(2)
 
Ending balance
$ (2)
$ 0 
 
Significant Accounting Policies (Intangible Assets) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
 
 
Intangible Assets, Gross (Excluding Goodwill)
$ 168 
$ 179 
Less: Accumulated Amortization
57 
45 
Intangible Assets, Net
111 
134 
Less current intangible assets
9 
12 
Intangible assets, noncurrent
102 
122 
Renewable Energy Credits [Member]
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
Intangible Assets, Gross
45 
51 
Contract Intangible Assets [Member]
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
Intangible Assets, Gross
122 
126 
Emission Allowances [Member]
 
 
Finite-Lived Intangible Assets [Line Items]
 
 
Indefinite-Lived Intangible Assets (Excluding Goodwill)
$ 1 
$ 2 
Significant Accounting Policies (Future Amortization Expense Intangible Assets) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Finite-Lived Intangible Assets, Net, Amortization Expense, Fiscal Year Maturity [Abstract]
 
2015
$ 12 
2016
11 
2017
8 
2018
8 
2019
$ 6 
Significant Accounting Policies (Details Textuals) (USD $)
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Significant Accounting Policies [Line Items]
 
 
 
Other income
$ 196,000,000 
$ 201,000,000 
$ 173,000,000 
Receivables due date
21 days 
 
 
Threshold period past due for write-off of trade accounts receivable
150 days 
 
 
Specific review of probable future collections based on receivable balances in excess of 90 days
30 days 
 
 
Unbilled revenues
1,504,000,000 
1,542,000,000 
 
Regulatory liabilities
820,000,000 
1,164,000,000 
 
Property maintenance accrual period
18 months 
 
 
Amortization of Intangible Assets
12,000,000 
14,000,000 
6,000,000 
Excise and sales taxes net impact on statement of operations
0 
 
 
Charitable Contributions to a Foundation
25,000,000 
18,000,000 
21,000,000 
Refueling Outage [Member]
 
 
 
Significant Accounting Policies [Line Items]
 
 
 
Regulatory liabilities
16,000,000 
26,000,000 
 
Minimum [Member]
 
 
 
Significant Accounting Policies [Line Items]
 
 
 
Notes receivable considered delinquent period
60 days 
 
 
Finite-lived intangible asset, useful life
1 year 
 
 
Maximum
 
 
 
Significant Accounting Policies [Line Items]
 
 
 
Notes receivable considered delinquent period
120 days 
 
 
Finite-lived intangible asset, useful life
27 years 
 
 
Unbilled Revenues [Member]
 
 
 
Significant Accounting Policies [Line Items]
 
 
 
Unbilled revenues
773,000,000 
815,000,000 
 
Public Utilities, Inventory, Natural Gas [Member]
 
 
 
Significant Accounting Policies [Line Items]
 
 
 
LIFO inventory amount
43,000,000 
4,000,000 
 
Excess of replacement costs over stated LIFO value
110,000,000 
170,000,000 
 
Power and Industrial Projects [Member]
 
 
 
Significant Accounting Policies [Line Items]
 
 
 
Other income
$ 78,000,000 
$ 81,000,000 
$ 63,000,000 
Discontinued Operations (Details Textuals) (USD $)
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
 
 
 
Proceeds from divestiture of business
$ 0 
$ 0 
$ 255,000,000 
Discontinued Operations [Member]
 
 
 
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
 
 
 
Percentage of disposal of equity interest in segment percentage
 
 
100.00% 
Proceeds from divestiture of business
 
 
255,000,000 
Loss from disposal before tax
 
 
83,000,000 
Loss from disposal, net of tax
 
 
55,000,000 
Allocation of corporate interest costs
 
 
$ 0 
Discontinued Operations (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
 
 
 
Total operating expenses
$ 10,711 
$ 8,458 
$ 7,512 
Income Tax Benefit
0 
0 
(29)
Net Loss Attributable to DTE Energy Company
0 
0 
(56)
Segment, Discontinued Operations [Member]
 
 
 
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
 
 
 
Operating Revenues
 
 
55 
Operation and maintenance
 
 
24 
Depreciation, depletion and amortization
 
 
23 
Taxes other than income
 
 
4 
Asset (gains) losses, net
 
 
83 
Total operating expenses
 
 
134 
Operating Loss
 
 
(79)
Other (Income) and Deductions
 
 
6 
Loss Before Income Taxes
 
 
(85)
Income Tax Benefit
 
 
(29)
Net Loss Attributable to DTE Energy Company
 
 
$ (56)
Property, Plant and Equipment (Summary of Property by Classification) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Property, Plant and Equipment [Line Items]
 
 
Property, Plant and Equipment - Non-utility and other
$ 2,476 
$ 2,292 
Property, plant and equipment, Total
26,538 
25,123 
Less Accumulated Depreciation, Depletion and Amortization - Nonutility and Other
(867)
(767)
Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment
(9,718)
(9,323)
Property, plant and equipment
16,820 
15,800 
Electric Generation Equipment [Member]
 
 
Property, Plant and Equipment [Line Items]
 
 
Property Plant and Equipment - Generation
11,641 
11,127 
Accumulated Depreciation, Depletion and Amortization
(4,149)
(4,004)
Electric Distribution [Member]
 
 
Property, Plant and Equipment [Line Items]
 
 
Property Plant and Equipment - Distribution
8,164 
7,603 
Accumulated Depreciation, Depletion and Amortization
(3,067)
(2,947)
Electric Generation, Transmission and Distribution Equipment [Member]
 
 
Property, Plant and Equipment [Line Items]
 
 
Public Utilities, Property, Plant and Equipment, Plant in Service
19,805 
18,730 
Accumulated Depreciation, Depletion and Amortization
(7,216)
(6,951)
Gas Distribution [Member]
 
 
Property, Plant and Equipment [Line Items]
 
 
Property Plant and Equipment - Distribution
2,946 
2,834 
Accumulated Depreciation, Depletion and Amortization
(1,130)
(1,129)
Storage [Member]
 
 
Property, Plant and Equipment [Line Items]
 
 
Property, Plant and Equipment - Storage
448 
431 
Accumulated Depreciation, Depletion and Amortization
(142)
(138)
Other [Member]
 
 
Property, Plant and Equipment [Line Items]
 
 
Property, Plant and Equipment - Other
863 
836 
Accumulated Depreciation, Depletion and Amortization
(363)
(338)
Gas Distribution and Storage [Member]
 
 
Property, Plant and Equipment [Line Items]
 
 
Public Utilities, Property, Plant and Equipment, Plant in Service
4,257 
4,101 
Accumulated Depreciation, Depletion and Amortization
$ (1,635)
$ (1,605)
Property, Plant and Equipment (Average Estimated Useful Life of Each Major Class) (Details)
12 Months Ended
Dec. 31, 2014
Electric [Member]
 
Public Utility Property, Plant and Equipment [Line Items]
 
Useful Life - Generation
40 years 
Useful Life - Distribution
41 years 
Gas [Member]
 
Public Utility Property, Plant and Equipment [Line Items]
 
Useful Life - Distribution
50 years 
Useful Life - Storage
53 years 
Property, Plant and Equipment (Details Textuals) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Public Utility Property, Plant and Equipment [Line Items]
 
 
 
AFUDC capitalized
$ 37 
$ 33 
 
Capitalized computer software amortization
77 
71 
68 
Capitalized computer software gross
668 
611 
 
Capitalized computer software accumulated amortization
335 
323 
 
Capital leased assets gross
35 
35 
 
Capital leases, accumulated depreciation
$ 27 
$ 21 
 
Electric [Member]
 
 
 
Public Utility Property, Plant and Equipment [Line Items]
 
 
 
Disclosure of composite depreciation rate for plants in service
3.40% 
3.40% 
3.30% 
Gas [Member]
 
 
 
Public Utility Property, Plant and Equipment [Line Items]
 
 
 
Disclosure of composite depreciation rate for plants in service
2.40% 
2.40% 
2.40% 
Minimum [Member]
 
 
 
Public Utility Property, Plant and Equipment [Line Items]
 
 
 
Property plant and equipment, useful life
3 years 
 
 
Finite-lived intangible asset, useful life
1 year 
 
 
Maximum
 
 
 
Public Utility Property, Plant and Equipment [Line Items]
 
 
 
Property plant and equipment, useful life
55 years 
 
 
Finite-lived intangible asset, useful life
27 years 
 
 
Computer Software, Intangible Asset [Member] |
Minimum [Member]
 
 
 
Public Utility Property, Plant and Equipment [Line Items]
 
 
 
Finite-lived intangible asset, useful life
3 years 
 
 
Computer Software, Intangible Asset [Member] |
Maximum
 
 
 
Public Utility Property, Plant and Equipment [Line Items]
 
 
 
Finite-lived intangible asset, useful life
15 years 
 
 
Jointly Owned Utility Plant (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
MW
Belle River [Member]
 
Jointly Owned Utility Plant Interests [Line Items]
 
Total plant capacity (in MW)
1,270 
Investment (in millions)
$ 1,742 
Accumulated depreciation (in millions)
993 
Ludington Hydroelectric Pumped Storage [Member]
 
Jointly Owned Utility Plant Interests [Line Items]
 
Total plant capacity (in MW)
1,872 
Ownership interest
49.00% 
Investment (in millions)
412 
Accumulated depreciation (in millions)
$ 175 
Jointly Owned Utility Plant (Detail Textuals)
Dec. 31, 2014
facilities
Jointly Owned Utility Plant Interests [Line Items]
 
Jointly Owned Utility Plant Number of Plants
2 
Belle River Unit 1 [Member]
 
Jointly Owned Utility Plant Interests [Line Items]
 
Jointly Owned Utility Plant, Proportionate Ownership Share
63.00% 
Belle River Facilities used jointly by Belle River and St. Clair Power Plants [Member]
 
Jointly Owned Utility Plant Interests [Line Items]
 
Jointly Owned Utility Plant, Proportionate Ownership Share
81.00% 
Belle River [Member]
 
Jointly Owned Utility Plant Interests [Line Items]
 
Joint Owners Percentage of the Total Capacity Energy and Related Responsibilities
19.00% 
Belle River Unit 2 [Member]
 
Jointly Owned Utility Plant Interests [Line Items]
 
Jointly Owned Utility Plant, Proportionate Ownership Share
75.00% 
Ludington Hydroelectric Pumped Storage [Member]
 
Jointly Owned Utility Plant Interests [Line Items]
 
Jointly Owned Utility Plant, Proportionate Ownership Share
49.00% 
Joint Owners Percentage of the Total Capacity Energy and Related Responsibilities
51.00% 
Asset Retirement Obligations (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
 
Asset retirement obligations, beginning balance
$ 1,827 
Accretion
112 
Liabilities incurred
11 
Liabilities settled
(12)
Revision in estimated cash flows
24 
Asset retirement obligations, ending balance
$ 1,962 
Asset Retirement Obligations (Details Textuals) (USD $)
12 Months Ended
Dec. 31, 2014
Asset Retirement Obligations [Line Items]
 
Asset retirement obligations, liability not recognized
Natural gas storage system assets, substations, manholes and certain other distribution assets have an indeterminate life. Therefore, no liability has been recorded for these assets. 
Liabilities balance upon completion of decommissioning
$ 0 
Fermi 2 [Member]
 
Asset Retirement Obligations [Line Items]
 
Nuclear decommissioning liabilities funded through surcharge and included in ARO balance
$ 1,700,000,000 
Regulatory Matters (Schedule of Regulatory Assets) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Regulatory Assets [Line Items]
 
 
Regulatory Assets
$ 3,727 
$ 2,863 
Regulatory Assets, Current
(76)
(26)
Regulatory Assets, Noncurrent
3,651 
2,837 
Securitized Regulatory Assets, Noncurrent
34 
231 
Pension Costs [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
2,284 
1,660 
Postretirment Costs [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
234 
0 
Asset Retirement Obligation Costs [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
448 
394 
Recoverable Michigan Income Taxes [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
267 
286 
Unamortized Loss on Reacquired Debt [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
67 
63 
Other Recoverabe Income Taxes [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
66 
71 
Accrued PSCR/GCR Revenue [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
61 
0 
Deferred Environmental Costs [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
59 
59 
Cost to Achieve Performance Excellence Process [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
54 
75 
Recoverable Income Taxes related to Securitized Regulatory Assets [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
19 
126 
Unrecovered Removal Costs [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
15 
0 
Transitional Recovery Mechanism [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
14 
0 
Other Assets [Member]
 
 
Regulatory Assets [Line Items]
 
 
Regulatory Assets
$ 139 
$ 129 
Regulatory Matters Regulatory Matters (Schedule of Regulatory Liabilities) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
$ 820 
$ 1,164 
Regulatory Liability, Current
(153)
(302)
Regulatory Liability, Noncurrent
667 
862 
Removal Costs [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
308 
351 
Renewable Energy [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
227 
277 
Over Recovery of Securitization [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
71 
72 
Refundable Revenue Decoupling [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
67 
127 
Pension Costs [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
67 
84 
Refundable Income Taxes [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
33 
45 
Energy Optimization [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
24 
31 
Refueling Outage [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
16 
26 
Refundable postretirement costs [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
0 
72 
Accrued PSCR GCR Refund [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
0 
65 
Other Liabilities [Member]
 
 
Regulatory Liabilities [Line Items]
 
 
Regulatory liabilities
$ 7 
$ 14 
Regulatory Matters (Details Textuals) (USD $)
12 Months Ended 0 Months Ended 3 Months Ended 12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2014
Refundable Revenue Decoupling [Member]
Dec. 31, 2013
Refundable Revenue Decoupling [Member]
Sep. 30, 2014
Electric [Member]
Jul. 30, 2012
Electric [Member]
Jan. 1, 2014
Electric [Member]
Refundable Revenue Decoupling [Member]
Sep. 30, 2012
Electric [Member]
Refundable Revenue Decoupling [Member]
Dec. 19, 2014
MPSC [Member]
Electric [Member]
Mar. 31, 2013
MPSC [Member]
Electric [Member]
Dec. 31, 2014
MPSC [Member]
Electric [Member]
Sep. 26, 2014
MPSC [Member]
Electric [Member]
Aug. 31, 2013
MPSC [Member]
Electric [Member]
Nov. 30, 2014
MPSC [Member]
Gas [Member]
Regulatory Assets [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Time period required by non-bypassable securitization bond surcharge to recover securitized regulatory asset
14 years 
 
 
 
 
 
 
 
 
 
 
 
 
 
Public utilities, requested rate increase (decrease)
 
 
 
 
 
 
 
 
$ 370,000,000 
 
 
 
 
 
Amortization period of cost to achieve deferral
10 years 
 
 
 
 
 
 
 
 
 
 
 
 
 
Deferral of investigation and remediation of costs associated with gas utilities former MGP sites
10 years 
 
 
 
 
 
 
 
 
 
 
 
 
 
Rate increase previously authorized by the MPSC challenged by Court of Appeals reopened by the MPSC
 
 
 
 
 
 
 
 
 
 
 
 
11,000,000 
 
Approved recovery amount for customer 360
 
 
 
 
 
 
 
 
 
 
 
215,000,000 
 
 
Approved amortization period for customer 360 recovery
 
 
 
 
 
 
 
 
 
 
15 years 
 
 
 
Regulatory liabilities
820,000,000 
1,164,000,000 
67,000,000 
127,000,000 
 
 
 
127,000,000 
 
 
 
 
 
 
Monthly amount to amortize from liability to income
 
 
 
 
 
 
10,600,000 
 
 
 
 
 
 
 
PSCR under-recovery from 2 plan years prior
 
 
 
 
 
 
 
 
 
87,000,000 
 
 
 
 
PSCR under-recovery from 3 plan years prior
 
 
 
 
 
 
 
 
 
148,000,000 
 
 
 
 
Fermi 2 production level of full capacity
 
 
 
 
 
68.00% 
 
 
 
 
 
 
 
 
Maximum of challenged Fermi 2 outage charges
 
 
 
 
32,000,000 
 
 
 
 
 
 
 
 
 
Infrastructure recovery mechanism surcharge
 
 
 
 
 
 
 
 
 
 
 
 
 
$ 47,000,000 
Income Taxes (Reconciliation of Income Tax Expense to the Statutory Federal Income Tax Rate) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Effective Income Tax Rate Reconciliation, Amount [Abstract]
 
 
 
Income before income taxes
$ 1,275 
$ 922 
$ 960 
Income tax expense at 35% statutory rate
446 
323 
336 
Production tax credits
(119)
(68)
(49)
Investment tax credits
(6)
(6)
(6)
Depreciation
(4)
(4)
(4)
AFUDC - Equity
(7)
(5)
(4)
Employee Stock Ownership Plan dividends
(4)
(4)
(4)
Domestic production activities deduction
0 
(14)
(14)
State and local income taxes, net of federal benefit
51 
37 
37 
Enactment of New York Corporate Income Tax Legislation, net of federal benefit
8 
0 
0 
Other, net
(1)
(5)
(6)
Income tax expense
$ 364 
$ 254 
$ 286 
Effective income tax rate (as percent)
28.50% 
27.50% 
29.80% 
Income Taxes (Components of Income Tax Expense) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Current income tax expense (benefit)
 
 
 
Federal
$ (16)
$ 74 
$ 190 
State and other income tax
24 
16 
49 
Total current income taxes
8 
90 
239 
Deferred income tax expense
 
 
 
Federal
289 
122 
39 
State and other income tax
67 
42 
8 
Total deferred income taxes
356 
164 
47 
Income tax expense
364 
254 
286 
Discontinued operations
0 
0 
(29)
Total
$ 364 
$ 254 
$ 257 
Income Taxes (Deferred Tax Assets (Liabilities)) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Components of Deferred Tax Assets and Liabilities [Abstract]
 
 
Property, plant and equipment
$ (3,832)
$ (3,372)
Securitized regulatory assets
(2)
(127)
Tax credit carry-forwards
296 
266 
Pension and benefits
(152)
(30)
State net operating loss and credit carry-forwards
39 
43 
Deferred Tax Liabilities, Other
(19)
(92)
Deferred Tax Liabilities, Gross
(3,670)
(3,312)
Less valuation allowance
(31)
(37)
Current deferred income tax assets (liabilities)
75 
(28)
Long-term deferred income tax liabilities
(3,776)
(3,321)
Deferred income tax assets
861 
934 
Deferred income tax liabilities
(4,562)
(4,283)
Deferred income tax liabilities
$ (3,701)
$ (3,349)
Income Taxes (Reconciliation of Unrecognized Tax Benefits) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
 
 
 
Unrecognized Tax Benefits, beginning balance
$ 10 
$ 11 
$ 48 
Reductions for tax positions of prior years
0 
0 
(2)
Additions for tax positions of current year
0 
0 
1 
Settlements
0 
0 
(30)
Lapse of statute of limitations
(1)
(1)
(6)
Unrecognized Tax Benefits, ending balance
$ 9 
$ 10 
$ 11 
Income Taxes (Details Textuals) (USD $)
12 Months Ended
Dec. 31, 2012
Dec. 31, 2014
Dec. 31, 2013
Income Tax Disclosure [Abstract]
 
 
 
Deferred tax asset, general business tax credit carryforwards
 
$ 29,000,000 
 
Deferred tax asset, alternative minimum tax credit carryforwards
 
267,000,000 
 
Deferred tax assets, state net operating loss and credit carry-forwards
 
39,000,000 
43,000,000 
Valuation allowance
 
31,000,000 
37,000,000 
Unrecognized tax benefits that would impact effective tax rate
 
2,000,000 
2,000,000 
Significant change in unrecognized tax benefit is reasonable possible, amount of unrecorded benefit
 
6,000,000 
 
Interest on income taxes accrued
 
1,000,000 
1,000,000 
Income tax penalties accrued
 
0 
 
Interest on income taxes expense
$ (1,000,000)
 
 
Earnings Per Share (Details) (USD $)
In Millions, except Per Share data, unless otherwise specified
3 Months Ended 12 Months Ended
Dec. 31, 2014
Sep. 30, 2014
Jun. 30, 2014
Mar. 31, 2014
Dec. 31, 2013
Sep. 30, 2013
Jun. 30, 2013
Mar. 31, 2013
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Basic Earnings per Share
 
 
 
 
 
 
 
 
 
 
 
Net Income Attributable to DTE Energy Company
$ 299 
$ 156 
$ 124 
$ 326 
$ 124 
$ 198 
$ 105 
$ 234 
$ 905 
$ 661 
$ 610 
Average number of common shares outstanding (in shares)
 
 
 
 
 
 
 
 
177 
175 
171 
Weighted average net restricted shares outstanding (in shares)
 
 
 
 
 
 
 
 
0 
1 
1 
Dividends declared — common shares
 
 
 
 
 
 
 
 
475 
453 
413 
Dividends declared — net restricted shares
 
 
 
 
 
 
 
 
1 
1 
1 
Total distributed earnings
 
 
 
 
 
 
 
 
476 
454 
414 
Net income less distributed earnings
 
 
 
 
 
 
 
 
429 
207 
196 
Distributed (dividends per common share) (in dollars per share)
 
 
 
 
 
 
 
 
$ 2.69 
$ 2.59 
$ 2.42 
Undistributed (in dollars per share)
 
 
 
 
 
 
 
 
$ 2.42 
$ 1.17 
$ 1.14 
Total (in dollars per share)
$ 1.68 
$ 0.88 
$ 0.70 
$ 1.84 
$ 0.70 
$ 1.13 
$ 0.60 
$ 1.35 
$ 5.11 
$ 3.76 
$ 3.56 
Diluted Earnings per Share
 
 
 
 
 
 
 
 
 
 
 
Net Income Attributable to DTE Energy Company
299 
156 
124 
326 
124 
198 
105 
234 
905 
661 
610 
Average number of common shares outstanding (in shares)
 
 
 
 
 
 
 
 
177 
175 
171 
Average incremental shares from assumed exercise of options (in shares)
 
 
 
 
 
 
 
 
0 
0 
1 
Common shares for dilutive calculation (in shares)
 
 
 
 
 
 
 
 
177 
175 
172 
Weighted average net restricted shares outstanding (in shares)
 
 
 
 
 
 
 
 
0 
1 
1 
Dividends declared — common shares
 
 
 
 
 
 
 
 
475 
453 
413 
Dividends declared — net restricted shares
 
 
 
 
 
 
 
 
1 
1 
1 
Total distributed earnings
 
 
 
 
 
 
 
 
476 
454 
414 
Net income less distributed earnings
 
 
 
 
 
 
 
 
$ 429 
$ 207 
$ 196 
Distributed (dividends per common share)
 
 
 
 
 
 
 
 
$ 2.69 
$ 2.59 
$ 2.42 
Undistributed (in dollars per share)
 
 
 
 
 
 
 
 
$ 2.41 
$ 1.17 
$ 1.13 
Total (in dollars per share)
$ 1.68 
$ 0.88 
$ 0.70 
$ 1.84 
$ 0.70 
$ 1.13 
$ 0.60 
$ 1.34 
$ 5.10 
$ 3.76 
$ 3.55 
Fair Value (Assets and Liabilities Recorded at Fair Value on a Recurring Basis) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Assets [Abstract]
 
 
Nuclear decommissioning trusts
$ 1,241 
$ 1,191 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
1,178 
833 
Derivative asset, Netting
(1,006)
(707)
Derivative assets, net
172 
126 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(1,110)
(936)
Derivative liability, netting
1,025 
698 
Derivative Liabilities, net
(85)
(238)
Current Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(1,041)
(773)
Noncurrent Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(69)
(163)
Natural Gas Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
787 
396 
Derivative asset, Netting
(681)
(382)
Derivative assets, net
106 
14 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(718)
(503)
Derivative liability, netting
679 
395 
Derivative Liabilities, net
(39)
(108)
Electricity Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
342 
400 
Derivative asset, Netting
(280)
(291)
Derivative assets, net
62 
109 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(342)
(398)
Derivative liability, netting
298 
269 
Derivative Liabilities, net
(44)
(129)
Other Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
45 
37 
Derivative asset, Netting
(42)
(34)
Derivative assets, net
3 
3 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(45)
(34)
Derivative liability, netting
45 
34 
Derivative Liabilities, net
0 
0 
Other Derivative Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
4 
0 
Derivative asset, Netting
(3)
0 
Derivative assets, net
1 
0 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(5)
(1)
Derivative liability, netting
3 
0 
Derivative Liabilities, net
(2)
(1)
Recurring [Member]
 
 
Assets [Abstract]
 
 
Cash equivalents
112 
125 
Nuclear decommissioning trusts
1,241 
1,191 
Other Investments
150 
136 
Derivative Asset [Abstract]
 
 
Derivative asset, Netting
(1,006)
(707)
Derivative assets, net
172 
126 
Total assets
1,675 
1,578 
Liabilities [Abstract]
 
 
Derivative liability, netting
1,025 
698 
Derivative Liabilities, net
(85)
(238)
Net Assets (Liabilities) at the end of the period
1,590 
1,340 
Net Assets (Liabilities) at the end of the period, netting
19 
(9)
Recurring [Member] |
Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, Netting
(955)
(592)
Total assets
240 
224 
Recurring [Member] |
Non Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, Netting
(51)
(115)
Total assets
1,435 
1,354 
Recurring [Member] |
Current Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Derivative liability, netting
964 
578 
Derivative Liabilities, net
(77)
(195)
Recurring [Member] |
Noncurrent Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Derivative liability, netting
61 
120 
Derivative Liabilities, net
(8)
(43)
Recurring [Member] |
Natural Gas Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, Netting
(681)
(382)
Derivative assets, net
106 
14 
Liabilities [Abstract]
 
 
Derivative liability, netting
679 
395 
Derivative Liabilities, net
(39)
(108)
Recurring [Member] |
Electricity Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, Netting
(280)
(291)
Derivative assets, net
62 
109 
Liabilities [Abstract]
 
 
Derivative liability, netting
298 
269 
Derivative Liabilities, net
(44)
(129)
Recurring [Member] |
Other Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, Netting
(42)
(34)
Derivative assets, net
3 
3 
Liabilities [Abstract]
 
 
Derivative liability, netting
45 
34 
Derivative Liabilities, net
0 
0 
Recurring [Member] |
Other Derivative Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, Netting
(3)
0 
Derivative assets, net
1 
0 
Liabilities [Abstract]
 
 
Derivative liability, netting
3 
0 
Derivative Liabilities, net
(2)
(1)
Recurring [Member] |
Level 1 [Member]
 
 
Assets [Abstract]
 
 
Cash equivalents
13 
10 
Nuclear decommissioning trusts
792 
779 
Other Investments
100 
92 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
597 
306 
Total assets
1,502 
1,187 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(610)
(309)
Net Assets (Liabilities) at the end of the period
892 
878 
Recurring [Member] |
Level 1 [Member] |
Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Total assets
582 
277 
Recurring [Member] |
Level 1 [Member] |
Non Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Total assets
920 
910 
Recurring [Member] |
Level 1 [Member] |
Current Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(572)
(268)
Recurring [Member] |
Level 1 [Member] |
Noncurrent Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(38)
(41)
Recurring [Member] |
Level 1 [Member] |
Natural Gas Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
555 
273 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(578)
(277)
Recurring [Member] |
Level 1 [Member] |
Electricity Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
0 
0 
Liabilities [Abstract]
 
 
Total fair value of derivatives
0 
0 
Recurring [Member] |
Level 1 [Member] |
Other Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
42 
33 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(32)
(32)
Recurring [Member] |
Level 1 [Member] |
Other Derivative Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
0 
0 
Liabilities [Abstract]
 
 
Total fair value of derivatives
0 
0 
Recurring [Member] |
Level 2 [Member]
 
 
Assets [Abstract]
 
 
Cash equivalents
99 
115 
Nuclear decommissioning trusts
449 
412 
Other Investments
50 
44 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
439 
351 
Total assets
1,037 
922 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(382)
(415)
Net Assets (Liabilities) at the end of the period
655 
507 
Recurring [Member] |
Level 2 [Member] |
Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Total assets
504 
400 
Recurring [Member] |
Level 2 [Member] |
Non Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Total assets
533 
522 
Recurring [Member] |
Level 2 [Member] |
Current Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(357)
(328)
Recurring [Member] |
Level 2 [Member] |
Noncurrent Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(25)
(87)
Recurring [Member] |
Level 2 [Member] |
Natural Gas Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
140 
89 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(78)
(140)
Recurring [Member] |
Level 2 [Member] |
Electricity Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
295 
261 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(290)
(272)
Recurring [Member] |
Level 2 [Member] |
Other Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
0 
1 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(9)
(2)
Recurring [Member] |
Level 2 [Member] |
Other Derivative Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
4 
0 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(5)
(1)
Recurring [Member] |
Level 3 [Member]
 
 
Assets [Abstract]
 
 
Cash equivalents
0 
0 
Nuclear decommissioning trusts
0 
0 
Other Investments
0 
0 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
142 
176 
Total assets
142 
176 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(118)
(212)
Net Assets (Liabilities) at the end of the period
24 
(36)
Recurring [Member] |
Level 3 [Member] |
Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Total assets
109 
139 
Recurring [Member] |
Level 3 [Member] |
Non Current Asset [Member]
 
 
Derivative Asset [Abstract]
 
 
Total assets
33 
37 
Recurring [Member] |
Level 3 [Member] |
Current Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(112)
(177)
Recurring [Member] |
Level 3 [Member] |
Noncurrent Derivative Liability [Member]
 
 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(6)
(35)
Recurring [Member] |
Level 3 [Member] |
Natural Gas Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
92 
34 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(62)
(86)
Recurring [Member] |
Level 3 [Member] |
Electricity Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
47 
139 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(52)
(126)
Recurring [Member] |
Level 3 [Member] |
Other Commodity Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
3 
3 
Liabilities [Abstract]
 
 
Total fair value of derivatives
(4)
0 
Recurring [Member] |
Level 3 [Member] |
Other Derivative Contract [Member]
 
 
Derivative Asset [Abstract]
 
 
Derivative asset, gross
0 
0 
Liabilities [Abstract]
 
 
Total fair value of derivatives
$ 0 
$ 0 
Fair Value (Reconciliation of Level 3 Assets and Liabilities at Fair Value on a Recurring Basis) (Details) (USD $)
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
 
 
Net Assets (Liabilities) as of December 31
$ (36,000,000)
$ (13,000,000)
Transfers into Level 3 from Level 2
0 
1,000,000 
Transfers from Level 3 into Level 2
(2,000,000)
0 
Total gains (losses):
 
 
Included in earnings
(20,000,000)
43,000,000 
Recorded in regulatory assets/liabilities
8,000,000 
5,000,000 
Purchases, issuances and settlements:
 
 
Purchases
1,000,000 
(7,000,000)
Issuances
(3,000,000)
(1,000,000)
Settlements
76,000,000 
(64,000,000)
Net Assets (Liabilities) as of December 31
24,000,000 
(36,000,000)
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
40,000,000 
(1,000,000)
Natural Gas Commodity Contract [Member]
 
 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
 
 
Net Assets (Liabilities) as of December 31
(52,000,000)
(38,000,000)
Transfers into Level 3 from Level 2
0 
1,000,000 
Transfers from Level 3 into Level 2
(2,000,000)
0 
Total gains (losses):
 
 
Included in earnings
(40,000,000)
(32,000,000)
Recorded in regulatory assets/liabilities
0 
0 
Purchases, issuances and settlements:
 
 
Purchases
0 
(8,000,000)
Issuances
0 
0 
Settlements
124,000,000 
25,000,000 
Net Assets (Liabilities) as of December 31
30,000,000 
(52,000,000)
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
35,000,000 
(49,000,000)
Electricity Commodity Contract [Member]
 
 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
 
 
Net Assets (Liabilities) as of December 31
13,000,000 
23,000,000 
Transfers into Level 3 from Level 2
0 
0 
Transfers from Level 3 into Level 2
0 
0 
Total gains (losses):
 
 
Included in earnings
25,000,000 
75,000,000 
Recorded in regulatory assets/liabilities
0 
0 
Purchases, issuances and settlements:
 
 
Purchases
1,000,000 
1,000,000 
Issuances
(3,000,000)
(1,000,000)
Settlements
(41,000,000)
(85,000,000)
Net Assets (Liabilities) as of December 31
(5,000,000)
13,000,000 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
9,000,000 
48,000,000 
Other Commodity Contract [Member]
 
 
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
 
 
Net Assets (Liabilities) as of December 31
3,000,000 
2,000,000 
Transfers into Level 3 from Level 2
0 
0 
Transfers from Level 3 into Level 2
0 
0 
Total gains (losses):
 
 
Included in earnings
(5,000,000)
0 
Recorded in regulatory assets/liabilities
8,000,000 
5,000,000 
Purchases, issuances and settlements:
 
 
Purchases
0 
0 
Issuances
0 
0 
Settlements
(7,000,000)
(4,000,000)
Net Assets (Liabilities) as of December 31
(1,000,000)
3,000,000 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
$ (4,000,000)
$ 0 
Fair Value (Unobservable Inputs related to Level 3 Assets and Liabilities) (Details) (USD $)
In Millions, unless otherwise specified
0 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Unobservable Input Valuation Techniques [Line Items]
 
 
Derivative asset, gross
$ 1,178 
$ 833 
Total fair value of derivatives
(1,110)
(936)
Natural Gas Commodity Contract [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Derivative asset, gross
787 
396 
Total fair value of derivatives
(718)
(503)
Electricity Commodity Contract [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Derivative asset, gross
342 
400 
Total fair value of derivatives
(342)
(398)
Level 3 [Member] |
Discounted Cash Flow Valuation Technique [Member] |
Natural Gas Commodity Contract [Member] |
Minimum [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Forward Basis Price
(2.28)
(0.88)
Level 3 [Member] |
Discounted Cash Flow Valuation Technique [Member] |
Natural Gas Commodity Contract [Member] |
Maximum
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Forward Basis Price
7.83 
5.07 
Level 3 [Member] |
Discounted Cash Flow Valuation Technique [Member] |
Natural Gas Commodity Contract [Member] |
Weighted Average [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Forward Basis Price
(0.22)
(0.16)
Level 3 [Member] |
Discounted Cash Flow Valuation Technique [Member] |
Electricity Commodity Contract [Member] |
Minimum [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Forward Basis Price
(14)
(7)
Level 3 [Member] |
Discounted Cash Flow Valuation Technique [Member] |
Electricity Commodity Contract [Member] |
Maximum
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Forward Basis Price
15 
15 
Level 3 [Member] |
Discounted Cash Flow Valuation Technique [Member] |
Electricity Commodity Contract [Member] |
Weighted Average [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Forward Basis Price
4 
3 
Recurring [Member] |
Level 3 [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Derivative asset, gross
142 
176 
Total fair value of derivatives
(118)
(212)
Recurring [Member] |
Level 3 [Member] |
Natural Gas Commodity Contract [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Derivative asset, gross
92 
34 
Total fair value of derivatives
(62)
(86)
Recurring [Member] |
Level 3 [Member] |
Electricity Commodity Contract [Member]
 
 
Unobservable Input Valuation Techniques [Line Items]
 
 
Derivative asset, gross
47 
139 
Total fair value of derivatives
$ (52)
$ (126)
Fair Value (Fair Value of Financial Instruments) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Reported Value Measurement [Member]
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
Notes receivable, excluding capital leases
$ 41 
$ 41 
Dividends payable
122 
116 
Short-term borrowings
398 
131 
Long-term debt, excluding capital leases
8,606 
8,094 
Estimate of Fair Value Measurement [Member] |
Level 1 [Member]
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
Notes receivable, excluding capital leases
0 
0 
Dividends payable
122 
116 
Short-term borrowings
0 
0 
Long-term debt, excluding capital leases
489 
425 
Estimate of Fair Value Measurement [Member] |
Level 2 [Member]
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
Notes receivable, excluding capital leases
0 
0 
Dividends payable
0 
0 
Short-term borrowings
398 
131 
Long-term debt, excluding capital leases
8,308 
7,551 
Estimate of Fair Value Measurement [Member] |
Level 3 [Member]
 
 
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
 
 
Notes receivable, excluding capital leases
41 
41 
Dividends payable
0 
0 
Short-term borrowings
0 
0 
Long-term debt, excluding capital leases
$ 706 
$ 499 
Fair Value (Fair Value of Nuclear Decommissioning Trust Fund Assets) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]
 
 
Decommissioning Fund Investments
$ 1,241 
$ 1,191 
Fermi 2 [Member]
 
 
Schedule of Available-for-sale Securities [Line Items]
 
 
Decommissioning Fund Investments
1,221 
1,172 
Fermi 1 [Member]
 
 
Schedule of Available-for-sale Securities [Line Items]
 
 
Decommissioning Fund Investments
3 
3 
Low Level Radioactive Waste [Member]
 
 
Schedule of Available-for-sale Securities [Line Items]
 
 
Decommissioning Fund Investments
17 
16 
Nuclear Decommissioning Trust Fund [Member]
 
 
Schedule of Available-for-sale Securities [Line Items]
 
 
Decommissioning Fund Investments
$ 1,241 
$ 1,191 
Fair Value (Gains and Losses and Proceeds from the Sale of Securities by the Nuclear Decommissioning Trust Funds) (Details) (Nuclear Decommissioning Trust Fund [Member], USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Nuclear Decommissioning Trust Fund [Member]
 
 
 
Schedule of Available-for-sale Securities [Line Items]
 
 
 
Realized gains
$ 54 
$ 83 
$ 37 
Realized losses
(33)
(41)
(31)
Proceeds from sales of securities
$ 1,146 
$ 1,118 
$ 759 
Fair Value (Fair Value and Unrealized Gains and Losses for the Nuclear Decommissioning Trust Funds) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]
 
 
Nuclear decommissioning trusts
$ 1,241 
$ 1,191 
Gross Unrealized Gain
225 
213 
Gross Unrealized Loss
(41)
(31)
Nuclear Decommissioning Trust Fund [Member]
 
 
Schedule of Available-for-sale Securities [Line Items]
 
 
Equity Securities
756 
730 
Debt Securities
474 
442 
Cash equivalents
11 
19 
Equity Securities, Gross Unrealized Gain
204 
201 
Equity Securities, Gross Unrealized Loss
(39)
(25)
Debt Securities, Gross Unrealized Gain
21 
12 
Debt Securities, Gross Unrealized Loss
$ (2)
$ (6)
Fair Value (Details Textuals) (USD $)
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Assets level 1 to level 2
$ 0 
$ 0 
 
Assets level 2 to 1
0 
0 
 
Liabilities level 1 to 2
0 
0 
 
Liabilities level 2 to 1
0 
0 
 
Unrealized losses on available for sale securities
(7,000,000)
(9,000,000)
 
Trading securities realized gain (loss)
14,000,000 
22,000,000 
11,000,000 
Accumulated Net Unrealized Investment Gain (Loss) [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Unrealized losses on available for sale securities
0 
0 
 
Nuclear Decommissioning Trust Fund [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Cash equivalents
11,000,000 
19,000,000 
 
Average maturity of debt securities
7 years 
7 years 
 
Cash and Cash Equivalents [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Nuclear decommissioning trust fund investments
1.00% 
2.00% 
 
Equity Securities [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Nuclear decommissioning trust fund investments
61.00% 
61.00% 
 
Debt Securities [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Nuclear decommissioning trust fund investments
38.00% 
37.00% 
 
Recurring [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Cash equivalents
112,000,000 
125,000,000 
 
Restricted Assets [Member] |
Recurring [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Cash equivalents
105,000,000 
109,000,000 
 
Other Investments [Member] |
Recurring [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Cash equivalents
7,000,000 
16,000,000 
 
Other Investments [Member] |
Recurring [Member] |
Equity [Member]
 
 
 
Fair Value, Option, Quantitative Disclosures [Line Items]
 
 
 
Available-for-sale securities
8,000,000 
7,000,000 
 
Other investments
$ 150,000,000 
$ 136,000,000 
 
Financial and Other Derivative Instruments (Fair Value of Derivative Instruments) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
$ 1,178 
$ 833 
Total fair value of derivatives
(1,110)
(936)
Natural Gas Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
787 
396 
Total fair value of derivatives
(718)
(503)
Electricity Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
342 
400 
Total fair value of derivatives
(342)
(398)
Other Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
45 
37 
Total fair value of derivatives
(45)
(34)
Not Designated as Hedging Instrument [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
1,178 
833 
Total fair value of derivatives
(1,110)
(936)
Not Designated as Hedging Instrument [Member] |
Foreign Currency Exchange Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
4 
0 
Total fair value of derivatives
(5)
(1)
Not Designated as Hedging Instrument [Member] |
Natural Gas Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
787 
396 
Total fair value of derivatives
(718)
(503)
Not Designated as Hedging Instrument [Member] |
Electricity Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
342 
400 
Total fair value of derivatives
(342)
(398)
Not Designated as Hedging Instrument [Member] |
Other Commodity Contract [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
45 
37 
Total fair value of derivatives
(45)
(34)
Current Derivative Asset [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
1,083 
691 
Noncurrent Derivative Asset [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
95 
142 
Current Derivative Liability [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
(1,041)
(773)
Noncurrent Derivative Liability [Member]
 
 
Derivatives, Fair Value [Line Items]
 
 
Total fair value of derivatives
$ (69)
$ (163)
Financial and Other Derivative Instruments (Netting Offsets of Derivative Assets and Liabilites) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Offsetting Assets [Line Items]
 
 
Total fair value of derivatives
$ 1,178 
$ 833 
Derivative Asset, Fair Value, Gross Liability
(1,006)
(707)
Net Amounts of Assets Presented in the Statements of Financial Position
172 
126 
Fair Value Gross Amounts of Recognized (Liabilities)
(1,110)
(936)
Derivative Liability, Fair Value, Gross Asset
1,025 
698 
Net Amounts of (Liabilities) Presented in the Statements of Financial Position
(85)
(238)
Natural Gas Commodity Contract [Member]
 
 
Offsetting Assets [Line Items]
 
 
Total fair value of derivatives
787 
396 
Derivative Asset, Fair Value, Gross Liability
(681)
(382)
Net Amounts of Assets Presented in the Statements of Financial Position
106 
14 
Fair Value Gross Amounts of Recognized (Liabilities)
(718)
(503)
Derivative Liability, Fair Value, Gross Asset
679 
395 
Net Amounts of (Liabilities) Presented in the Statements of Financial Position
(39)
(108)
Electricity Commodity Contract [Member]
 
 
Offsetting Assets [Line Items]
 
 
Total fair value of derivatives
342 
400 
Derivative Asset, Fair Value, Gross Liability
(280)
(291)
Net Amounts of Assets Presented in the Statements of Financial Position
62 
109 
Fair Value Gross Amounts of Recognized (Liabilities)
(342)
(398)
Derivative Liability, Fair Value, Gross Asset
298 
269 
Net Amounts of (Liabilities) Presented in the Statements of Financial Position
(44)
(129)
Other Commodity Contract [Member]
 
 
Offsetting Assets [Line Items]
 
 
Total fair value of derivatives
45 
37 
Derivative Asset, Fair Value, Gross Liability
(42)
(34)
Net Amounts of Assets Presented in the Statements of Financial Position
3 
3 
Fair Value Gross Amounts of Recognized (Liabilities)
(45)
(34)
Derivative Liability, Fair Value, Gross Asset
45 
34 
Net Amounts of (Liabilities) Presented in the Statements of Financial Position
0 
0 
Other Derivative Contract [Member]
 
 
Offsetting Assets [Line Items]
 
 
Total fair value of derivatives
4 
0 
Derivative Asset, Fair Value, Gross Liability
(3)
0 
Net Amounts of Assets Presented in the Statements of Financial Position
1 
0 
Fair Value Gross Amounts of Recognized (Liabilities)
(5)
(1)
Derivative Liability, Fair Value, Gross Asset
3 
0 
Net Amounts of (Liabilities) Presented in the Statements of Financial Position
$ (2)
$ (1)
Financial and Other Derivative Instruments (Netting Offsets Reconciliation to Balance Sheet) (Details) (USD $)
Dec. 31, 2014
Dec. 31, 2013
Derivative Assets:
 
 
Total fair value of derivatives
$ 1,178,000,000 
$ 833,000,000 
Collateral adjustment
0 
(26,000,000)
Derivative Asset, Current
128,000,000 
99,000,000 
Derivative Assets, Noncurrent
44,000,000 
27,000,000 
Derivative Liabilities:
 
 
Total fair value of derivatives
(1,110,000,000)
(936,000,000)
Counterparty netting
19,000,000 
17,000,000 
Derivative Liabilities, Current
(77,000,000)
(195,000,000)
Derivative Liabilities, Noncurrent
(8,000,000)
(43,000,000)
Current Derivative Asset [Member]
 
 
Derivative Assets:
 
 
Total fair value of derivatives
1,083,000,000 
691,000,000 
Counterparty netting
(955,000,000)
(566,000,000)
Collateral adjustment
0 
(26,000,000)
Noncurrent Derivative Asset [Member]
 
 
Derivative Assets:
 
 
Total fair value of derivatives
95,000,000 
142,000,000 
Counterparty netting
(51,000,000)
(115,000,000)
Collateral adjustment
0 
0 
Current Derivative Liability [Member]
 
 
Derivative Liabilities:
 
 
Total fair value of derivatives
(1,041,000,000)
(773,000,000)
Counterparty netting
9,000,000 
12,000,000 
Collateral adjustment
955,000,000 
566,000,000 
Noncurrent Derivative Liability [Member]
 
 
Derivative Liabilities:
 
 
Total fair value of derivatives
(69,000,000)
(163,000,000)
Counterparty netting
10,000,000 
5,000,000 
Collateral adjustment
$ 51,000,000 
$ 115,000,000 
Financial and Other Derivative Instruments (Effect of Derivatives not Deisgnated as Hedging Instruments on the Consolidated Statement of Operations) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Derivative Instruments, Gain (Loss) [Line Items]
 
 
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net
$ 79 
$ (11)
Foreign Currency Exchange Contract [Member] |
Operating Revenue [Member]
 
 
Derivative Instruments, Gain (Loss) [Line Items]
 
 
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net
(2)
(1)
Natural Gas Commodity Contract [Member] |
Operating Revenue [Member]
 
 
Derivative Instruments, Gain (Loss) [Line Items]
 
 
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net
(30)
(48)
Natural Gas Commodity Contract [Member] |
Fuel, purchased power and gas [Member]
 
 
Derivative Instruments, Gain (Loss) [Line Items]
 
 
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net
(5)
(44)
Electricity Commodity Contract [Member] |
Operating Revenue [Member]
 
 
Derivative Instruments, Gain (Loss) [Line Items]
 
 
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net
123 
82 
Other Commodity Contract [Member] |
Operating Revenue [Member]
 
 
Derivative Instruments, Gain (Loss) [Line Items]
 
 
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net
$ (7)
$ 0 
Financial and Other Derivative Instruments (Cumulative Gross Volume of Derivative Contracts Outstanding) (Details) (CAD $)
Dec. 31, 2014
MMBTU
Natural Gas Commodity Contract [Member]
 
Derivative [Line Items]
 
Derivative outstanding, energy
895,599,953 
Electricity Commodity Contract [Member]
 
Derivative [Line Items]
 
Derivative outstanding, energy
11,296,153 
Foreign Currency Exchange Contract [Member]
 
Derivative [Line Items]
 
Foreign Currency Exchange (Canadian dollars)
$ 63,022,462 
Financial and Other Derivative Instruments (Details Textuals) (USD $)
Dec. 31, 2014
Dec. 31, 2013
Derivative Instruments and Hedging Activities Disclosure [Abstract]
 
 
Letters of credit that could be used to offset net derivative liabilities
$ 7,000,000 
$ 19,000,000 
Letters of credit received that could be used to offset net derivative assets
5,000,000 
1,000,000 
Cash collateral posted, net of cash collateral received
61,000,000 
12,000,000 
Derivative asset, counterparty netting
0 
26,000,000 
Derivative liability, counterparty netting
19,000,000 
17,000,000 
Cash collateral received
2,000,000 
13,000,000 
Cash collateral paid
44,000,000 
34,000,000 
Derivative net liability position aggregate fair value
1,058,000,000 
 
Collateral already posted fair value
12,000,000 
 
Derivative, net asset position, fair value
973,000,000 
 
Remaining amount of offsets to derivative net liability positions for hard and soft trigger provisions
73,000,000 
 
Additional collateral, aggregate fair value
$ 349,000,000 
 
Long-Term Debt (Long Term Debt Outstanding and Weighted Average Interest Rates) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Debt Instrument [Line Items]
 
 
Long-term Debt, Total
$ 8,620 
 
Long Term Debt excluding Securitization, Debentures and Capital Leases
8,021 
7,312 
Less Amount of Long-term Debt due within one year
(161)
(694)
Long-term Debt, Excluding Current Maturities
7,860 
6,618 
Less Amount of Securitization Bonds due within one year
(105)
(197)
Securitization bonds, Excluding Current Maturities
0 
105 
Junior Subordinated Notes, Noncurrent
480 
480 
6.6% Securitization Bonds Due 2015 [Member]
 
 
Debt Instrument [Line Items]
 
 
Debt, Weighted Average Interest Rate
6.60% 
 
Debt Instrument, Maturity Date
Mar. 15, 2015 
 
Long-term Securitization Bond
105 
302 
Junior Subordinated Debentures [Member] |
6.5% Junior Subordinated Debentures Due 2061 [Member]
 
 
Debt Instrument [Line Items]
 
 
Debt, Weighted Average Interest Rate
6.50% 
 
Debt Instrument, Maturity Date
Dec. 01, 2061 
 
Junior Subordinated Notes, Noncurrent
280 
280 
Junior Subordinated Debentures [Member] |
5.25% Junior Subordinated Debentures Due 2062 [Member]
 
 
Debt Instrument [Line Items]
 
 
Debt, Weighted Average Interest Rate
5.25% 
 
Debt Instrument, Maturity Date
Dec. 01, 2062 
 
Junior Subordinated Notes, Noncurrent
200 
200 
DTE Energy [Member] |
Unsecured Debt [Member] |
4.6% Unsecured Debt Due 2016 to 2033 [Member]
 
 
Debt Instrument [Line Items]
 
 
Debt, Weighted Average Interest Rate
4.60% 
 
Debt Instrument, Maturity Date Range, Start
Jun. 01, 2016 
 
Debt Instrument, Maturity Date Range, End
Apr. 15, 2033 
 
Long-term Debt, Total
1,647 
1,297 
DTE Electric [Member] |
Secured Debt [Member] |
4.5% Taxable Debt, Principally Secured Due 2016 to 2044 [Member]
 
 
Debt Instrument [Line Items]
 
 
Debt, Weighted Average Interest Rate
4.50% 
 
Debt Instrument, Maturity Date Range, Start
Mar. 31, 2016 
 
Debt Instrument, Maturity Date Range, End
Jun. 01, 2044 
 
Long-term Debt, Total
4,824 
4,286 
DTE Electric [Member] |
Tax Exempt Revenue Bonds [Member] |
5.2% Tax Exempt Revenue Bonds Due 2020 to 2030 [Member]
 
 
Debt Instrument [Line Items]
 
 
Debt, Weighted Average Interest Rate
5.20% 
 
Debt Instrument, Maturity Date Range, Start
Jul. 01, 2020 
 
Debt Instrument, Maturity Date Range, End
Dec. 01, 2030 
 
Long-term Debt, Total
330 
558 
DTE Gas [Member] |
Secured Debt [Member] |
5.2% Taxable Debt, Principally Secured Due 2015 to 2044 [Member]
 
 
Debt Instrument [Line Items]
 
 
Debt, Weighted Average Interest Rate
5.20% 
 
Debt Instrument, Maturity Date Range, Start
Sep. 01, 2015 
 
Debt Instrument, Maturity Date Range, End
Dec. 15, 2044 
 
Long-term Debt, Total
1,099 
1,029 
DTE Gas [Member] |
Long Term Debt, Other [Member]
 
 
Debt Instrument [Line Items]
 
 
Long-term Debt, Total
$ 121 
$ 142 
Long-Term Debt (Debt Issuances) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Debt Instrument [Line Items]
 
Debt face amount
$ 1,750 
DTE Energy [Member] |
Senior Notes [Member] |
May 2014 3.50% Senior Notes Maturing in 2024 [Member]
 
Debt Instrument [Line Items]
 
Debt instrument stated interest rate
3.50% 
Debt face amount
350 
DTE Energy [Member] |
Senior Notes [Member] |
November 2014 2.40% Senior Notes Maturing in 2019 [Member]
 
Debt Instrument [Line Items]
 
Debt instrument stated interest rate
2.40% 
Debt face amount
300 
Electric [Member] |
Mortgages [Member] |
June 2014 3.77% Mortgage Bonds Maturing in 2026 [Member]
 
Debt Instrument [Line Items]
 
Debt instrument stated interest rate
3.77% 
Debt face amount
100 
Electric [Member] |
Mortgages [Member] |
June 2014 4.60% Mortgage Bonds Maturing in 2044 [Member]
 
Debt Instrument [Line Items]
 
Debt instrument stated interest rate
4.60% 
Debt face amount
150 
Electric [Member] |
Mortgages [Member] |
July 2014 3.375% Mortgage Bonds Maturing in 2025 [Member]
 
Debt Instrument [Line Items]
 
Debt instrument stated interest rate
3.375% 
Debt face amount
350 
Electric [Member] |
Mortgages [Member] |
July 2014 4.30% Mortgage Bonds Maturing in 2044 [Member]
 
Debt Instrument [Line Items]
 
Debt instrument stated interest rate
4.30% 
Debt face amount
350 
Gas [Member] |
Mortgages [Member] |
December 2014 4.35% Mortgage Bonds Maturing in 2044 [Member]
 
Debt Instrument [Line Items]
 
Debt instrument stated interest rate
4.35% 
Debt face amount
$ 150 
Long-Term Debt (Debt Redemptions) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Debt Instrument, Redemption [Line Items]
 
Extinguishment of debt
$ 1,237 
Mortgages [Member] |
Electric [Member] |
March 2014 Mortgage Bonds Various Interest Rates Maturing in 2014 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Extinguishment of debt
13 
Mortgages [Member] |
Gas [Member] |
May 2014 Mortgage Bonds 8.25% Maturing in 2014 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
8.25% 
Extinguishment of debt
80 
Senior Notes [Member] |
Electric [Member] |
July 2014 Senior Notes 4.80% Maturing in 2015 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
4.80% 
Extinguishment of debt
200 
Senior Notes [Member] |
Electric [Member] |
August 2014 Senior Notes 5.40% Maturing in 2014 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
5.40% 
Extinguishment of debt
200 
Senior Notes [Member] |
DTE Energy [Member] |
May 2014 Senior Notes 7.625% Maturing in 2014 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
7.625% 
Extinguishment of debt
300 
Securitization Bonds [Member] |
Electric [Member] |
March 2014 Securitization Bonds 6.62% Maturing in 2014 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
6.62% 
Extinguishment of debt
100 
Securitization Bonds [Member] |
Electric [Member] |
September 2014 Securitization Bonds 6.62% Maturing in 2014 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
6.62% 
Extinguishment of debt
96 
Tax Exempt Revenue Bonds [Member] |
Electric [Member] |
April 2014 Tax Exempt Revenue Bonds 2.35% Maturing in 2024 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
2.35% 
Extinguishment of debt
31 
Tax Exempt Revenue Bonds [Member] |
Electric [Member] |
April 2014 Tax Exempt Revenue Bonds 4.65% Maturing in 2028 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
4.65% 
Extinguishment of debt
32 
Tax Exempt Revenue Bonds [Member] |
Electric [Member] |
June 2014 Tax Exempt Revenue Bonds 4.875% Maturing in 2029 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
4.875% 
Extinguishment of debt
36 
Tax Exempt Revenue Bonds [Member] |
Electric [Member] |
June 2014 Tax Exempt Revenue Bonds 6.00% Maturing in 2036 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
6.00% 
Extinguishment of debt
69 
Tax Exempt Revenue Bonds [Member] |
Electric [Member] |
August 2014 Tax Exempt Revenue Bonds 5.25% Maturing in 2029 [Member]
 
Debt Instrument, Redemption [Line Items]
 
Debt instrument stated interest rate
5.25% 
Extinguishment of debt
60 
Long Term Debt, Other [Member] |
DTE Energy [Member]
 
Debt Instrument, Redemption [Line Items]
 
Extinguishment of debt
$ 20 
Long-Term Debt (Scheduled Debt Maturities) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Maturities of Long-term Debt [Abstract]
 
2015
$ 266 
2016
465 
2017
9 
2018
407 
2019
427 
2020 and Thereafter
7,046 
Long-term Debt, Total
$ 8,620 
Long-Term Debt (Details Textuals) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Debt Instrument [Line Items]
 
 
Junior Subordinated Notes, Noncurrent
$ 480 
$ 480 
Preferred and Preferenced Securities (Details) (USD $)
Dec. 31, 2014
DTE Energy [Member]
 
Preferred and Preferenced Securities [Line Items]
 
Preferred stock, par value (in dollars per share)
$ 0 
Preferred stock, shares authorized (in shares)
5,000,000 
DTE Electric [Member]
 
Preferred and Preferenced Securities [Line Items]
 
Preferred stock, par value (in dollars per share)
$ 100 
Preferred stock, shares authorized (in shares)
6,747,484 
Preference stock, par value (in dollars per share)
$ 1 
Preference stock shares authorized (in shares)
30,000,000 
DTE Gas [Member]
 
Preferred and Preferenced Securities [Line Items]
 
Preferred stock, par value (in dollars per share)
$ 1 
Preferred stock, shares authorized (in shares)
7,000,000 
Preference stock, par value (in dollars per share)
$ 1 
Preference stock shares authorized (in shares)
4,000,000 
Short-Term Credit Arrangements and Borrowings (Details) (USD $)
Dec. 31, 2014
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
$ 2,025,000,000 
Amounts outstanding
602,000,000 
Net availability
1,423,000,000 
DTE Energy [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
1,425,000,000 
Amounts outstanding
407,000,000 
Net availability
1,018,000,000 
DTE Electric [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
300,000,000 
Amounts outstanding
50,000,000 
Net availability
250,000,000 
DTE Gas [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
300,000,000 
Amounts outstanding
145,000,000 
Net availability
155,000,000 
Letter of Credit [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
204,000,000 
Letter of Credit [Member] |
DTE Energy [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
204,000,000 
Letter of Credit [Member] |
DTE Electric [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
0 
Letter of Credit [Member] |
DTE Gas [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
0 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in February 2015 [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
100,000,000 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in February 2015 [Member] |
DTE Energy [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
100,000,000 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in February 2015 [Member] |
DTE Electric [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
0 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in February 2015 [Member] |
DTE Gas [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
0 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in August 2015 [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
125,000,000 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in August 2015 [Member] |
DTE Energy [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
125,000,000 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in August 2015 [Member] |
DTE Electric [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
0 
Letter of Credit [Member] |
Unsecured letter of credit, expiring in August 2015 [Member] |
DTE Gas [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
0 
Revolving Credit Facility [Member] |
Unsecured revolving credit facility, expiring April 2018 [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
1,800,000,000 
Revolving Credit Facility [Member] |
Unsecured revolving credit facility, expiring April 2018 [Member] |
DTE Energy [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
1,200,000,000 
Revolving Credit Facility [Member] |
Unsecured revolving credit facility, expiring April 2018 [Member] |
DTE Electric [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
300,000,000 
Revolving Credit Facility [Member] |
Unsecured revolving credit facility, expiring April 2018 [Member] |
DTE Gas [Member]
 
Line Of Credit Facility [Line Items]
 
Line of Credit Facility, Maximum Borrowing Capacity
300,000,000 
Commercial Paper [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
398,000,000 
Commercial Paper [Member] |
DTE Energy [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
203,000,000 
Commercial Paper [Member] |
DTE Electric [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
50,000,000 
Commercial Paper [Member] |
DTE Gas [Member]
 
Line Of Credit Facility [Line Items]
 
Amounts outstanding
$ 145,000,000 
Short-Term Credit Arrangements and Borrowings (Details Textuals) (USD $)
Dec. 31, 2014
Dec. 31, 2013
Short-term Debt [Line Items]
 
 
Other outstanding letters of credit
$ 602,000,000 
 
Short-term Debt, Weighted Average Interest Rate
0.40% 
0.20% 
Line of Credit Facility, Dividend Restrictions
730,000,000 
 
Retained Earnings (Accumulated Deficit)
4,578,000,000 
4,150,000,000 
Other Restrictions on Payment of Dividends
0 
 
DTE Energy [Member]
 
 
Short-term Debt [Line Items]
 
 
Total Funded Debt to Total Capitalization Ratio
0.50 
 
Other outstanding letters of credit
407,000,000 
 
DTE Electric [Member]
 
 
Short-term Debt [Line Items]
 
 
Total Funded Debt to Total Capitalization Ratio
0.51 
 
Other outstanding letters of credit
50,000,000 
 
DTE Gas [Member]
 
 
Short-term Debt [Line Items]
 
 
Total Funded Debt to Total Capitalization Ratio
0.48 
 
Other outstanding letters of credit
145,000,000 
 
Letter of Credit [Member]
 
 
Short-term Debt [Line Items]
 
 
Other outstanding letters of credit
204,000,000 
 
Letter of Credit [Member] |
DTE Energy [Member]
 
 
Short-term Debt [Line Items]
 
 
Other outstanding letters of credit
204,000,000 
 
Letter of Credit [Member] |
DTE Electric [Member]
 
 
Short-term Debt [Line Items]
 
 
Other outstanding letters of credit
0 
 
Letter of Credit [Member] |
DTE Gas [Member]
 
 
Short-term Debt [Line Items]
 
 
Other outstanding letters of credit
0 
 
Demand Financing Agreement [Member] |
DTE Energy [Member]
 
 
Short-term Debt [Line Items]
 
 
Financing Agreement, Maximum Borrowing Capacity
100,000,000 
 
Maximum Additional Margin Financing
50,000,000 
 
Financing Agreement, Amount Outstanding
37,000,000 
138,000,000 
Demand Financing Agreement Plus Letter of Credit [Member] |
DTE Energy [Member]
 
 
Short-term Debt [Line Items]
 
 
Financing Agreement, Maximum Borrowing Capacity
150,000,000 
 
Other outstanding letters of credit [Member] |
Letter of Credit [Member] |
DTE Energy [Member]
 
 
Short-term Debt [Line Items]
 
 
Other outstanding letters of credit
35,000,000 
 
Demand Financing Agreement [Member] |
Letter of Credit [Member] |
DTE Energy [Member]
 
 
Short-term Debt [Line Items]
 
 
Financing Agreement, Maximum Borrowing Capacity
$ 50,000,000 
 
Maximum
 
 
Short-term Debt [Line Items]
 
 
Total Funded Debt to Total Capitalization Ratio
0.65 
 
Capital and Operating Leases (Future Minimum Lease Payments under Non-Cancelable Leases) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Operating Leases, Future Minimum Payments Due, Fiscal Year Maturity [Abstract]
 
2015
$ 42 
2016
34 
2017
28 
2018
23 
2019
14 
Thereafter
78 
Total minimum lease payments
$ 219 
Capital and Operating (Components of the Net Investment in the Capital Leases) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Capital Leases of Lessor [Abstract]
 
2015
$ 12 
2016
13 
2017
13 
2018
13 
2019
10 
Thereafter
9 
Total minimum future lease receipts
70 
Residual value of leased pipeline
40 
Less unearned income
(34)
Net investment in capital lease
76 
Less current portion
(5)
Capital Lease, noncurrent
$ 71 
Capital and Operating Leases (Details Textuals) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Leases [Abstract]
 
 
 
Rent expense
$ 38 
$ 34 
$ 36 
Pipeline System Lease [Member]
 
 
 
Schedule of Lessor Capital Leases [Line Items]
 
 
 
Lessor capital lease renewal terms
5 years 
 
 
Percent ownership in pipeline
40.00% 
 
 
Minimum [Member] |
Energy Services Agreement [Member]
 
 
 
Schedule of Lessor Capital Leases [Line Items]
 
 
 
Lessor capital lease renewal terms
3 years 
 
 
Maximum |
Energy Services Agreement [Member]
 
 
 
Schedule of Lessor Capital Leases [Line Items]
 
 
 
Lessor capital lease renewal terms
5 years 
 
 
Commitments and Contingencies (Purchase Commitments) (Details) (USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Purchase Obligation, Fiscal Year Maturity [Abstract]
 
2015
$ 2,384 
2016
1,258 
2017
742 
2018
477 
2019
431 
2020 and thereafter
3,723 
Total Purchase Commitments
$ 9,015 
Commitments and Contingencies (Details Textuals) (USD $)
1 Months Ended 12 Months Ended 12 Months Ended 0 Months Ended 4 Months Ended 8 Months Ended 12 Months Ended 12 Months Ended
Apr. 30, 2014
Dec. 31, 2014
Dec. 31, 2010
dte_instances
Dec. 31, 2014
Gas [Member]
facilities
Dec. 31, 2013
Gas [Member]
May 31, 2014
Electric [Member]
May 15, 2014
Electric [Member]
kWh
Dec. 31, 2014
Electric [Member]
kWh
facilities
dte_instances
Dec. 31, 2014
Electric [Member]
facilities
dte_instances
Dec. 31, 2013
Electric [Member]
Dec. 31, 2014
Synthetic Fuel [Member]
Dec. 31, 2014
Reduced Emissions Fuel Guarantees [Member]
Dec. 31, 2014
Guarantee Type, Other [Member]
Dec. 31, 2014
Surety Bond [Member]
Dec. 31, 2014
Represented Employees [Member]
employees
Dec. 31, 2014
Cleanup completed and site closed [Member]
Gas [Member]
facilities
Dec. 31, 2014
Partial closure expected by end of fiscal year [Member]
Gas [Member]
facilities
Loss Contingencies [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Environmental Capital Expenditures Through Current Year
 
 
 
 
 
 
 
 
$ 2,200,000,000 
 
 
 
 
 
 
 
 
Estimated capital expenditures in next fiscal year
 
 
 
 
 
 
 
 
100,000,000 
 
 
 
 
 
 
 
 
Environmental Capital Expenditures In Future Years
 
 
 
 
 
 
 
 
30,000,000 
 
 
 
 
 
 
 
 
EPA is Alleging Power Plants Violated New Source Performance Standards
 
 
 
 
 
 
 
5 
5 
 
 
 
 
 
 
 
 
Number of NOVs/FOVs currently being discussed with the EPA
 
 
 
 
 
 
 
2 
2 
 
 
 
 
 
 
 
 
Time period to complete studies on cooling water intake structures impacts on fish - EPA ruling
 
 
 
 
 
3 years 
 
 
 
 
 
 
 
 
 
 
 
Number of Former MGP Sites
 
 
 
15 
 
 
 
 
3 
 
 
 
 
 
 
3 
2 
Accrued for remediation related to the sites
 
 
 
24,000,000 
28,000,000 
 
 
10,000,000 
10,000,000 
8,000,000 
 
 
 
 
 
 
 
Number of Permitted Engineered Ash Storage Facilities Owned
 
 
 
 
 
 
 
 
3 
 
 
 
 
 
 
 
 
Period Gas Utility Can Amortize MGP Costs
 
 
 
10 years 
 
 
 
 
 
 
 
 
 
 
 
 
 
Number of NOVs
 
 
2 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Possible Environmental Capital Expenditures to Comply with Requirements
 
1,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Estimated maximum spend to upgrade treatment technology to biological treatment to meet future requirements
 
13,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Length of Notice of Intent to sue from the Group Against Smog and Pollution
 
60 days 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Fine related to consent order and agreement with Allegheny County related to NOV
300,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Estimated expenditures for a supplemental environmental project to enhance particulate collection efficiency
 
300,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
EPA Sulfur Dioxide Ambient Air Quality Standard
 
1 hour 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Waiting Period of Policy
 
84 days 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Insurance Coverage for Extra Expense when Power Plant Unavailable
 
 
 
 
 
 
 
 
490,000,000 
 
 
 
 
 
 
 
 
Period of Coverage of Policy for Extra Expenses
 
 
 
 
 
 
 
 
3 years 
 
 
 
 
 
 
 
 
Primary Coverage
 
 
 
 
 
 
 
 
1,500,000,000.0 
 
 
 
 
 
 
 
 
Coverage for Stabilization Decontamination Debris Removal Repair and Replacement of Property and Decommissioning
 
 
 
 
 
 
 
 
1,250,000,000.00 
 
 
 
 
 
 
 
 
Combined Coverage Limit for Total Property Damage
 
 
 
 
 
 
 
 
2,750,000,000.00 
 
 
 
 
 
 
 
 
Insurance Deductible for Nuclear Power Plant
 
 
 
 
 
 
 
1,000,000 
1,000,000 
 
 
 
 
 
 
 
 
Total Limit for Property Damage for Non-Nuclear Events
 
 
 
 
 
 
 
2,000,000,000 
2,000,000,000 
 
 
 
 
 
 
 
 
Limit of Coverage for Aggregate Extra Expenses for Non-Nuclear Events
 
 
 
 
 
 
 
 
328,000,000 
 
 
 
 
 
 
 
 
Limit for Property Damage for Non-Nuclear Events Aggregate of Extra Expenses of Period
 
 
 
 
 
 
 
 
2 years 
 
 
 
 
 
 
 
 
Time Period for TRIA Insurance After the First Loss from Terrorism
 
 
 
 
 
 
 
 
1 year 
 
 
 
 
 
 
 
 
NEIL Policies Against Terroism Loss
 
 
 
 
 
 
 
 
3,200,000,000 
 
 
 
 
 
 
 
 
Amount per Event Loss Associated with Nuclear Power Plants
 
 
 
 
 
 
 
 
35,000,000 
 
 
 
 
 
 
 
 
Maintenance of Public Liability Insurance for Nuclear Power Plants
 
 
 
 
 
 
 
 
375,000,000 
 
 
 
 
 
 
 
 
Aggregate Limit of Liabilities Arises From Terroist Act Outside Scope of Trials Subject to One Industry
 
 
 
 
 
 
 
 
300,000,000 
 
 
 
 
 
 
 
 
Deferred Premium Charged Leviied Against Each Licensed Nuclear Facility
 
 
 
 
 
 
 
 
127,000,000 
 
 
 
 
 
 
 
 
Limit Deferred Premium Charges Per Year
 
 
 
 
 
 
 
 
19,000,000 
 
 
 
 
 
 
 
 
Company Obligated to Pay DOE Fee of Fermi 2 Electricity Generated and Sold
 
 
 
 
 
 
1 
 
 
 
 
 
 
 
 
 
 
Court of Appeals proposal to congress to reduce nuclear waste fee, amount
 
 
 
 
 
 
 
0 
 
 
 
 
 
 
 
 
 
Guarantor Obligations, Maximum Exposure, Undiscounted
 
 
 
 
 
 
 
 
 
 
1,000,000,000 
172,000,000 
60,000,000 
 
 
 
 
Performance Bonds Outstanding
 
 
 
 
 
 
 
 
 
 
 
 
 
49,000,000 
 
 
 
Number of Represented Employees
 
 
 
 
 
 
 
 
 
 
 
 
 
 
4,900 
 
 
Total Purchase Commitments
 
9,015,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Estimated future capital expenditures for next year
 
$ 2,600,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Retirement Benefits and Trusteed Assets (Pension Plan - Pension Cost Inclusions) (Details) (Pension Plan, USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Pension Plan
 
 
 
Defined Benefit Plan, Net Periodic Benefit Cost [Abstract]
 
 
 
Service cost
$ 83 
$ 94 
$ 82 
Interest cost
212 
192 
204 
Expected return on plan assets
(273)
(266)
(244)
Amortization of Net Loss
157 
208 
176 
Special termination benefits
0 
0 
2 
Net pension cost
$ 179 
$ 228 
$ 220 
Retirement Benefits and Trusteed Assets (Pension Plan - Other Changes in Plan Assets and Benefit Obligations recognized in Reg Assets and OCI) (Details) (Pension Plan, USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Pension Plan
 
 
Other changes in plan assets and benefit obligations recognized in Regulatory assets and Other comprehensive income
 
 
Net actuarial (gain) loss
$ 805 
$ (581)
Amortization of net actuarial loss
(157)
(208)
Prior service cost
(7)
0 
Total recognized Regulatory assets and Other comprehensive income
641 
(789)
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income
820 
(561)
Estimated amounts to be amortized from Regulatory assets and Accumulated other comprehensive income into net periodic benefit cost during next fiscal year
 
 
Future amortization of net actuarial loss into net periodic benefit cost
$ 206 
$ 151 
Retirement Benefits and Trusteed Assets (Pension Plan - Reconciliation of Obligations, Assets and Funded Status of Plans) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Amounts recognized in Regulatory assets (see Note 8)
 
 
 
Regulatory Assets
$ 3,727 
$ 2,863 
 
Pension Plan
 
 
 
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
 
 
 
Accumulated benefit obligation, end of year
4,853 
4,068 
 
Change in accumulated postretirement benefit obligation
 
 
 
Benefit obligation, beginning of year
4,380 
4,729 
 
Service cost
83 
94 
82 
Interest cost
212 
192 
204 
Plan amendments
(7)
(3)
 
Actuarial (gain) loss
836 
(400)
 
Benefits paid
(235)
(232)
 
Benefit obligation, end of year
5,269 
4,380 
4,729 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
 
Plan assets at fair value, beginning of year
3,720 
3,223 
 
Actual return on plan assets
301 
445 
 
Company contributions
195 
284 
 
Benefits paid
(235)
(232)
 
Plan assets at fair value, end of year
3,981 
3,720 
3,223 
Funded status of the plans
(1,288)
(660)
 
Amount recorded as:
 
 
 
Current liabilities
(8)
(7)
 
Noncurrent liabilities
(1,280)
(653)
 
Pension and Other Postretirement Defined Benefit Plans, Liabilities
(1,288)
(660)
 
Amounts recognized in Accumulated other comprehensive loss, pre-tax
 
 
 
Net actuarial loss
194 
174 
 
Prior service (credit)
(1)
(1)
 
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax
193 
173 
 
Amounts recognized in Regulatory assets (see Note 8)
 
 
 
Net actuarial loss
2,285 
1,654 
 
Prior service credit
(1)
6 
 
Regulatory Assets
$ 2,284 
$ 1,660 
 
Retirement Benefits and Trusteed Assets (Pension Plan - Benefits related to Qualified and Nonqualified Pension Plans Expected to be paid in the Next Ten Years) (Details) (Pension Plan, USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Pension Plan
 
Defined Benefit Plan, Expected Future Benefit Payments, Fiscal Year Maturity [Abstract]
 
2015
$ 269 
2016
277 
2017
286 
2018
298 
2019
309 
2020-2024
1,634 
Total Expected Future Benefit Payments
$ 3,073 
Retirement Benefits and Trusteed Assets (Pension Plan - Assumptions used in Determining the PBO and Net Pension Costs) (Details) (Pension Plan)
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Pension Plan
 
 
 
Projected benefit obligation
 
 
 
Discount rate
4.12% 
4.95% 
4.15% 
Rate of compensation increase
4.65% 
4.20% 
4.20% 
Net pension costs
 
 
 
Discount rate
4.95% 
4.15% 
5.00% 
Rate of compensation increase
4.20% 
4.20% 
4.20% 
Expected long-term rate of return on plan assets
7.75% 
8.25% 
8.25% 
Retirement Benefits and Trusteed Assets (Pension Plan - Target Allocations of Plan Assets) (Details) (Pension Plan)
12 Months Ended
Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
100.00% 
US Large Cap Equity Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
22.00% 
US Small Cap and Mid Cap Equity Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
5.00% 
Non US Equity Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
20.00% 
Fixed Income Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
25.00% 
Hedge Funds [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
20.00% 
Private Equity Funds [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
8.00% 
Retirement Benefits and Trusteed Assets (Pension Plan - Fair Value Measurements) (Details) (Pension Plan, USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
$ 3,981 
$ 3,720 
$ 3,223 
Short-term Investments [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
46 
22 
 
US Large Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
899 
896 
 
US Small Cap and Mid Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
225 
221 
 
Non US Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
745 
741 
 
Fixed Income Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
1,120 
937 
 
Hedge Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
759 
733 
 
Private Equity Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
187 
170 
 
Securities Lending [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
(239)
0 
 
Securities Lending Collateral [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
239 
0 
 
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
1,929 
2,034 
 
Level 1 [Member] |
Short-term Investments [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
46 
22 
 
Level 1 [Member] |
US Large Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
899 
896 
 
Level 1 [Member] |
US Small Cap and Mid Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
225 
221 
 
Level 1 [Member] |
Non US Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
526 
611 
 
Level 1 [Member] |
Fixed Income Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
7 
16 
 
Level 1 [Member] |
Hedge Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
226 
268 
 
Level 1 [Member] |
Private Equity Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 1 [Member] |
Securities Lending [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
(189)
0 
 
Level 1 [Member] |
Securities Lending Collateral [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
189 
0 
 
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
1,427 
1,121 
 
Level 2 [Member] |
Short-term Investments [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 2 [Member] |
US Large Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 2 [Member] |
US Small Cap and Mid Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 2 [Member] |
Non US Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
219 
130 
 
Level 2 [Member] |
Fixed Income Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
1,113 
921 
 
Level 2 [Member] |
Hedge Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
95 
70 
 
Level 2 [Member] |
Private Equity Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 2 [Member] |
Securities Lending [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
(50)
0 
 
Level 2 [Member] |
Securities Lending Collateral [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
50 
0 
 
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
625 
565 
518 
Level 3 [Member] |
Short-term Investments [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 3 [Member] |
US Large Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 3 [Member] |
US Small Cap and Mid Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 3 [Member] |
Non US Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 3 [Member] |
Fixed Income Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 3 [Member] |
Hedge Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
438 
395 
339 
Level 3 [Member] |
Private Equity Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
187 
170 
179 
Level 3 [Member] |
Securities Lending [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Level 3 [Member] |
Securities Lending Collateral [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
$ 0 
$ 0 
 
Retirement Benefits and Trusteed Assets (Pension Plan - Fair Value Measurement using Level 3 Inputs) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
$ 40 
$ (1)
Pension Plan
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
3,720 
3,223 
Total realized/unrealized gains (losses)
301 
445 
Plan assets at fair value, end of year
3,981 
3,720 
Pension Plan |
Level 3 [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
565 
518 
Total realized/unrealized gains (losses)
38 
44 
Purchases
53 
31 
Sales
(31)
(28)
Plan assets at fair value, end of year
625 
565 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
32 
41 
Pension Plan |
Hedge Funds [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, end of year
759 
733 
Pension Plan |
Hedge Funds [Member] |
Level 3 [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
395 
339 
Total realized/unrealized gains (losses)
22 
40 
Purchases
22 
16 
Sales
(1)
0 
Plan assets at fair value, end of year
438 
395 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
21 
38 
Pension Plan |
Private Equity Funds [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, end of year
187 
170 
Pension Plan |
Private Equity Funds [Member] |
Level 3 [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
170 
179 
Total realized/unrealized gains (losses)
16 
4 
Purchases
31 
15 
Sales
(30)
(28)
Plan assets at fair value, end of year
187 
170 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
$ 11 
$ 3 
Retirement Benefits and Trusteed Assets (OPEB - Postretirement Cost Inclusions) (Details) (Other Postretirement Benefit Plan, USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Other Postretirement Benefit Plan
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Service cost
$ 34 
$ 47 
$ 68 
Interest cost
89 
88 
120 
Expected return on plan assets
(122)
(110)
(92)
Amortization of Net Loss
20 
64 
80 
Amortization of Prior Service Cost (Credit)
(144)
(131)
(25)
Net pension cost
$ (123)
$ (42)
$ 151 
Retirement Benefits and Trusteed Assets (OPEB - Other Changes in Plan Assets and APBO Recognized in Regulatory Assets and OCI) (Details) (Other Postretirement Benefit Plan, USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Other Postretirement Benefit Plan
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
Net actuarial (gain) loss
$ 192 
$ (353)
Amortization of net actuarial loss
(20)
(64)
Prior service credit
0 
(218)
Amortization of prior service credit
144 
131 
Total recognized Regulatory assets and Other comprehensive income
316 
(504)
Total recognized in net periodic pension cost, Regulatory assets and Other comprehensive income
193 
(546)
Future amortization of net actuarial loss into net periodic benefit cost
43 
21 
Future amortization of prior service credit into net periodic benefit cost
$ (126)
$ (144)
Retirement Benefits and Trusteed Assets (OPEB - Reconciliation of Obligations, Assets and Funded Status of Plans) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Amounts recognized in Regulatory assets (liabilities) (see Note 8)
 
 
 
Regulatory Liabilities
$ (820)
$ (1,164)
 
Other Postretirement Benefit Plan
 
 
 
Change in accumulated postretirement benefit obligation
 
 
 
Benefit obligation, beginning of year
1,878 
2,315 
 
Service cost
34 
47 
68 
Interest cost
89 
88 
120 
Plan amendments
0 
(218)
 
Actuarial (gain) loss
131 
(267)
 
Medicare Part D subsidy
0 
1 
 
Benefits paid
(88)
(88)
 
Benefit obligation, end of year
2,044 
1,878 
2,315 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
1,528 
1,527 
1,153 
Actual return on plan assets
62 
196 
 
Company contributions
24 
264 
 
Benefits paid
(85)
(86)
 
Funded status of the plans
(516)
(351)
 
Amount recorded as:
 
 
 
Current liabilities
(1)
(1)
 
Noncurrent liabilities
(515)
(350)
 
Pension and Other Postretirement Defined Benefit Plans, Liabilities
(516)
(351)
 
Amounts recognized in Accumulated other comprehensive loss, pre-tax
 
 
 
Net actuarial loss
34 
29 
 
Prior service (credit)
(5)
(10)
 
Pension and Other Postretirement Benefit Plans, Accumulated Other Comprehensive Income (Loss), before Tax
29 
19 
 
Amounts recognized in Regulatory assets (liabilities) (see Note 8)
 
 
 
Net actuarial loss
488 
321 
 
Prior service credit
(254)
(393)
 
Regulatory Liabilities
$ 234 
$ (72)
 
Retirement Benefits and Trusteed Assets (OPEB - Benefits related to Qualified and Nonqualified Pension Plans Expected to be paid in the Next Ten Years) (Details) (Other Postretirement Benefit Plan, USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Other Postretirement Benefit Plan
 
Defined Benefit Plan Disclosure [Line Items]
 
2015
$ 101 
2016
107 
2017
111 
2018
117 
2019
122 
2020-2024
660 
Total Expected Future Benefit Payments
$ 1,218 
Retirement Benefits and Trusteed Assets (OPEB - Assumptions used in Determining the PBO and Net Pension Costs) (Details)
3 Months Ended 9 Months Ended 12 Months Ended
Mar. 31, 2013
Dec. 31, 2013
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
 
 
 
 
 
Ultimate health care trend rate
 
 
 
 
5.00% 
Health care trend rate pre- and post- 65
 
 
 
 
7.00% 
Other Postretirement Benefit Plan
 
 
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
 
 
Discount rate
4.30% 
4.95% 
4.10% 
4.95% 
4.15% 
Health care trend rate pre 65
 
 
7.50% 
7.50% 
 
Health care trend post 65
 
 
6.50% 
6.50% 
 
Ultimate health care trend rate
 
 
4.50% 
4.50% 
 
Health care trend pre 65
 
 
2025 
2025 
 
Health care trend post 65
 
 
6.50% 
 
 
Year in which ultimate reached pre- and post- 65
 
 
 
 
2021 
Ultimate year post 65
 
 
2024 
2024 
 
Other postretirement benefit costs, Discount Rate
4.15% 
4.30% 
4.95% 
 
5.00% 
Expected long-term rate of return on plan assets
 
 
8.00% 
8.25% 
8.25% 
Health care trend rate pre-65
 
 
7.50% 
 
 
Health care trend rate pre- and post- 65
 
 
 
7.00% 
7.00% 
Other Postretirement Benefit Plan |
Other postretirement benefit costs [Member]
 
 
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
 
 
Ultimate health care trend rate
 
 
4.50% 
5.00% 
5.00% 
Health care trend pre 65
 
 
2025 
 
 
Year in which ultimate reached pre- and post- 65
 
2021 
 
2021 
2020 
Ultimate year post 65
 
 
2024 
 
 
Retirement Benefits and Trusteed Assets (OPEB - Target Allocations of Plan Assets) (Details) (Other Postretirement Benefit Plan)
12 Months Ended
Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
100.00% 
US Large Cap Equity Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
17.00% 
US Small Cap and Mid Cap Equity Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
4.00% 
Non US Equity Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
20.00% 
Fixed Income Securities [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
25.00% 
Hedge Funds [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
20.00% 
Private Equity Funds [Member]
 
Defined Benefit Plan Disclosure [Line Items]
 
Target Allocation Percentage of Assets
14.00% 
Retirement Benefits and Trusteed Assets (OPEB - Fair Value Measurements) (Details) (Other Postretirement Benefit Plan, USD $)
In Millions, unless otherwise specified
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
$ 1,528 
$ 1,527 
$ 1,153 
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
765 
883 
 
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
464 
384 
 
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
299 
260 
205 
Short-term Investments [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
6 
5 
 
Short-term Investments [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
6 
5 
 
Short-term Investments [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Short-term Investments [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
US Large Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
266 
302 
 
US Large Cap Equity Securities [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
266 
302 
 
US Large Cap Equity Securities [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
US Large Cap Equity Securities [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
US Small Cap and Mid Cap Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
149 
147 
 
US Small Cap and Mid Cap Equity Securities [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
149 
147 
 
US Small Cap and Mid Cap Equity Securities [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
US Small Cap and Mid Cap Equity Securities [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Non US Equity Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
281 
291 
 
Non US Equity Securities [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
222 
282 
 
Non US Equity Securities [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
59 
9 
 
Non US Equity Securities [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Fixed Income Securities [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
375 
367 
 
Fixed Income Securities [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
15 
17 
 
Fixed Income Securities [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
360 
350 
 
Fixed Income Securities [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Hedge Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
320 
314 
 
Hedge Funds [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
107 
130 
 
Hedge Funds [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
45 
25 
 
Hedge Funds [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
168 
159 
119 
Private Equity Funds [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
131 
101 
 
Private Equity Funds [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Private Equity Funds [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Private Equity Funds [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
131 
101 
86 
Securities Lending [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
(158)
0 
 
Securities Lending [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
(141)
0 
 
Securities Lending [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
(17)
0 
 
Securities Lending [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
0 
0 
 
Securities Lending Collateral [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
158 
0 
 
Securities Lending Collateral [Member] |
Level 1 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
141 
0 
 
Securities Lending Collateral [Member] |
Level 2 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
17 
0 
 
Securities Lending Collateral [Member] |
Level 3 [Member]
 
 
 
Defined Benefit Plan Disclosure [Line Items]
 
 
 
Defined Benefit Plan, Fair Value of Plan Assets
$ 0 
$ 0 
 
Retirement Benefits and Trusteed Assets (OPEB - Fair Value Measurements using Level 3 Inputs) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
$ 40 
$ (1)
Other Postretirement Benefit Plan
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
1,527 
1,153 
Total realized/unrealized gains (losses)
62 
196 
Plan assets at fair value, end of year
1,528 
1,527 
Other Postretirement Benefit Plan |
Hedge Funds [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, end of year
320 
314 
Other Postretirement Benefit Plan |
Private Equity Funds [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, end of year
131 
101 
Level 3 [Member] |
Other Postretirement Benefit Plan
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
260 
205 
Total realized/unrealized gains (losses)
17 
23 
Purchases
42 
41 
Sales
(20)
(9)
Plan assets at fair value, end of year
299 
260 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
15 
23 
Level 3 [Member] |
Other Postretirement Benefit Plan |
Hedge Funds [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
159 
119 
Total realized/unrealized gains (losses)
8 
14 
Purchases
9 
26 
Sales
(8)
0 
Plan assets at fair value, end of year
168 
159 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
7 
14 
Level 3 [Member] |
Other Postretirement Benefit Plan |
Private Equity Funds [Member]
 
 
Defined Benefit Plan, Change in Fair Value of Plan Assets [Roll Forward]
 
 
Plan assets at fair value, beginning of year
101 
86 
Total realized/unrealized gains (losses)
9 
9 
Purchases
33 
15 
Sales
(12)
(9)
Plan assets at fair value, end of year
131 
101 
The amount of total gains (losses) included in net income attributed to the change in unrealized gains (losses) related to assets and liabilities held at December 31, 2014 and 2013 and reflected in Operating revenues and Fuel, purchased power and gas in the Consolidated Statements of Operations
$ 8 
$ 9 
Retirement Benefits and Trusteed Assets (Details Textuals) (USD $)
12 Months Ended 12 Months Ended 12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Dec. 31, 2014
Retirement Savings Plan [Member]
Dec. 31, 2014
Retirement Savings Plan [Member]
DTE Gas Represented Employees
Dec. 31, 2014
Qualified Pension Plan [Member]
Dec. 31, 2014
Pension Plan
Dec. 31, 2013
Pension Plan
Dec. 31, 2012
Pension Plan
Dec. 31, 2014
Pension Plan
Maximum
Dec. 31, 2014
Other Postretirement Benefit Plan
Dec. 31, 2013
Other Postretirement Benefit Plan
Mar. 31, 2013
Other Postretirement Benefit Plan
Dec. 31, 2012
Other Postretirement Benefit Plan
Dec. 31, 2014
Other Postretirement Benefit Plan
Maximum
Dec. 31, 2014
Retiree Healthcare Plan [Member]
Dec. 31, 2013
Retiree Healthcare Plan [Member]
Dec. 31, 2012
Retiree Healthcare Plan [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Company contribution to employee savings plan
 
 
 
4.00% 
8.00% 
 
 
 
 
 
 
 
 
 
 
 
 
 
Company contributions
 
 
 
 
 
$ 188,000,000 
$ 195,000,000 
$ 284,000,000 
 
 
$ 24,000,000 
$ 264,000,000 
 
 
 
 
 
 
Estimated future employer contributions in next fiscal year
 
 
 
 
 
 
 
 
 
180,000,000 
 
 
 
 
200,000,000 
 
 
 
Expected return on plan assets
 
 
 
 
 
 
7.75% 
 
 
 
8.00% 
 
 
 
 
 
 
 
Transfers into Level 3
0 
1,000,000 
 
 
 
 
0 
0 
 
 
0 
0 
 
 
 
 
 
 
Transfers out of Level 3
2,000,000 
0 
 
 
 
 
0 
0 
 
 
0 
0 
 
 
 
 
 
 
Defined contribution plan, cost recognized (less than $1 million in 2012)
48,000,000 
41,000,000 
37,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
4,000,000 
2,000,000 
1,000,000 
Annual allocation to Retiree Reimbursement Account Per Participant, Retired on or before January 1, 2013
 
 
 
 
 
 
 
 
 
 
3,570 
3,500 
 
 
 
 
 
 
Annual allocation to Retiree Reimbursement Account Per Participant, Retired after January 1, 2013
 
 
 
 
 
 
 
 
 
 
3,315 
3,250 
 
 
 
 
 
 
Retiree Health Care Allowance will increase at lower of the rate of medical inflation or a set percentage
 
 
 
 
 
 
 
 
 
 
2.00% 
 
 
 
 
 
 
 
Defined Benefit Plan, Effect of One Percentage Point Increase on Service and Interest Cost Components
 
 
 
 
 
 
 
 
 
 
8,000,000 
 
 
 
 
 
 
 
Defined Benefit Plan, Effect of One Percentage Point Increase on Accumulated Postretirement Benefit Obligation
 
 
 
 
 
 
 
 
 
 
108,000,000 
 
 
 
 
 
 
 
Defined Benefit Plan, Effect of One Percentage Point Decrease on Service and Interest Cost Components
 
 
 
 
 
 
 
 
 
 
7,000,000 
 
 
 
 
 
 
 
Defined Benefit Plan, Effect of One Percentage Point Decrease on Accumulated Postretirement Benefit Obligation
 
 
 
 
 
 
 
 
 
 
94,000,000 
 
 
 
 
 
 
 
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate
 
 
 
 
 
 
4.12% 
4.95% 
4.15% 
 
4.10% 
4.95% 
4.30% 
4.15% 
 
 
 
 
Grantor Trust Balance
$ 18,000,000 
$ 17,000,000 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Stock-Based Compensation (Components of Stock Based Compensation) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Components of stock based-compensation [Abstract]
 
 
 
Compensation expense
$ 103 
$ 99 
$ 83 
Employee Service Share-based Compensation Equity and Liability, Tax
40 
38 
33 
Employee Service Share-based Compensation, Allocation of Recognized Period Costs Liability and Equity, Capitalized Amount
$ 16 
$ 15 
$ 5 
Stock-Based Compensation (Stock Option Activity) (Details) (USD $)
In Millions, except Share data, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Number of options (in shares):
 
Options outstanding beginning of the year
723,697 
Granted
0 
Exercised
(268,689)
Forfeited or expired
(10,730)
Options outstanding end of the year
444,278 
Weighted Average Exercise Price (in dollars per share):
 
Options outstanding beginning of the year
$ 42.60 
Granted
$ 0.00 
Exercised
$ 41.14 
Forfeited or expired
$ 39.41 
Options outstanding end of the year
$ 43.56 
Outstanding, Intrinsic Value
$ 17 
Stock-Based Compensation (Number, Weighted Average Exercise Price and Weighted Average Remaining Contractual Life of Options Outstanding) (Details) (USD $)
12 Months Ended
Dec. 31, 2014
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
 
Number of Options (in shares)
444,278.000000 
Weighted Average Exercise Price (in dollars per share)
$ 43.56 
Weighted Average Remaining Contractual Life (Years)
3 years 4 months 27 days 
$27.00 - $38.00 [Member]
 
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
 
Range of Exercise Prices Lower Limit
$ 27.00 
Range of Exercise Prices Upper Limit
$ 38.00 
Number of Options (in shares)
25,857 
Weighted Average Exercise Price (in dollars per share)
$ 27.70 
Weighted Average Remaining Contractual Life (Years)
4 years 1 month 28 days 
$38.01 - $42.00 [Member]
 
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
 
Range of Exercise Prices Lower Limit
$ 38.01 
Range of Exercise Prices Upper Limit
$ 42.00 
Number of Options (in shares)
82,834 
Weighted Average Exercise Price (in dollars per share)
$ 41.77 
Weighted Average Remaining Contractual Life (Years)
3 years 1 month 28 days 
$42.01 - $45.00 [Member]
 
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
 
Range of Exercise Prices Lower Limit
$ 42.01 
Range of Exercise Prices Upper Limit
$ 45.00 
Number of Options (in shares)
221,487 
Weighted Average Exercise Price (in dollars per share)
$ 43.93 
Weighted Average Remaining Contractual Life (Years)
4 years 22 days 
$45.01 - $50.00 [Member]
 
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
 
Range of Exercise Prices Lower Limit
$ 45.01 
Range of Exercise Prices Upper Limit
$ 50.00 
Number of Options (in shares)
114,100 
Weighted Average Exercise Price (in dollars per share)
$ 47.75 
Weighted Average Remaining Contractual Life (Years)
2 years 1 month 25 days 
Stock-Based Compensation (Restricted Stock Award Activity) (Details) (Restricted Stock [Member], USD $)
In Millions, except Share data, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Restricted Stock [Member]
 
 
 
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
 
 
 
Fair value of awards vested (in millions)
$ 11 
$ 8 
$ 9 
Restricted common shares awarded (in shares)
159,590 
127,785 
167,320 
Weighted average market price of shares awarded
$ 70.09 
$ 64.72 
$ 53.71 
Compensation cost charged against income (in millions)
$ 10 
$ 23 
$ 12 
Stock Based-Compensation (Stock Awards Activity Rollforward) (Details) (USD $)
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Restricted Stock (in shares):
 
 
 
Forfeitures
(10,730)
 
 
Restricted Stock [Member]
 
 
 
Restricted Stock (in shares):
 
 
 
Balance at beginning of the period
492,329 
 
 
Grants
159,590 
127,785 
167,320 
Forfeitures
(16,841)
 
 
Vested and issued
(218,760)
 
 
Balance at end of period
416,318 
492,329 
 
Weighted Average Grant Date Fair Value (in dollars per share):
 
 
 
Balance at beginning of period
$ 53.76 
 
 
Grants
$ 70.09 
$ 64.72 
$ 53.71 
Forfeitures
$ 62.41 
 
 
Vested and issued
$ 47.77 
 
 
Balance at end of period
$ 62.82 
$ 53.76 
 
Stock-Based Compensation (Performance Share Awards Compensation Expense) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Compensation Expense Recorded [Line Items]
 
 
 
Compensation expense
$ 103 
$ 99 
$ 83 
Performance Shares [Member]
 
 
 
Compensation Expense Recorded [Line Items]
 
 
 
Compensation expense
93 
77 
71 
Cash settlements
11 
9 
4 
Stock settlements
$ 61 
$ 56 
$ 41 
Stock-Based Compensation (Performance Share Awards Activity) (Details) (Performance Shares [Member], USD $)
12 Months Ended
Dec. 31, 2014
Performance Shares [Member]
 
Performance Shares (in shares):
 
Balance at beginning of period
1,608,789 
Grants
561,335 
Forfeitures
(44,250)
Payouts
(571,177)
Balance at end of period
1,554,697 
Weighted Average Grant Date Fair Value (in dollars per share):
 
Balance at beginning of period
$ 0.00 
Grants
$ 69.32 
Forfeitures
$ 69.16 
Payouts
$ 0.00 
Balance at end of period
$ 69.32 
Stock-Based Compensation (Unrecognized Compensation Costs) (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]
 
Unrecognized Compensation Cost
$ 58 
Weighted Average to be Recognized
11 months 25 days 
Restricted Stock [Member]
 
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]
 
Unrecognized Compensation Cost
10 
Weighted Average to be Recognized
1 year 23 days 
Performance Shares [Member]
 
Share Based Compensation Unrecognized and Non-Vested Cost [Line Items]
 
Unrecognized Compensation Cost
$ 48 
Weighted Average to be Recognized
11 months 22 days 
Stock-Based Compensation (Details Textuals) (USD $)
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
 
 
 
Authorized limit of common stock shares
14,500,000 
 
 
Performance units price per unit
1.00 
 
 
Weighted Average Remaining Contractual Term
3 years 4 months 27 days 
 
 
Options vested (in shares)
0 
 
 
Options grants in period
$ 0 
$ 0 
$ 0 
Options, exercises, intrinsic value
$ 11,000,000 
$ 12,000,000 
$ 25,000,000 
Stock option expense
$ 0 
$ 0 
$ 700,000 
Employee Stock Option [Member]
 
 
 
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
 
 
 
Maximum award per employee
500,000 
 
 
Award expiration period
10 years 
 
 
Award vesting period
3 years 
 
 
Restricted Stock [Member]
 
 
 
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
 
 
 
Maximum award per employee
150,000 
 
 
Performance Shares [Member]
 
 
 
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
 
 
 
Maximum award per employee
300,000 
 
 
Performance Unit [Member]
 
 
 
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
 
 
 
Maximum award per employee
1,000,000 
 
 
Segment and Related Information (Details Textuals)
Dec. 31, 2014
customers
Segment Reporting [Abstract]
 
Number of electric utility customers
2,100,000 
Number of gas utility customers
1,200,000 
Segment and Related Information (Financial Data) (Details) (USD $)
In Millions, unless otherwise specified
3 Months Ended 12 Months Ended
Dec. 31, 2014
Sep. 30, 2014
Jun. 30, 2014
Mar. 31, 2014
Dec. 31, 2013
Sep. 30, 2013
Jun. 30, 2013
Mar. 31, 2013
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
$ 3,078 
$ 2,595 
$ 2,698 
$ 3,930 
$ 2,533 
$ 2,387 
$ 2,225 
$ 2,516 
$ 12,301 
$ 9,661 
$ 8,791 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
1,145 
1,094 
1,018 
Interest income
 
 
 
 
 
 
 
 
(10)
(9)
(10)
Interest Expense
 
 
 
 
 
 
 
 
429 
436 
440 
Income Taxes
 
 
 
 
 
 
 
 
364 
254 
286 
Net Income Attributable to DTE Energy Company
299 
156 
124 
326 
124 
198 
105 
234 
905 
661 
610 
Total Assets
27,974 
 
 
 
25,935 
 
 
 
27,974 
25,935 
26,339 
Goodwill
2,018 
 
 
 
2,018 
 
 
 
2,018 
2,018 
2,018 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
2,049 
1,876 
2,018 
Continuing Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
 
 
8,791 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
 
 
995 
Interest income
 
 
 
 
 
 
 
 
 
 
(10)
Interest Expense
 
 
 
 
 
 
 
 
 
 
440 
Income Taxes
 
 
 
 
 
 
 
 
 
 
286 
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
 
 
666 
Total Assets
 
 
 
 
 
 
 
 
 
 
26,339 
Goodwill
 
 
 
 
 
 
 
 
 
 
2,018 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
 
 
1,969 
Discontinued Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
 
 
(56)
Total Assets
 
 
 
 
 
 
 
 
 
 
0 
Goodwill
 
 
 
 
 
 
 
 
 
 
0 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
 
 
49 
Operating Segments [Member] |
Electric [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
5,283 
5,199 
5,293 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
933 
902 
827 
Interest income
 
 
 
 
 
 
 
 
(1)
(1)
(1)
Interest Expense
 
 
 
 
 
 
 
 
250 
268 
272 
Income Taxes
 
 
 
 
 
 
 
 
296 
252 
280 
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
528 
484 
483 
Total Assets
18,715 
 
 
 
17,508 
 
 
 
18,715 
17,508 
17,755 
Goodwill
1,208 
 
 
 
1,208 
 
 
 
1,208 
1,208 
1,208 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
1,561 
1,325 
1,230 
Operating Segments [Member] |
Gas [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
1,636 
1,474 
1,315 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
99 
95 
92 
Interest income
 
 
 
 
 
 
 
 
(7)
(7)
(7)
Interest Expense
 
 
 
 
 
 
 
 
57 
58 
59 
Income Taxes
 
 
 
 
 
 
 
 
78 
77 
50 
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
140 
143 
115 
Total Assets
4,283 
 
 
 
3,938 
 
 
 
4,283 
3,938 
4,059 
Goodwill
743 
 
 
 
743 
 
 
 
743 
743 
745 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
224 
209 
221 
Operating Segments [Member] |
Power and Industrial Projects [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
2,289 
1,950 
1,823 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
77 
72 
65 
Interest income
 
 
 
 
 
 
 
 
(5)
(6)
(7)
Interest Expense
 
 
 
 
 
 
 
 
28 
27 
37 
Income Taxes
 
 
 
 
 
 
 
 
(100)
(45)
(44)
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
90 
66 
42 
Total Assets
1,009 
 
 
 
1,067 
 
 
 
1,009 
1,067 
991 
Goodwill
26 
 
 
 
26 
 
 
 
26 
26 
26 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
77 
93 
281 
Operating Segments [Member] |
Gas Storage and Pipelines [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
203 
132 
96 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
34 
23 
8 
Interest income
 
 
 
 
 
 
 
 
(6)
(7)
(8)
Interest Expense
 
 
 
 
 
 
 
 
22 
18 
8 
Income Taxes
 
 
 
 
 
 
 
 
53 
45 
39 
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
82 
70 
61 
Total Assets
884 
 
 
 
824 
 
 
 
884 
824 
668 
Goodwill
24 
 
 
 
24 
 
 
 
24 
24 
22 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
184 
245 
233 
Operating Segments [Member] |
Energy Trading [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
3,762 
1,771 
1,109 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
1 
1 
2 
Interest income
 
 
 
 
 
 
 
 
0 
0 
0 
Interest Expense
 
 
 
 
 
 
 
 
7 
8 
8 
Income Taxes
 
 
 
 
 
 
 
 
77 
(38)
7 
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
122 
(58)
12 
Total Assets
755 
 
 
 
623 
 
 
 
755 
623 
629 
Goodwill
17 
 
 
 
17 
 
 
 
17 
17 
17 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
3 
3 
1 
Operating Segments [Member] |
Corporate and Other [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
2 
3 
3 
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
1 
1 
1 
Interest income
 
 
 
 
 
 
 
 
(48)
(51)
(52)
Interest Expense
 
 
 
 
 
 
 
 
122 
120 
121 
Income Taxes
 
 
 
 
 
 
 
 
(40)
(37)
(46)
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
(57)
(44)
(47)
Total Assets
3,209 
 
 
 
2,945 
 
 
 
3,209 
2,945 
3,074 
Goodwill
0 
 
 
 
0 
 
 
 
0 
0 
0 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
0 
1 
3 
Intersegment Eliminations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
(874)
(868)
(848)
Depreciation, Depletion and Amortization
 
 
 
 
 
 
 
 
0 
0 
0 
Interest income
 
 
 
 
 
 
 
 
57 
63 
65 
Interest Expense
 
 
 
 
 
 
 
 
(57)
(63)
(65)
Income Taxes
 
 
 
 
 
 
 
 
0 
0 
0 
Net Income Attributable to DTE Energy Company
 
 
 
 
 
 
 
 
0 
0 
0 
Total Assets
(881)
 
 
 
(970)
 
 
 
(881)
(970)
(837)
Goodwill
0 
 
 
 
0 
 
 
 
0 
0 
0 
Capital Expenditures and Acquisitions
 
 
 
 
 
 
 
 
0 
0 
0 
Intersegment Eliminations [Member] |
Discontinued Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
0 
0 
(2)
Intersegment Eliminations [Member] |
Electric [Member] |
Continuing Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
(29)
(26)
(29)
Intersegment Eliminations [Member] |
Gas [Member] |
Continuing Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
(6)
(4)
(4)
Intersegment Eliminations [Member] |
Power and Industrial Projects [Member] |
Continuing Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
(794)
(816)
(801)
Intersegment Eliminations [Member] |
Gas Storage and Pipelines [Member] |
Continuing Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
(9)
(3)
(6)
Intersegment Eliminations [Member] |
Energy Trading [Member] |
Continuing Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
(33)
(43)
(43)
Intersegment Eliminations [Member] |
Corporate and Other [Member] |
Continuing Operations [Member]
 
 
 
 
 
 
 
 
 
 
 
Segment Reporting Information [Line Items]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
 
 
 
 
 
 
 
 
$ (3)
$ 24 
$ 37 
Supplementary Quarterly Financial Information (Unaudited) (Details) (USD $)
In Millions, except Per Share data, unless otherwise specified
3 Months Ended 12 Months Ended
Dec. 31, 2014
Sep. 30, 2014
Jun. 30, 2014
Mar. 31, 2014
Dec. 31, 2013
Sep. 30, 2013
Jun. 30, 2013
Mar. 31, 2013
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Quarterly Financial Information Disclosure [Abstract]
 
 
 
 
 
 
 
 
 
 
 
Operating Revenues
$ 3,078 
$ 2,595 
$ 2,698 
$ 3,930 
$ 2,533 
$ 2,387 
$ 2,225 
$ 2,516 
$ 12,301 
$ 9,661 
$ 8,791 
Operating Income
542 
239 
249 
560 
241 
329 
223 
410 
1,590 
1,203 
1,279 
Net Income Attributable to DTE Energy Company
$ 299 
$ 156 
$ 124 
$ 326 
$ 124 
$ 198 
$ 105 
$ 234 
$ 905 
$ 661 
$ 610 
Basic Earnings per Share (in dollars per share)
$ 1.68 
$ 0.88 
$ 0.70 
$ 1.84 
$ 0.70 
$ 1.13 
$ 0.60 
$ 1.35 
$ 5.11 
$ 3.76 
$ 3.56 
Diluted Earnings per Share (in dollars per share)
$ 1.68 
$ 0.88 
$ 0.70 
$ 1.84 
$ 0.70 
$ 1.13 
$ 0.60 
$ 1.34 
$ 5.10 
$ 3.76 
$ 3.55 
Subsequent Event (Details) (Electric [Member], Subsequent Event [Member], USD $)
In Millions, unless otherwise specified
0 Months Ended
Jan. 21, 2015
Electric [Member] |
Subsequent Event [Member]
 
Subsequent Event [Line Items]
 
Payments to acquire business
$ 240 
Valuation and Qualifying Accounts Valuation and Qualifying Accounts (Details) (USD $)
In Millions, unless otherwise specified
12 Months Ended
Dec. 31, 2014
Dec. 31, 2013
Dec. 31, 2012
Movement in Valuation Allowances and Reserves [Roll Forward]
 
 
 
Balance at Beginning of Period
$ 55 
$ 62 
$ 162 
Charged to cost and expenses
95 
94 
79 
Charged to other accounts
20 
23 
16 
Deductions
(116)
(124)
(195)
Balance at End of Period
$ 54 
$ 55 
$ 62