Oncor Electric Delivery S-4 8 Sep 15 Registration of securities issued in business combination transactions Financial data

Document and Entity Information

Document and Entity Information - USD ($)	6 Months Ended
	Jun. 30, 2015	Jul. 30, 2015	Feb. 26, 2015	Dec. 31, 2014
Entity Registrant Name	ONCOR ELECTRIC DELIVERY CO LLC
Entity Central Index Key	1,193,311
Document Type	S4
Document Period End Date	Jun. 30, 2015
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0		0
Entity Public Float				$ 0
Oncor's Management and Board of Directors [Member]
Entity Outstanding Membership Interests		0.22%	0.22%
Oncor Electric Delivery Holdings Company LLC [Member]
Entity Outstanding Membership Interests		80.03%	80.03%
Texas Transmission and Investment LLC [Member]
Entity Outstanding Membership Interests		19.75%	19.75%

Condensed Statements of Consoli

Condensed Statements of Consolidated Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Operating revenues:
Nonaffiliates	$ 714	$ 687	$ 1,424	$ 1,364	$ 2,851	$ 2,585	$ 2,366
Affiliates	224	225	460	465	971	967	962
Total operating revenues	938	912	1,884	1,829	3,822	3,552	3,328
Operating expenses:
Wholesale transmission service	199	185	393	364	755	588	502
Operation and maintenance	168	168	353	334	698	681	669
Depreciation and amortization	220	210	437	420	851	814	771
Provision in lieu of income taxes (Note 10)	57	60	115	123	280	247	240
Taxes other than amounts related to income taxes	108	106	220	215	438	424	415
Total operating expenses	752	729	1,518	1,456	3,022	2,754	2,597
Operating income	186	183	366	373	800	798	731
Other income and deductions:
Other income (Note 11)	1	3	4	7	13	18	26
Other deductions (Note 11)	7	4	12	7	15	15	64
Nonoperating provision in lieu of income taxes	(2)		(2)	1	(2)	2	(6)
Interest income		1	1	2	3	4	24
Interest expense and related charges (Note 11)	84	89	165	177	353	371	374
Net income	$ 98	$ 94	$ 196	$ 197	$ 450	$ 432	$ 349

Condensed Statements of Consol3

Condensed Statements of Consolidated Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Statements Of Consolidated Comprehensive Income [Abstract]
Net income	$ 98	$ 94	$ 196	$ 197	$ 450	$ 432	$ 349
Other comprehensive income (loss):
Cash flow hedges - derivative value net loss recognized in net income (net of tax expense of $-, $-, $- and $-) (Note 1)	1	1	1	1	2	2	3
Defined benefit pension plans (net of tax benefit of $-, $-, $- and $-) (Note 9)			1		(61)	(19)	(3)
Total other comprehensive income (loss)	1	1	2	1	(59)	(17)
Comprehensive income	$ 99	$ 95	$ 198	$ 198	$ 391	$ 415	$ 349

Condensed Statements Of Consol4

Condensed Statements Of Consolidated Comprehensive Income (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Statements Of Consolidated Comprehensive Income [Abstract]
Cash flow hedges - derivative value net loss recognized in net income, net of tax expense	$ 1	$ 1	$ 1
Defined benefit pension plans- net tax benefit	$ 33	$ 11	$ 1

Condensed Statements Of Consol5

Condensed Statements Of Consolidated Cash Flows - USD ($) $ in Millions	6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash flows - operating activities:
Net income	$ 196	$ 197	$ 450	$ 432	$ 349
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	459	440	892	848	802
Provision in lieu of deferred income taxes - net	(46)	(4)	148	194	208
Other - net	(1)	(2)	(3)	(4)	(4)
Changes in operating assets and liabilities:
Accounts receivable - trade (including affiliates) (Note 12)			8	(129)	52
Inventories			(9)	9	(3)
Accounts payable - trade (including affiliates)			15	38	(9)
Deferred revenues (Note 4)	(16)	(29)	(44)	(53)	(101)
Other - assets			(233)	172	(17)
Other - liabilities			52	(137)	(8)
Changes in other operating assets and liabilities	(18)	(211)
Cash provided by operating activities	574	391	1,276	1,370	1,269
Cash flows - financing activities:
Issuances of long-term debt (Note 6)	725	250	250	100	900
Repayments of long-term debt (Note 6)	(569)	(65)	(131)	(125)	(1,018)
Net increase in short-term borrowings (Note 5)	69	77	(34)	10	343
Distributions to members (Note 8)	(165)	(110)	(282)	(310)	(225)
Decrease in note receivable from TCEH (Note 12)					20
Sale of related-party agreements (Note 12)					159
Debt discount, premium, financing and reacquisition expenses - net	(12)	(4)	(5)	1	(46)
Other-net					(1)
Cash provided by financing activities	48	148	(202)	(324)	132
Cash flows - investing activities:
Capital expenditures	(625)	(572)	(1,107)	(1,079)	(1,389)
Other - net	15	11	10	15	21
Cash used in investing activities	(610)	(561)	(1,097)	(1,064)	(1,368)
Net change in cash and cash equivalents	12	(22)	(23)	(18)	33
Cash and cash equivalents - beginning balance	4	27	27	45	12
Cash and cash equivalents - ending balance	$ 16	$ 5	$ 4	$ 27	$ 45

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions		Jun. 30, 2015	Dec. 31, 2014		Dec. 31, 2013
Current assets:
Cash and cash equivalents		$ 16	$ 4		$ 27
Restricted cash - Bondco (Note 11)		64	56		52
Trade accounts receivable from nonaffiliates - net (Note 11)		430	407		385
Trade accounts and other receivables from affiliates - net (Note 10)		138	118		135
Amounts receivable from members related to income taxes (Note 10)		29	180		23
Materials and supplies inventories - at average cost		76	73		65
Prepayments and other current assets		89	88		79
Total current assets		842	926		766
Restricted cash - Bondco (Note 11)			16		16
Investments and other property (Note 11)		98	97		91
Property, plant and equipment - net (Note 11)		12,777	12,463		11,902
Goodwill (Notes 11)		4,064	4,064		4,064
Other noncurrent assets		71	67		71
Total assets		19,173	19,062		18,234
Current liabilities:
Short-term borrowings (Note 5)		780	711		745
Trade accounts payable to nonaffiliates		179	202		178
Amounts payable to members related to income taxes (Note 10)		12	24		23
Accrued taxes other than amounts related to income taxes		103	174		169
Accrued interest		83	93		95
Other current liabilities		136	156		135
Total current liabilities		1,404	1,999		1,476
Long-term debt, less amounts due currently (Note 6)		5,680	4,997		5,381
Liability in lieu of deferred income taxes (Notes 10)		2,514	2,559		2,414
Other noncurrent liabilities and deferred credits (Notes 11)		2,024	1,989		1,554
Total liabilities		11,622	$ 11,544		$ 10,825
Commitments and contingencies (Note 7)
Membership interests (Note 8):
Capital account - number of interests outstanding 2015 and 2014 - 635,000,000		7,656	$ 7,625		$ 7,457
Accumulated other comprehensive loss		(105)	(107)		(48)
Total membership interests		7,551	7,518		7,409
Total liabilities and membership interests		19,173	19,062		18,234
Oncor
Current assets:
Regulatory assets - net (Note 4)		1,274	1,321		1,098
Current liabilities:
Long-term debt due currently (Note 6)	[1]		500
Long-term debt, less amounts due currently (Note 6)		5,680	4,956	[1]	5,202	[1]
Bondco
Current assets:
Regulatory assets - net (Note 4)		47	108		226
Current liabilities:
Long-term debt due currently (Note 6)		$ 111	139	[2]	131	[2]
Long-term debt, less amounts due currently (Note 6)	[2]		$ 41		$ 179
[1]	Secured by first priority lien on certain transmission and distribution assets equally and ratably with all of Oncor's other secured indebtedness. See "Deed of Trust" below for additional information.
[2]	The transition bonds are nonrecourse to Oncor and were issued to securitize a regulatory asset.

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - shares	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Condensed Consolidated Balance Sheets [Abstract]
Capital account, interests outstanding	635,000,000	635,000,000	635,000,000	635,000,000

Statements Of Consolidated Memb

Statements Of Consolidated Membership Interests - USD ($) $ in Millions	3 Months Ended				6 Months Ended		12 Months Ended
	Dec. 31, 2014	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2013	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Capital account:
Balance at beginning of period		$ 7,457		$ 7,335	$ 7,625	$ 7,457	$ 7,457	$ 7,335	$ 7,212
Net income	$ 94	104	$ 103	87	196	197	450	432	349
Distributions to members							(282)	(310)	(225)
Sale of related-party agreements (net of tax benefit of $-, $- and $1) (Note 12)									(2)
Other									1
Balance at end of period (number of interests outstanding: 2014, 2013, and 2012 - 635 million)	7,625		7,457				7,625	7,457	7,335
Accumulated other comprehensive income (loss) net of tax effects:
Balance at beginning of period		$ (48)		$ (31)	(107)	$ (48)	(48)	(31)	(31)
Net effects of cash flow hedges (net of tax expense of $1, $1 and $1)							2	2	3
Defined benefit pension plans (net of tax benefit of $-, $-, $- and $-) (Note 9)					1		(61)	(19)	(3)
Balance at end of period	(107)		(48)		$ (105)		(107)	(48)	(31)
Total membership interests at end of period	$ 7,518		$ 7,409				$ 7,518	$ 7,409	$ 7,304

Statements Of Consolidated Mem9

Statements Of Consolidated Membership Interests (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statements Of Consolidated Membership Interest [Abstract]
Sale of related-party agreements, tax benefit			$ 1
Interests outstanding	635,000,000	635,000,000	635,000,000
Net effects of cash flow hedges, tax expense	$ 1	$ 1	$ 1
Defined benefit pension plans- net tax benefit	$ 33	$ 11	$ 1

Description Of Business and Sig

Description Of Business and Significant Accounting Policies	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Description Of Business and Significant Accounting Policies [Abstract]
DESCRIPTION OF BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES	ONCOR ELECTRIC DELIVERY COMPANY LLC NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Unaudited) 1. BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES Description of Business References in this report to “we,” “our,” “us” and “the company” are to Oncor and/or its subsidiary as apparent in the context. See “Glossary” for definition of terms and abbreviations. We are a regulated electricity transmission and distribution company principally engaged in providing delivery services to REPs, including subsidiaries of TCEH, that sell power in the north-central, eastern and western parts of Texas. Revenues from TCEH represented 24% and 25% of our total operating revenues for the six months ended June 30, 2015 and 2014, respectively. We are a direct, majority-owned subsidiary of Oncor Holdings, which is a direct, wholly-owned subsidiary of EFIH, a direct, wholly-owned subsidiary of EFH Corp. EFH Corp. is a subsidiary of Texas Holdings, which is controlled by the Sponsor Group. Oncor Holdings owns 80.03% of our membership interests, Texas Transmission owns 19.75% of our membership interests and certain members of our management team and board of directors indirectly own the remaining membership interests through Investment LLC. We are managed as an integrated business; consequently, there are no separate reportable business segments. Our consolidated financial statements include our wholly-owned, bankruptcy-remote financing subsidiary, Bondco, a variable interest entity . This financing subsidiary was organized for the limited purpose of issuing certain transition bonds in 2003 and 2004. Bondco issued $1.3 billion principal amount of transition bonds to recover generation-related regulatory asset stranded costs and other qualified costs under an order issued by the PUCT in 2002. Various “ring-fencing” measures have been taken to enhance the separateness between the Oncor Ring-Fenced Entities and the Texas Holdings Group and our credit quality. These measures serve to mitigate our and Oncor Holdings’ credit exposure to the Texas Holdings Group and to reduce the risk that our assets and liabilities or those of Oncor Holdings would be substantively consolidated with the assets and liabilities of the Texas Holdings Group in connection with a bankruptcy of one or more of those entities, including the EFH Bankruptcy Proceedings discussed below. Such measures include, among other things: our sale of a 19.75% equity interest to Texas Transmission in November 2008; maintenance of separate books and records for the Oncor Ring-Fenced Entities; our board of directors being comprised of a majority of independent directors; and prohibitions on the Oncor Ring-Fenced Entities providing credit support to, or receiving credit support from, any member of the Texas Holdings Group. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of the Texas Holdings Group, including TXU Energy and Luminant, and none of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or contractual obligations of any member of the Texas Holdings Group. We do not bear any liability for debt or contractual obligations of the Texas Holdings Group, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from the Texas Holdings Group. EFH Corp. Bankruptcy Proceedings On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. The Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. We believe the “ring-fencing” measures discussed above mitigate our potential exposure to the EFH Bankruptcy Proceedings. See Note 2 for a discussion of the potential impacts of the EFH Bankruptcy Proceedings on our financial statements. Basis of Presentation Our condensed consolidated financial statements have been prepared in accordance with US GAAP and on the same basis as the audited financial statements in our 2014 Form 10-K. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with US GAAP have been omitted pursuant to the rules and regulations of the SEC . Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by US GAAP, they should be read in conjunction with the audited financial statements and related notes in our 2014 Form 10-K. The results of operations for an interim period may not give a true indication of results for a full year due to seasonality. All dollar amounts in the financial statements and tables in the notes are stated in millions of US dollars unless otherwise indicated. Use of Estimates Preparation of our financial statements requires management to make estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information. Derivative Instruments and Mark-to-Market Accounting We have from time-to-time entered into derivative instruments to hedge interest rate risk. If the instrument meets the definition of a derivative under accounting standards related to derivative instruments and hedging activities, the fair value of each derivative is recognized on the balance sheet as a derivative asset or liability and changes in the fair value are recognized in net income, unless criteria for certain exceptions are met. This recognition is referred to as “mark-to-market” accounting. Reconcilable Tariffs The PUCT has designated certain tariffs (TCRF, EECRF surcharges, AMS surcharges and charges related to transition bonds) as reconcilable, which means the differences between amounts billed under these tariffs and the related incurred costs are deferred as either regulatory assets or regulatory liabilities. Accordingly, at prescribed intervals, future tariffs are adjusted to either repay regulatory liabilities or collect regulatory assets. Contingencies We evaluate and account for contingencies using the best information available. A loss contingency is accrued and disclosed when it is probable that an asset has been impaired or a liability incurred and the amount of the loss can be reasonably estimated. If a range of probable loss is established, the minimum amount in the range is accrued, unless some other amount within the range appears to be a better estimate. If the probable loss cannot be reasonably estimated, no accrual is recorded, but the loss contingency is disclosed to the effect that the probable loss cannot be reasonably estimated. A loss contingency will be disclosed when it is reasonably possible that an asset has been impaired or a liability incurred. If the likelihood that an impairment or incurrence is remote, the contingency is neither accrued nor disclosed. Gain contingencies are recognized upon realization. Changes in Accounting Standards In April 2015, the Financial Accounting Standards Board issued a new accounting standard update, which changes the presentation of debt issuance costs in the balance sheet. The update requires that such costs be presented as a direct reduction to the face value of the related debt rather than as an asset. This will make the presentation of debt issuance costs consistent with debt discounts. The update is effective for interim and annual periods beginning after December 15, 2015. Early application is permitted. When adopted, we anticipate that both other noncurrent assets and long-term debt amounts will decrease by approximately $40 million.	1. DESCRIPTION OF BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES Description of Business References in this report to “we,” “our,” “us” and “the company” are to Oncor and/or its subsidiary as apparent in the context. See “Glossary” for definition of terms and abbreviations. We are a regulated electricity transmission and distribution company principally engaged in providing delivery services to REPs, including subsidiaries of TCEH, that sell power in the north-central, eastern and western parts of Texas. Revenues from TCEH represented 25 %, 27 % and 29 % of our total operating revenues for the years ended December 31, 2014, 2013 and 2012, respectively. We are a direct, majority-owned subsidiary of Oncor Holdings, which is a direct, wholly-owned subsidiary of EFIH, a direct, wholly-owned subsidiary of EFH Corp. EFH Corp. is a subsidiary of Texas Holdings, which is controlled by the Sponsor Group. Oncor Holdings owns 80.03 % of our membership interests, Texas Transmission owns 19.75 % of our membership interests and certain members of our management team and board of directors indirectly own the remaining membership interests through Investment LLC. We are managed as an integrated business; consequently, there are no separate reportable business segments. Our consolidated financial statements include our wholly-owned, bankruptcy-remote financing subsidiary, Bondco, a VIE (see Note 13) . This financing subsidiary was organized for the limited purpose of issuing certain transition bonds to recover generation-related regulatory asset stranded costs and other qualified costs under an order issued by the PUCT in 2002. Bondco issued an aggregate $ 1.3 billion principal amount of transition bonds during 2003 and 2004. At December 31, 2014, $ 180 million principal amount of transition bonds (maturing in 2015 and 2016) was outstanding (see Note 7). Various “ring-fencing” measures have been taken to enhance the separateness between the Oncor Ring-Fenced Entities and the Texas Holdings Group and our credit quality. These measures serve to mitigate our and Oncor Holdings’ credit exposure to the Texas Holdings Group and to reduce the risk that our assets and liabilities or those of Oncor Holdings would be substantively consolidated with the assets and liabilities of the Texas Holdings Group in connection with a bankruptcy of one or more of those entities , including the EFH Bankruptcy Proceedings discussed below . Such measures include, among other things: our sale of a 19.75% equity interest to Texas Transmission in November 2008; maintenance of separate books and records for the Oncor Ring-Fenced Entities; our board of directors being comprised of a majority of independent directors; and prohibitions on the Oncor Ring-Fenced Entities providing credit support to, or receiving credit support from, any member of the Texas Holdings Group. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of the Texas Holdings Group, including TXU Energy and Luminant, and none of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or contractual obligations of any member of the Texas Holdings Group. We do not bear any liability for debt or contractual obligations of the Texas Holdings Group, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from the Texas Holdings Group. EFH Bankruptcy Proceedings On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. The Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. We believe the “ring-fencing” measures discussed above mitigate our potential exposure to the EFH Bankruptcy Proceedings. See Note 2 for a discussion of the potential impacts of the EFH Bankruptcy Proceedings on our financial statements. Basis of Presentation Our consolidated financial statements have been prepared in accordance with US GAAP and on the same basis as the audited financial statements in our Annual Report on Form 10-K for the year ended December 31, 2013. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. All dollar amounts in the financial statements and tables in the notes are stated in millions of US dollars unless otherwise indicated. Consolidation of Variable Interest Entities A VIE is an entity with which we have a relationship or arrangement that indicates some level of control over the entity or results in economic risks to us. We consolidate a VIE if we have: a) the power to direct the significant activities of the VIE and b) the right or obligation to absorb profit and loss from the VIE (primary beneficiary). See Note 13. Income Taxes Effective with the November 2008 sale of equity interests to Texas Transmission and Investment LLC, we became a partnership for US federal income tax purposes, and subsequently we are not a member of EFH Corp.’s consolidated tax group and only EFH Corp.’s share of our partnership income is included in its consolidated federal income tax return. Our tax sharing agreement with Oncor Holdings and EFH Corp. was amended in November 2008 to include Texas Transmission and Investment LLC. The tax sharing agreement provides for the calculation of tax liability substantially as if we and Oncor Holdings were taxed as corporations, and requires tax payments to members determined on that basis (without duplication for any income taxes paid by a subsidiary of Oncor Holdings). While partnerships are not subject to income taxes, in consideration of the tax sharing agreement and the presentation of our financial statements as an entity subject to cost-based regulatory rate-setting processes, with such costs including income taxes, the financial statements present amounts determined under the tax sharing agreement as “provision in lieu of income taxes” and “liability in lieu of deferred income taxes” for periods subsequent to the sales of equity interests discussed in Note 4. Such amounts are determined in accordance with the provisions of accounting guidance for income taxes and for uncertainty in income taxes and thus differences between the book and tax bases of assets and liabilities are accounted for as if we were taxed as a corporation. The accounting guidance for rate-regulated enterprises requires the recognition of regulatory assets or liabilities if it is probable such deferred tax amounts will be recovered from, or returned to customers in future rates. Investment tax credits are amortized to income over the estimated lives of the related properties. We classify interest and penalties expense related to uncertain tax positions as current provision in lieu of income taxes as discussed in Note 4. Use of Estimates Preparation of our financial statements requires management to make estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information. No material adjustments were made to previous estimates or assumptions during the current year. Derivative Instruments and Mark-to-Market Accounting We have from time-to-time entered into derivative instruments to hedge interest rate risk. If the instrument meets the definition of a derivative under accounting standards related to derivative instruments and hedging activities, the fair value of each derivative is recognized on the balance sheet as a derivative asset or liability and changes in the fair value are recognized in net income, unless criteria for certain exceptions are met. This recognition is referred to as “mark-to-market” accounting. Reconcilable Tariffs The PUCT has designated certain tariffs (TCRF, EECRF surcharges, AMS surcharges and charges related to transition bonds) as reconcilable, which means the differences between amounts billed under these tariffs and the related incurred costs are deferred as either regulatory assets or regulatory liabilities. Accordingly, at prescribed intervals, future tariffs are adjusted to either repay regulatory liabilities or collect regulatory assets. Revenue Recognition R evenue includes an estimate for electricity delivery services provided from the billed meter reading date to the end of the period (unbilled revenue). For electricity delivery services billed on the basis of kWh volumes, unbilled revenue is based on data collected through our AMS. For other electricity delivery services, unbilled revenue is based on average daily revenues for the most recent period applied to the number of unmetered days through the end of the period. Impairment of Long-Lived Assets and Goodwill We evaluate long-lived assets (including intangible assets with finite lives) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. We also evaluate goodwill for impairment annually (at December 1) and whenever events or changes in circumstances indicate that an impairment may exist. The determination of the existence of these and other indications of impairment involves judgments that are subjective in nature and may require the use of estimates in forecasting future results and cash flows. If at the assessment date our carrying value exceeds our estimated fair value (enterprise value), then the estimated enterprise value is compared to the estimated fair values of our operating assets (including identifiable intangible assets) and liabilities at the assessment date. The resultant implied goodwill amount is compared to the recorded goodwill amount. Any excess of the recorded goodwill amount over the implied goodwill amount is written off as an impairment charge. The goodwill impairment test performed in 2014 was based on a qualitative assessment in which we considered macroeconomic conditions, industry and market considerations, cost factors, overall financial performance and other relative factors. Goodwill impairment tests performed in 2013 and 2012 were based on determinations of enterprise value using discounted cash flow analyses, comparable company equity values and any relevant transactions indicative of enterprise values (quantitative assessment). Based on tests results, no impairments were recognized in 2014, 2013 or 2012 . System of Accounts Our accounting records have been maintained in accordance with the FERC Uniform System of Accounts as adopted by the PUCT. Defined Benefit Pension Plans and OPEB Plans We have liabilities under pension plans that offer benefits based on either a traditional defined benefit formula or a cash balance formula and an OPEB plan that offers certain health care and life insurance benefits to eligible employees and their eligible dependents upon the retirement of such employees from the company. Costs of pension and OPEB plans are dependent upon numerous factors, assumptions and estimates. In 2012, EFH Corp. made various changes to the EFH Retirement Plan, including splitting off into a new plan all of the assets and liabilities associated with Oncor employees and all retirees and terminated vested participants of EFH Corp. and its subsidiaries (including discontinued businesses). See Note 10 for additional information regarding pension and OPEB plans. Contingencies We evaluate and account for contingencies using the best information available. A loss contingency is accrued and disclosed when it is probable that an asset has been impaired or a liability incurred and the amount of the loss can be reasonably estimated. If a range of probable loss is established, the minimum amount in the range is accrued, unless some other amount within the range appears to be a better estimate. If the probable loss cannot be reasonably estimated, no accrual is recorded, but the loss contingency is disclosed to the effect that the probable loss cannot be reasonably estimated. A loss contingency will be disclosed when it is reasonably possible that an asset has been impaired or a liability incurred. If the likelihood that an impairment or incurrence is remote, the contingency is neither accrued nor disclosed. Gain contingencies are recognized upon realization. Fair Value of Nonderivative Financial Instruments The carrying amounts for financial assets classified as current assets and the carrying amounts for financial liabilities classified as current liabilities approximate fair value due to the short maturity of such instruments. The fair values of other financial instruments, for which carrying amounts and fair values have not been presented, are not materially different than their related carrying amounts. The following discussion of fair value accounting standards applies primarily to our determination of the fair value of assets in the pension and OPEB plans trusts (see Note 10) and long-term debt (see Note 7). Accounting standards related to the determination of fair value define fair value 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. We use a “mid-market” valuation convention (the mid-point price between bid and ask prices) as a practical expedient to measure fair value for the majority of our assets and liabilities subject to fair value measurement on a recurring basis. We primarily use the market approach for recurring fair value measurements and use valuation techniques to maximize the use of observable inputs and minimize the use of unobservable inputs. We categorize our assets and liabilities recorded at fair value based upon the following fair value hierarchy: · Level 1 valuations use quoted prices in active markets for identical assets or liabilities that are accessible at the measurement date. An active market is a market in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. · Level 2 valuations use inputs that, in the absence of actively quoted market prices, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include: (a) quoted prices for similar assets or liabilities in active markets, (b) quoted prices for identical or similar assets or liabilities in markets that are not active, (c) inputs other than quoted prices that are observable for the asset or liability such as interest rates and yield curves observable at commonly quoted intervals and (d) inputs that are derived principally from or corroborated by observable market data by correlation or other means. Our Level 2 valuations utilize over-the-counter broker quotes, quoted prices for similar assets or liabilities that are corroborated by correlations or other mathematical means and other valuation inputs. · Level 3 valuations use unobservable inputs for the asset or liability. Unobservable inputs are used to the extent observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at the measurement date. We use the most meaningful information available from the market combined with internally developed valuation methodologies to develop our best estimate of fair value. We utilize several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those items that are measured on a recurring basis. Franchise Taxes Franchise taxes are assessed to us by local governmental bodies, based on kWh delivered and are the principal component of taxes other than amounts related to income taxes as reported in the income statement. Franchise taxes are not a “pass through” item. The rates we charge customers are intended to recover the franchise taxes, but we are not acting as an agent to collect the taxes from customers. Cash and Cash Equivalents For purposes of reporting cash and cash equivalents, temporary cash investments purchased with a remaining maturity of three months or less are considered to be cash equivalents. See Note 13 for details regarding restricted cash. Property, Plant and Equipment Properties are stated at original cost. The cost of self-constructed property additions includes materials and both direct and indirect labor and applicable overhead and an allowance for funds used during construction. D epreciation of property, plant and equipment is calculated on a straight-line basis over the estimated service lives of the properties based on depreciation rates approved by the PUCT. As is common in the industry, depreciation expense is recorded using composite depreciation rates that reflect blended estimates of the lives of major asset groups as compared to depreciation expense calculated on a component asset-by-asset basis. Depreciation rates include plant removal costs as a component of depreciation expense, consistent with regulatory treatment. Actual removal costs incurred are charged to accumulated depreciation. When accrued removal costs exceed incurred removal costs, the difference is reclassified as a regulatory obligation to retire assets in the future. Allowance for Funds Used During Construction (AFUDC) AFUDC is a regulatory cost accounting procedure whereby both interest charges on borrowed funds and a return on equity capital used to finance construction are included in the recorded cost of utility plant and equipment being constructed. AFUDC is capitalized on all projects involving construction periods lasting greater than thirty days. The equity portion of capitalized AFUDC is accounted for as other income. We recorded no equity AFUDC in the years ended December 31, 2014 and 2013 and $ 1 million in the year ended December 31, 2012. See Note 13 for detail of amounts charged to interest expense. Regulatory Assets and Liabilities Our financial statements reflect regulatory assets and liabilities under cost-based rate regulation in accordance with accounting standards related to the effect of certain types of regulation. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital and the timing and amount of assets to be recovered by rates. See Note 5 for details of regulatory assets and liabilities. Changes in Accounting Standards In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update No. 2014-09 (ASU 2014-09), Revenue from Contracts with Customers . ASU 2014-09 introduces new, increased requirements for disclosure of revenue in financial statements and is intended to eliminate inconsistencies in revenue recognition and thereby improve financial reporting comparability across entities, industries and capital markets. ASU 2014-09 is effective for annual reporting periods (including interim reporting periods within those periods) beginning after December 15, 2016 for public entities. Early application is not permitted. We are currently evaluating the potential impact of ASU 2014-09. The adoption of ASU 2014-09 is not expected to have a material effect on our reported results of operations, financial condition or cash flows.

EFH Bankruptcy Proceedings

EFH Bankruptcy Proceedings	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
EFH Bankruptcy Proceedings [Abstract]
EFH BANKRUPTCY PROCEEDINGS	2. EFH BANKRUPTCY PROCEEDINGS On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. The Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. We believe the “ring-fencing” measures discussed above mitigate our potential exposure to the EFH Bankruptcy Proceedings. The US Bankruptcy Code automatically enjoined, or stayed, us from judicial or administrative proceedings or filing of other actions against our affiliates or their property to recover, collect or secure our claims arising prior to the EFH Petition Date. Following the EFH Petition Date, EFH Corp. received approval from the bankruptcy court to pay or otherwise honor certain prepetition obligations generally designed to stabilize its operations. Included in the approval were the obligations owed to us representing our prepetition electricity delivery fees. As of the EFH Petition Date, we estimated that our receivables from the Texas Holdings Group totaled approximately $129 million. Since that time, we have collected $127 million of the prepetition amount. We estimate any potential pre-tax loss resulting from the EFH Bankruptcy Proceedings to be immaterial. A provision for uncollectible accounts from affiliates had not been established as of June 30, 2015. Potential Change in Control of Majority Owner or Other Change in Ownership of Oncor In January 2015, the bankruptcy court approved the debtors' bidding procedures motion that set forth the process by which the debtors were authorized to solicit proposals (i.e., bids) from third parties to acquire (in any form and employing any structure, whether taxable (in whole or in part) or tax-free) an indirect equity ownership interest in Oncor in accordance with the US Bankruptcy Code. These bidding procedures contemplated that the debtors select a stalking horse bid after a two-stage closed bidding process, and, after approval by the bankruptcy court of such stalking horse bid, the debtors conduct a round of open bidding culminating in an auction intended to obtain a higher or otherwise best bid for a transaction. Initial bids were received in early March 2015 and second round bids were received in April 2015. Following receipt and negotiation of second round bids, the debtors in the EFH Bankruptcy Proceedings elected not to select a stalking horse bid. As part of the EFH Bankruptcy Proceedings, on July 23, 2015, EFH Corp. and the other debtors filed with the bankruptcy court an amended joint plan of reorganization (as such may be amended from time to time, Plan of Reorganization) and related amended disclosure statement (as such may be amended from time to time, Disclosure Statement). In general, the Plan of Reorganization proposes a structure that involves a tax-free deconsolidation of TCEH from EFH Corp. and the reorganization of EFH Corp. and EFIH either: (1) pursuant to a plan of reorganization backstopped by existing creditors and third party investors or (2) a standalone plan of reorganization pursuant to which the creditors of EFH Corp. and EFIH would convert their debt into equity of reorganized EFH Corp.. In this regard, the Plan of Reorganization provides for a series of transactions that likely would lead to a significant change in the indirect equity ownership of Oncor. We cannot predict the outcome of the EFH Bankruptcy Proceedings and the related stakeholder negotiations, including whether the bankruptcy court will approve any of the structures contemplated by the Plan of Reorganization and related transactions or whether any such transactions will (or when they will) ultimately close because any such transactions would be the subject of customary closing conditions, including receipt of all applicable regulatory approvals and the requirements of the US Bankruptcy Code or the bankruptcy court. The EFH Bankruptcy Proceedings are a complex litigation matter and the full extent of potential impacts on Oncor at this time is unknown. The Plan of Reorganization and the Disclosure Statement are subject to revision in response to creditor claims and objections, the ultimate outcome of stakeholder negotiations and the requirements of the US Bankruptcy Code or the bankruptcy court. Bankruptcy courts have broad equitable powers, and as a result, outcomes in bankruptcy proceedings are inherently difficult to predict. As indicated above, the Plan of Reorganization contemplates potential transactions that would result in a change in control of Oncor or otherwise implicate a regulatory review. We have made some preliminary preparations for potential change in control filings, including discussions with EFH Corp. and others, in light of the proposals in the EFH Bankruptcy Proceedings and the filing of the Plan of Reorganization and Disclosure Statement, but cannot predict the result of any transaction or review. In addition, we will continue to evaluate our affiliate transactions and contingencies throughout the EFH Bankruptcy Proceedings to determine any risks and resulting impacts on our results of operations, financial statements and cash flows. See Note 10 for details of our related-party transactions with members of the Texas Holdings Group.	2. E FH BANKRUPTCY PROCEEDINGS On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. The Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. We believe the “ring-fencing” measures discussed above mitigate our potential exposure to the EFH Bankruptcy Proceedings. See Note 1 and below for further information regarding the EFH Bankruptcy Proceedings and the proposed change in control of Oncor’s indirect majority owner in connection with such proceedings. The US Bankruptcy Code automatically enjoined, or stayed, us from judicial or administrative proceedings or filing of other actions against our affiliates or their property to recover, collect or secure our claims arising prior to the EFH Petition Date. Following the EFH Petition Date, EFH Corp. received approval from the bankruptcy court to pay or otherwise honor certain prepetition obligations generally designed to stabilize its operations. Included in the approval were the obligations owed to us representing our prepetition electricity delivery fees. As of the EFH Petition Date, we estimated that our receivables from the Texas Holdings Group totaled approximately $ 129 million. Since that time, we have collected $ 127 million of the prepetition amount. We estimate any potential pre-tax loss resulting from the EFH Bankruptcy Proceedings to be immaterial. As such, a provision for uncollectible accounts from affiliates had not been established as of December 31, 2014. Proposed Change in Control of Majority Owner In September 2014, with input and support from several key EFH Corp. stakeholders, the debtors in the EFH Bankruptcy Proceedings filed a motion with the bankruptcy court seeking the entry of an order approving bidding procedures that would result in a change in control of Oncor’s indirect majority owner . During October 2014, the bankruptcy court held hearings regarding the motion. In November 2014, the bankruptcy court conditionally approved the motion. In January 2015, the bankruptcy court approved the debtors' bidding procedures motion that sets forth the process by which the debtors are authorized to solicit proposals (i.e., bids) from third parties to acquire (in any form and employing any structure, whether taxable (in whole or in part) or tax-free) an indirect equity ownership interest in Oncor in accordance with the Bankruptcy Code. These bidding procedures contemplate that the debtors select a stalking horse bid after a two-stage closed bidding process, and, after approval by the bankruptcy court of such stalking horse bid, the debtors conduct a round of open bidding culminating in an auction intended to obtain a higher or otherwise best bid for a transaction. Initial bids are due no later than March 2, 2015. We cannot predict the outcome of this process, including whether the debtors will receive any acceptable bid or whether the bankruptcy court will approve any such bid or whether any such transaction will (or when it will) ultimately close because any such transaction would be the subject of customary closing conditions, including receipt of all applicable regulatory approvals. The EFH Bankruptcy Proceedings are a complex litigation matter and the full extent of potential exposure at this time is unknown. Bankruptcy courts have broad equitable powers, and as a result, outcomes in bankruptcy proceedings are inherently difficult to predict. We will continue to evaluate our affiliate transactions and contingencies throughout the EFH Bankruptcy Proceedings to determine any risks and resulting impacts on our financial statements. EFH Corp. has been exploring various options regarding potential transactions that could be deemed to implicate a regulatory review. We have made some preliminary preparations for potential change in control filings, including discussions with EFH Corp. and others, in light of the proposals in the EFH Bankruptcy Proceedings, but cannot predict the result of any transaction or review. See Note 12 for details of our related-party transactions with members of the Texas Holdings Group.

Regulatory Matters

Regulatory Matters	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Regulatory Matters [Abstract]
REGULATORY MATTERS	3. REGULATORY MATTERS 2008 Rate Review In August 2009, the PUCT issued a final order with respect to our June 2008 rate review filing with the PUCT and 204 cities based on a test year ended December 31, 2007 (Docket 35717), and new rates were implemented in September 2009. We and four other parties appealed various portions of the rate review final order to a state district court. In January 2011, the district court signed its judgment reversing the PUCT with respect to two issues: the PUCT’s disallowance of certain franchise fees and the PUCT’s decision that PURA no longer requires imposition of a rate discount for state colleges and universities. We filed an appeal with the Texas Third Court of Appeals (Austin Court of Appeals) in February 2011 with respect to the issues we appealed to the district court and did not prevail upon, as well as the district court’s decision to reverse the PUCT with respect to discounts for state colleges and universities. In early August 2014, the Austin Court of Appeals reversed the district court and affirmed the PUCT with respect to the PUCT’s disallowance of certain franchise fees and the PUCT’s decision that PURA no longer requires imposition of a rate discount for state colleges and universities. The Austin Court of Appeals also reversed the PUCT and district court’s rejection of a proposed consolidated tax savings adjustment arising out of EFH Corp.’s ability to offset our taxable income against losses from other investments and remanded the issue to the PUCT to determine the amount of the consolidated tax savings adjustment. In late August 2014, we filed a motion on rehearing with the Austin Court of Appeals with respect to certain appeal issues on which we were not successful, including the consolidated tax savings adjustment. In December 2014, the Austin Court of Appeals issued its opinion, clarifying that it was rendering judgment on the rate discount for state colleges and universities issue (affirming that PURA no longer requires imposition of the rate discount) rather than remanding it to the PUCT, and dismissing the motions for rehearing regarding the franchise fee issue and the consolidated tax savings adjustment. We filed a petition for review with the Texas Supreme Court in February 2015. At the request of the court, the parties filed responses to the petitions for review in June 2015. We filed a reply brief on July 30, 2015, the deadline for all parties to file replies. There is no deadline for the court to act. If our appeals efforts are unsuccessful and the proposed consolidated tax savings adjustment is implemented, we estimate that on remand, the impact on earnings of the consolidated tax savings adjustment’s value could range from zero , as originally determined by the PUCT in Docket 35717, to an approximate $130 million loss (after tax). We do not believe that any of the other issues ruled upon by the Austin Court of Appeals would result in a material impact to our results of operations or financial condition. See Note 3 to Financial Statements in our 2014 Form 10-K for additional information regarding regulatory matters.	3. REGULATORY MATTERS 2008 Rate Review In August 2009, the PUCT issued a final order with respect to our June 2008 rate review filing with the PUCT and 204 cities based on a test year ended December 31, 2007 (Docket 35717), and new rates were implemented in September 2009. We and four other parties appealed various portions of the rate review final order to a state district court. In January 2011, the district court signed its judgment reversing the PUCT with respect to two issues: the PUCT’s disallowance of certain franchise fees and the PUCT’s decision that PURA no longer requires imposition of a rate discount for state colleges and universities. We filed an appeal with the Texas Third Court of Appeals (Austin Court of Appeals) in February 2011 with respect to the issues we appealed to the district court and did not prevail upon, as well as the district court’s decision to reverse the PUCT with respect to discounts for state colleges and universities. In early August 2014, the Austin Court of Appeals reversed the district court and affirmed the PUCT with respect to the PUCT’s disallowance of certain franchise fees and the PUCT’s decision that PURA no longer requires imposition of a rate discount for state colleges and universities. The Austin Court of Appeals also reversed the PUCT and district court’s rejection of a proposed consolidated tax savings adjustment arising out of EFH Corp.’s ability to offset our taxable income against losses from other investments and remanded the issue to the PUCT to determine the amount of the consolidated tax savings adjustment. In late August 2014, we filed a motion on rehearing with the Austin Court of Appeals with respect to certain appeal issues on which we were not successful, including the consolidated tax savings adjustment. In December 2014, the Austin Court of Appeals issued its Opinion on Rehearing, clarifying that it was rendering judgment on the rate discount for state colleges and universities issue (affirming that PURA no longer requires imposition of the rate discount) rather than remanding it to the PUCT, and dismissing the motions for rehearing regarding the franchise fee issue and the consolidated tax savings adjustment. We filed a petition for review with the Texas Supreme Court on February 19, 2015. If our appeals efforts are unsuccessful and the proposed consolidated tax savings adjustment is implemented, we estimate that on remand, the impact on earnings of the consolidated tax savings adjustment’s value could range from zero , as originally determined by the PUCT in Docket 35717, to a $ 130 million loss (after tax). We do not believe that any of the other issues ruled upon by the Austin Court of Appeals would result in a material impact to our results of operations or financial condition. We are involved in various other regulatory proceedings in the normal course of business, the ultimate resolution of which, in the opinion of management, should not have a material effect upon our financial position, results of operations or cash flows.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
INCOME TAXES	4. INCOME TAXES The components of our reported provision (benefit) in lieu of income taxes are as follows: Year Ended December 31, 2014 2013 2012 Reported in operating expenses: Current: US federal $ $ $ State Deferred: US federal State - - Amortization of investment tax credits Total reported in operating expenses Reported in other income and deductions: Current: US federal State - - - Deferred federal Total reported in other income and deductions Total provision in lieu of income taxes $ $ $ Reconciliation of provision in lieu of income taxes computed at the US federal statutory rate to provision in lieu of income taxes: Year Ended December 31, 2014 2013 2012 Income before provision in lieu of income taxes $ $ $ Provision in lieu of income taxes at the US federal statutory rate of 35% $ $ $ Amortization of investment tax credits – net of deferred tax effect Amortization (under regulatory accounting) of statutory tax rate changes Amortization of Medicare subsidy regulatory asset Texas margin tax, net of federal tax benefit Nondeductible losses (gains) on benefit plan investments Other, including audit settlements - Reported provision in lieu of income taxes $ $ $ Effective rate The net amounts of $ 2.5 59 billion and $2.414 billion reported in the balance sheets at December 31, 2014 and 2013, respectively, as liability in lieu of deferred income taxes include amounts previously recorded as net deferred tax liabilities. Upon the sale of equity interests to Texas Transmission and Investment LLC in 2008, we became a partnership for US federal income tax purposes, and the temporary differences that gave rise to the deferred taxes will, over time, become taxable to the equity holders. Under a tax sharing agreement among us and our equity holders (see Note 1), we make payments to the equity holders for income taxes as the partnership earnings become taxable to the equity holders. Accordingly, as the temporary differences become taxable, we will pay the equity holders. In the unlikely event such amounts are not paid under the tax sharing agreement, it is probable that they would be reimbursed to rate payers. Accounting For Uncertainty in Income Taxes Prior to November 2008, we were a member of the EFH Corp. consolidated tax group. The examination process of EFH Corp. and its subsidiaries’ federal income tax returns for the years ending prior to January 1, 2008 are complete, but the tax years 2003 through 2006 remain in appeals with the IRS. Texas franchise and margin tax returns are under examination or still open for examination for tax years beginning after 2006. Subsequent to November 2008, we are not a member of the EFH Corp. consolidated federal tax group and assess our liability for uncertain tax positions in our partnership returns. We have been advised by EFH Corp. that approval by the Joint Committee on Taxation for the 1997 through 2002 IRS appeals settlement was received in May 2013 and that all issues contested have been resolved. As a result, the liability for uncertain tax positions was reduced by $32 million in the second quarter of 2013. This resolution also resulted in a $10 million net reduction to liability in lieu of deferred income taxes and a reversal of accrued interest and tax totaling $5 million ($ 3 million after tax), which is reported as a decrease in provision in lieu of income taxes. We made a cash payment of $33 million to EFH Corp. in the third quarter of 2013, as required under the tax sharing agreement, to settle the liability resulting from the 1997 through 2002 IRS audit, and received a $10 million refund from EFH Corp. as a result of filing amended Texas franchise tax returns for 1997 through 2001. The IRS audit for the years 2003 through 2006 was concluded in June 2011. A significant number of adjustments to the originally filed returns for such years were proposed. In March 2013, EFH Corp. and the IRS agreed on terms to resolve the disputed adjustments. In the first quarter of 2013, we reduced the liability for uncertain tax positions by $76 million to reflect the terms of the agreement. This reduction consisted of a $58 million increase to liability in lieu of deferred income taxes and a reversal of accrued interest and tax totaling $18 million ($ 12 million after tax), which is reported as a decrease in provision in lieu of income taxes. In the fourth quarter of 2013, the 2003 through 2006 state tax positions were remeasured, which resulted in a net reversal of accrued interest and tax totaling $3 million. The cash income tax impact related to the conclusion of the 2003 through 2006 audit is a refund from our members of approximately $9 million that is recorded in liability in lieu of deferred income taxes . In the first quarter of 2014, several uncertain tax positions were remeasured under US GAAP guidance as a result of new information received from the IRS with respect to the audit of tax years 2007 through 2009. As a result, we reduced the liability for uncertain tax positions by $ 18 million. This reduction consisted of a $16 million increase in liability in lieu of deferred income taxes and a $2 million ($ 1 million after tax) reversal of accrued interest, which is reported as a decrease in provision in lieu of income taxes. In September 2014, EFH Corp. signed the final agreed Revenue Agent Report and associated documentation (RAR) for the 2007 tax year and filed a motion seeking approval of the bankruptcy court in the EFH Bankruptcy Proceedings of its signing of the RAR. With the signing of the RAR in the third quarter of 2014, the remaining $1 million liability for uncertain tax positions with respect to tax year 2007 was released. The reduction consisted of a $1 million reversal of provision in lieu of income taxes. Final processing of the agreed RAR continues. The cash income tax impact related to the conclusion of the 200 7 audit is a refund from our members of approximately $44 million that is recorded in liability in lieu of deferred income taxes . In the fourth quarter of 2014, the Department of Justice filed a claim with the bankruptcy court for open tax years through 2013 that was consistent with the settlement EFH Corp. reached with the IRS for tax years 2003 through 2006. As a result of this filing, the 2003 through 2006 open tax years for GAAP purposes were settled and the liability for uncertain tax positions was reduced by $35 million. This reduction consisted of a $33 million increase in liability in lieu of deferred income taxes and a $2 million reduction in provision in lieu of income taxes. The following table summarizes the changes to the uncertain tax positions reported in other noncurrent liabilities in our consolidated balance sheet during the years ended December 31, 2014, 2013 and 2012: 2014 2013 2012 Balance at January 1, excluding interest and penalties $ $ $ Additions based on tax positions related to prior years - - Reductions based on tax positions related to prior years - Settlements with taxing authorities - Balance at December 31, excluding interest and penalties $ $ $ Of the balances at December 31, 2014 and 201 3 , $3 million and $51 million, respectively, represent tax positions for which the uncertainty relates to the timing of recognition for tax purposes. The disallowance of such positions would not affect the effective tax rate, but would accelerate the payment of cash under the tax sharing agreement to an earlier period. With respect to tax positions for which the ultimate deductibility is uncertain (permanent items), should EFH Corp. or we sustain such positions on income tax returns previously filed, our liabilities recorded would increase by $1 million resulting in de creased net income and a n un favorable impact on the effective tax rate . Noncurrent liabilities included no accrued interest related to uncertain tax positions at December 31, 2014 and a total of $2 million in accrued interest related to uncertain tax positions at December 31, 201 3 . Amounts recorded related to interest and penalties totaled benefit s of $1 million and $15 million in the year s ended December 31, 2014 and 2013 , respectively, and an expense of $3 million in the year ended December 31, 2012 (all amounts after tax). The federal income tax benefit on the interest accrued on uncertain tax positions is recorded as liability in lieu of deferred income taxes.

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Regulatory Assets and Liabilities [Abstract]
REGULATORY ASSETS AND LIABILITIES	4. REGULATORY ASSETS AND LIABILITIES Recognition of regulatory assets and liabilities and the amortization periods over which they are expected to be recovered or refunded through rate regulation reflect the decisions of the PUCT. Components of the regulatory assets and liabilities are provided in the table below. Amounts not earning a return through rate regulation are noted. Remaining Rate Recovery/Amortization Period at Carrying Amount At June 30, 2015 June 30, 2015 December 31, 2014 Regulatory assets: Generation-related regulatory assets securitized by transition bonds (a)(e) 1 year $ $ Employee retirement costs 5 years Employee retirement costs to be reviewed (b)(c) To be determined Employee retirement liability (a)(c)(d) To be determined Self-insurance reserve (primarily storm recovery costs) ― net 5 years Self-insurance reserve to be reviewed ― net (b)(c) To be determined Securities reacquisition costs (pre-industry restructure) 2 years Securities reacquisition costs (post-industry restructure) ― net Terms of related debt Recoverable amounts in lieu of deferred income taxes ― net Life of related asset or liability Deferred conventional meter and metering facilities depreciation Largely 5 years Deferred AMS costs To be determined Energy efficiency performance bonus (a) 1 year Under-recovered wholesale transmission service expense ― net (a) 1 year Other regulatory assets Various Total regulatory assets Regulatory liabilities: Estimated net removal costs Life of utility plant Investment tax credit and protected excess deferred taxes Various Over-collection of transition bond revenues (a)(e) 1 year Energy efficiency programs (a) Not applicable Total regulatory liabilities Net regulatory asset $ $ ____________ (a) Not earning a return in the regulatory rate-setting process. (b) Costs incurred since the period covered under the last rate review. (c) Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review. (d) Represents unfunded liabilities recorded in accordance with pension and OPEB accounting standards. (e) Bondco net regulatory assets of $47 million at June 30, 2015 consisted of $78 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $31 million. Bondco net regulatory assets of $108 million at December 31, 2014 consisted of $140 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $32 million.	5. REGULATORY ASSETS AND LIABILITIES Recognition of regulatory assets and liabilities and the amortization periods over which they are expected to be recovered or refunded through rate regulation reflect the decisions of the PUCT. Components of our regulatory assets and liabilities are provided in the table below. Amounts not earning a return through rate regulation are noted. Remaining Rate Recovery/Amortization Period at Carrying Amount At December 31, 2014 December 31, 2014 December 31, 2013 Regulatory assets: Generation-related regulatory assets securitized by transition bonds (a)(e) 1 year $ $ Employee retirement costs 5 years Employee retirement costs to be reviewed (b)(c) To be determined Employee retirement liability (a)(c)(d) To be determined Self-insurance reserve (primarily storm recovery costs) ― net 5 years Self-insurance reserve to be reviewed ― net (b)(c) To be determined Securities reacquisition costs (pre-industry restructure) 2 years Securities reacquisition costs (post-industry restructure) ― net Lives of related debt Recoverable amounts in lieu of deferred income taxes ― net Life of related asset or liability Deferred conventional meter and metering facilities depreciation Largely 6 years Deferred AMS costs To be determined Energy efficiency performance bonus (a) 1 year Under-recovered wholesale transmission service expense ― net (a) 1 year Other regulatory assets Various Total regulatory assets Regulatory liabilities: Estimated net removal costs Lives of related assets Investment tax credit and protected excess deferred taxes Various Over-collection of transition bond revenues (a)(e) 1 year Energy efficiency programs (a) Not applicable Total regulatory liabilities Net regulatory asset $ $ ____________ (a) Not earning a return in the regulatory rate-setting process. (b) Costs incurred since the period covered under the last rate review. (c) Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review. (d) Represents unfunded liabilities recorded in accordance with pension and OPEB accounting standards. (e) Bondco net regulatory assets of $ 108 million at December 31, 2014 consisted of $ 140 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $ 32 million. Bondco net regulatory assets of $ 226 million at December 31, 2013 consisted of $ 261 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $ 35 million. In August 2011, the PUCT issued a final order in our rate review filed in January 2011. The rate review included a determination of the recoverability of regulatory assets at June 30, 2010, including the recoverability period of those assets deemed allowable by the PUCT. In accordance with the PUCT’s August 2009 order in our rate review, the remaining net book value and the approved amount of removal cost of existing conventional meters that were replaced by advanced meters are being charged to depreciation and amortization expense over an 11-year cost recovery period. In September 2008, the PUCT approved a settlement for us to recover our estimated future investment for advanced metering deployment. We began billing the AMS surcharge in the January 2009 billing month cycle. The surcharge is expected to total $ 1.023 billion over the 11 -year recovery period and includes a cost recovery factor of $2.19 per month per residential retail customer and $2.39 to $5.15 per month for non-residential retail customers. We account for the difference between the surcharge billings for advanced metering facilities and the allowable revenues under the surcharge provisions, which are based on expenditures and an allowed return, as a regulatory asset or liability. Such differences arise principally as a result of timing of expenditures. As indicated in the table above, the regulatory asset at December 31, 2014 and 2013 totaled $113 million and $62 million, respectively. As a result of purchase accounting, in 2007 the carrying value of certain generation-related regulatory assets securitized by transition bonds, which have been reviewed and approved by the PUCT for recovery but without earning a rate of return, was reduced by $ 213 million. This amount is being accreted to other income over the recovery period that was remaining at October 10, 2007 (approximately nine years). See Note 12 for information regarding nuclear decommissioning cost recovery.

Borrowings Under Credit Facilit

Borrowings Under Credit Facilities	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Long-Term Debt [Abstract]
BORROWINGS UNDER CREDIT FACILITIES	5. BORROWINGS UNDER CREDIT FACILITIES At June 30, 2015, we had a $2.4 billion secured revolving credit facility to be used for working capital and general corporate purposes, issuances of letters of credit and support for any commercial paper issuances. The revolving credit facility expires in October 2016. We have the option of requesting up to two one -year extensions, with such extensions subject to certain conditions and lender approval. The terms of the revolving credit facility allow us to request an additional increase in our borrowing capacity of $100 million, provided certain conditions are met, including lender approval. Borrowings under the revolving credit facility are classified as short-term on the balance sheet and are secured equally and ratably with all of our other secured indebtedness by a first priority lien on property we acquired or constructed for the transmission and distribution of electricity. The property is mortgaged under the Deed of Trust. At June 30, 2015, we had outstanding borrowings under the revolving credit facility totaling $780 million with an interest rate of 1.31% and outstanding letters of credit totaling $7 million. At December 31, 2014, we had outstanding borrowings under the revolving credit facility totaling $711 million with an interest rate of 1.29% and outstanding letters of credit totaling $7 million. Borrowings under the revolving credit facility bear interest at per annum rates equal to, at our option, (i) LIBOR plus a spread ranging from 1.00% to 1.75% depending on credit ratings assigned to our senior secured non-credit enhanced long-term debt or (ii) an alternate base rate (the highest of (1) the prime rate of JPMorgan Chase, (2) the federal funds effective rate plus 0.50% , and (3) daily one-month LIBOR plus 1.00% ) plus a spread ranging from 0.00% to 0.75% depending on credit ratings assigned to our senior secured non-credit enhanced long-term debt. At June 30, 2015, all outstanding borrowings bore interest at LIBOR plus 1.125% . Amounts borrowed under the revolving credit facility, once repaid, can be borrowed again from time to time. An unused commitment fee is payable quarterly in arrears and upon termination or commitment reduction at a rate equal to 0.100% to 0.275% (such spread depending on certain credit ratings assigned to our senior secured debt) of the daily unused commitments under the revolving credit facility. Letter of credit fees on the stated amount of letters of credit issued under the revolving credit facility are payable to the lenders quarterly in arrears and upon termination at a rate per annum equal to the spread over adjusted LIBOR. Customary fronting and administrative fees are also payable to letter of credit fronting banks. At June 30, 2015, letters of credit bore interest at 1.325% , and a commitment fee (at a rate of 0.125% per annum) was payable on the unfunded commitments under the revolving credit facility, each based on our current credit ratings. Subject to the limitations described below, borrowing capacity available under the revolving credit facility at June 30, 2015 and December 31, 2014 was $1.613 billion and $1.682 billion, respectively. Generally, our indentures and revolving credit facility limit the incurrence of other secured indebtedness except for indebtedness secured equally and ratably with the indentures and revolving credit facility and certain permitted exceptions. As described further in Note 6, the Deed of Trust permits us to secure indebtedness (including borrowings under our revolving credit facility) with the lien of the Deed of Trust. At June 30, 2015, the available borrowing capacity of the revolving credit facility could be fully drawn. The revolving credit facility contains customary covenants for facilities of this type, restricting, subject to certain exceptions, us and our subsidiaries from, among other things: incurring additional liens; entering into mergers and consolidations; and sales of substantial assets. In addition, the revolving credit facility requires that we maintain a consolidated senior debt-to-capitalization ratio of no greater than 0.65 to 1.00 and observe certain customary reporting requirements and other affirmative covenants. For purposes of the ratio, debt is calculated as indebtedness defined in the revolving credit facility (principally, the sum of long-term debt, any capital leases, short-term debt and debt due currently in accordance with US GAAP). The debt calculation excludes transition bonds issued by Bondco, but includes the unamortized fair value discount related to Bondco. Capitalization is calculated as membership interests determined in accordance with US GAAP plus indebtedness described above. At June 30, 2015, we were in compliance with this covenant and with all other covenants .	6. BORROWINGS UNDER CREDIT FACILITIES At December 31, 201 4 , we had a $ 2.4 billion secured revolving credit facility to be used for working capital and general corporate purposes, issuances of letters of credit and support for any commercial paper issuances. The revolving credit facility expires in October 2016, and we have the option of requesting up to two one -year extensions, with such extensions subject to certain conditions and lender approval. The terms of the revolving credit facility allow us to request an additional increase in our borrowing capacity of $ 100 million, provided certain conditions are met, including lender approval. Borrowings under the revolving credit facility are classified as short-term on the balance sheet and are secured equally and ratably with all of our other secured indebtedness by a first priority lien on property we acquired or constructed for the transmission and distribution of electricity. The property is mortgaged under the Deed of Trust. At December 31, 2014, we had outstanding borrowings under the revolving credit facility totaling $ 711 million with an interest rate of 1.29 % and outstanding letters of credit totaling $ 7 million. At December 31, 2013, we had outstanding borrowings under the revolving credit facility totaling $ 745 million with an interest rate of 1.67 % and outstanding letters of credit totaling $ 6 million. Borrowings under the revolving credit facility bear interest at per annum rates equal to, at our option, (i) LIBOR plus a spread ranging from 1.00 % to 1.75 % depending on credit ratings assigned to our senior secured non-credit enhanced long-term debt or (ii) an alternate base rate (the highest of (1) the prime rate of JPMorgan Chase, (2) the federal funds effective rate plus 0.50 %, and (3) daily one-month LIBOR plus 1.00 %) plus a spread ranging from 0.00 % to 0.75 % depending on credit ratings assigned to our senior secured non-credit enhanced long-term debt. At December 31, 2014, all outstanding borrowings bore interest at LIBOR plus 1.125 %. Amounts borrowed under the facility, once repaid, can be borrowed again from time to time. An unused commitment fee is payable quarterly in arrears and upon termination or commitment reduction at a rate equal to 0.100 % to 0.275 % (such spread depending on certain credit ratings assigned to our senior secured debt) of the daily unused commitments under the revolving credit facility. Letter of credit fees on the stated amount of letters of credit issued under the revolving credit facility are payable to the lenders quarterly in arrears and upon termination at a rate per annum equal to the spread over adjusted LIBOR. Customary fronting and administrative fees are also payable to letter of credit fronting banks. At December 31, 2014, letters of credit bore interest at 1.325 %, and a commitment fee (at a rate of 0.125 % per annum) was payable on the unfunded commitments under the facility, each based on our current credit ratings. Subject to the limitations described below, borrowing capacity available under the credit facility at December 31, 2014 and 2013 was $ 1.682 billion and $ 1.649 billion, respectively. Generally, our indentures and revolving credit facility limit the incurrence of other secured indebtedness except for indebtedness secured equally and ratably with the indentures and revolving credit facility and certain permitted exceptions . As described further in Note 7 , the Deed of Trust permits us to secure indebtedness (including borrowings under our revolving credit facility) with the lien of the Deed of Trust . At December 31, 2014, the available borrowing capacity of the revolving credit facility could be fully drawn. The revolving credit facility contains customary covenants for facilities of this type, restricting, subject to certain exceptions, us and our subsidiaries from, among other things: incurring additional liens; entering into mergers and consolidations; and sales of substantial assets. In addition, the revolving credit facility requires that we maintain a consolidated senior debt-to-capitalization ratio of no greater than 0.65 to 1.00 and observe certain customary reporting requirements and other affirmative covenants. For purposes of the ratio, debt is calculated as indebtedness defined in the revolving credit facility (principally, the sum of long-term debt, any capital leases, short-term debt and debt due currently in accordance with US GAAP). The debt calculation excludes transition bonds issued by Bondco, but includes the unamortized fair value discount related to Bondco. Capitalization is calculated as membership interests determined in accordance with US GAAP plus indebtedness described above. At December 31, 2014, we were in compliance with this covenant with a debt-to-capitalization ratio of 0.45 to 1.00 and with all other covenants .

Long-Term Debt

Long-Term Debt	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Long-Term Debt [Abstract]
LONG-TERM DEBT	6. LONG-TERM DEBT At June 30, 2015 and December 31, 2014, our long-term debt consisted of the following: June 30, December 31, 2015 2014 Oncor (a): 6.375% Fixed Senior Notes due January 15, 2015 $ - $ 5.000% Fixed Senior Notes due September 30, 2017 6.800% Fixed Senior Notes due September 1, 2018 2.150% Fixed Senior Notes due June 1, 2019 5.750% Fixed Senior Notes due September 30, 2020 4.100% Fixed Senior Notes due June 1, 2022 7.000% Fixed Debentures due September 1, 2022 2.950% Fixed Senior Notes due April 1, 2025 - 7.000% Fixed Senior Notes due May 1, 2032 7.250% Fixed Senior Notes due January 15, 2033 7.500% Fixed Senior Notes due September 1, 2038 5.250% Fixed Senior Notes due September 30, 2040 4.550% Fixed Senior Notes due December 1, 2041 5.300% Fixed Senior Notes due June 1, 2042 3.750% Fixed Senior Notes due April 1, 2045 - Unamortized discount Less amount due currently - Long-term debt, less amounts due currently — Oncor Bondco (b): 5.420% Fixed Series 2003 Bonds due in semiannual installments through August 15, 2015 5.290% Fixed Series 2004 Bonds due in semiannual installments through May 15, 2016 Less amount due currently Long-term debt, less amounts due currently — Bondco - Total long-term debt, less amounts due currently $ $ __________ (a) Secured by first priority lien on certain transmission and distribution assets equally and ratably with all of Oncor’s other secured indebtedness. See “Deed of Trust” below for additional information. (b) The transition bonds are nonrecourse to Oncor and were issued to securitize a regulatory asset. Debt-Related Activity in 2015 Debt Repayments Rep ayments of long-term debt in the six months ended June 30, 2015 totaled $569 million representing $500 million aggregate principal amount of 6.375% senior secured notes paid at the scheduled maturity date of January 15, 2015 and $69 million representing transition bond principal payments at scheduled maturity dates. Issuance of New Senior Secured Notes In March 2015 , we issued $350 million aggregate principal amount of 2.950% senior secured notes maturing in April 2025 (2025 Notes) and $375 million aggregate principal amount of 3.750% senior secured notes maturing in April 2045 (2045 Notes, and together with the 2025 Notes, the Notes). We used the proceeds (net of the initial purchasers’ discount, fees and expenses) of approximately $714 million from the sale of the Notes to repay borrowings under our revolving credit facility and for other general corporate purposes. The Notes are secured by a first priority lien , and are secured equally and ratably with all of our other secured indebtedness. Interest on the Notes is payable in cash semiannually in arrears on April 1 and October 1 of each year, beginning on October 1, 2015. Prior to January 1, 2025, in the case of the 2025 Notes, and October 1, 2044, in the case of the 2045 Notes, we may at our option at any time redeem all or part of the Notes at a price equal to 100% of their principal amount, plus accrued and unpaid interest and a make-whole premium. On and after January 1, 2025, in the case of the 2025 Notes, and October 1, 2044, in the case of the 2045 Notes, Oncor may redeem the Notes at any time, in whole or in part, at a redemption price equal to 100% of the principal amount of such Notes, plus accrued and unpaid interest. The Notes also contain customary events of default, including failure to pay principal or interest on the Notes when due. The Notes were issued in a private placement and were not registered under the Securities Act. We have agreed, subject to certain exceptions, to register with the SEC notes having substantially identical terms as the Notes (except for provisions relating to the transfer restriction and payment of additional interest) as part of an offer to exchange freely tradable exchange notes for the Notes. We have agreed to use commercially reasonable efforts to cause the exchange offer to be completed within 315 days after the issue date of the Notes. If a registration statement for the exchange offer is not declared effective by the SEC within 270 days after the issue date of the Notes or the exchange offer is not completed within 315 days after the issue date of the Notes (an exchange default), then the annual interest rate on the Notes will increase 50 basis points per annum until the earlier of the expiration of the exchange default or the second anniversary of the issue date of the Notes. Deed of Trust Our secured indebtedness, including the revolving credit facility described in Note 5, is secured equally and ratably by a first priority lien on property we acquired or constructed for the transmission and distribution of electricity. The property is mortgaged under the Deed of Trust. The Deed of Trust permits us to secure indebtedness (including borrowings under our revolving credit facility) with the lien of the Deed of Trust up to the aggregate of (i) the amount of available bond credits, and (ii) 85% of the lower of the fair value or cost of certain property additions that could be certified to the Deed of Trust collateral agent. At June 30, 2015, the amount of available bond credits was approximately $2.637 billion and the amount of future debt we could secure with property additions, subject to those property additions being certified to the Deed of Trust collateral agent, was $1.103 billion. Fair Value of Long-Term Debt At June 30, 2015 and December 31, 2014, the estimated fair value of our long-term debt (including current maturities) totaled $6.622 billion and $6.844 billion, respectively, and the carrying amount totaled $5.791 billion and $5.636 billion, respectively. The fair value is estimated by an independent party who uses observable market data, representing Level 2 valuations under accounting standards related to the determination of fair value.	7. LONG-TERM DEBT At December 31, 2014 and 2013, our long-term debt consisted of the following: December 31, 2014 2013 Oncor (a): 6.375% Fixed Senior Notes due January 15, 2015 $ $ 5.000% Fixed Senior Notes due September 30, 2017 6.800% Fixed Senior Notes due September 1, 2018 2.150% Fixed Senior Notes due June 1, 2019 - 5.750% Fixed Senior Notes due September 30, 2020 4.100% Fixed Senior Notes due June 1, 2022 7.000% Fixed Debentures due September 1, 2022 7.000% Fixed Senior Notes due May 1, 2032 7.250% Fixed Senior Notes due January 15, 2033 7.500% Fixed Senior Notes due September 1, 2038 5.250% Fixed Senior Notes due September 30, 2040 4.550% Fixed Senior Notes due December 1, 2041 5.300% Fixed Senior Notes due June 1, 2042 Unamortized discount Less amount due currently - Long-term debt, less amounts due currently — Oncor Bondco (b): 5.420% Fixed Series 2003 Bonds due in semiannual installments through August 15, 2015 5.290% Fixed Series 2004 Bonds due in semiannual installments through May 15, 2016 Unamortized fair value discount related to transition bonds - Less amount due currently Long-term debt, less amounts due currently — Bondco Total long-term debt, less amounts due currently $ $ __________ (a) Secured by first priority lien on certain transmission and distribution assets equally and ratably with all of Oncor’s other secured indebtedness. See “Deed of Trust” below for additional information. (b) The transition bonds are nonrecourse to Oncor and were issued to securitize a regulatory asset. Debt-Related Activity in 2014 Debt Repayments Rep ayments of long-term debt in 2014 totaled $ 131 million and represent transition bond principal payments at scheduled maturity dates. Issuance of New Senior Secured Notes In May 2014 , we issued $250 million aggregate principal amount of 2.150% senior secured notes maturing in June 2019 (2019 Notes). We used the proceeds (net of the initial purchasers’ discount, fees and expenses) of approximately $ 248 million from the sale of the 2019 Notes to repay borrowings under our revolving credit facility and for other general corporate purposes. The 2019 Notes are secured by a first priority lien , and are secured equally and ratably with all of our other secured indebtedness. Interest on the 2019 Notes is payable in cash semiannually in arrears on June 1 and December 1 of each year, beginning on December 1, 2014. We may at our option redeem the 2019 Notes, in whole or in part, at any time, at a price equal to 100 % of their principal amount, plus accrued and unpaid interest and , until May 1, 2019, a make-whole premium. The 2019 Notes also contain customary events of default, including failure to pay principal or interest on the 2019 Notes when due. The 2019 Notes were issued in a private placement . I n December 2014 we completed an offering with the holders of the 2019 Notes to exchange their respective 2019 Notes for notes that have terms identical in all material respects to the Notes (2019 Exchange Notes), except that the 2019 Exchange Notes do not contain terms with respect to transfer restrictions, registration rights and payment of additional interest for failure to observe certain obligations in a certain registration rights agreement. The 2019 Exchange Notes were registered on a Form S-4, which was declared effective in November 2014. Debt-Related Activity in 2013 Debt Repayments Rep ayments of long-term debt in 2013 totaled $125 million and represent transition bond principal payments at scheduled maturity dates. Issuance of New Senior Secured Notes In May 2013 , we completed the sale of $100 million aggregate principal amount of 4.550% senior secured notes maturing in December 2041 (Additional 2041 Notes). The Additional 2041 Notes were an additional issuance of our 4.550% senior secured notes maturing in December 2041, $300 million aggregate principal amount of which were previously issued in November 2011 (2041 Notes). The Additional 2041 Notes were issued as part of the same series as the 2041 Notes. We used the net proceeds of approximately $ 107 million from the sale of the Additional 2041 Notes to repay borrowings under our revolving credit facility and for general corporate purposes. The Additional 2041 Notes and 2041 Notes are secured by the first priority lien and are secured equally and ratably with all of our other secured indebtedness as discussed below . Interest on the Additional 2041 Notes is payable in cash semiannually in arrears on June 1 and December 1 of each year, beginning on June 1, 2013. We may at our option redeem the Additional 2041 Notes, in whole or in part, at any time, at a price equal to 100% of their principal amount, plus accrued and unpaid interest and , until June 1, 2041, a make-whole premium. The notes also contain customary events of default, including failure to pay principal or interest on the notes when due. The Additional 2041 Notes were issued in a private placement . I n July 2013 we completed an offering with the holders of the Additional 2041 Notes to exchange their respective Additional 2041 Notes for notes that have terms identical in all material respects to the Additional 2041 Notes (Exchange Notes), except that the Exchange Notes do not contain terms with respect to transfer restrictions, registration rights and payment of additional interest for failure to observe certain obligations in a certain registration rights agreement. The Exchange Notes were registered on a Form S-4, which was declared effective in June 2013. Deed of Trust Our secured indebtedness, including the revolving credit facility described in Note 6, is secured equally and ratably by a first priority lien on property we acquired or constructed for the transmission and distribution of electricity. The property is mortgaged under the Deed of Trust. The Deed of Trust permits us to secure indebtedness (including borrowings under our revolving credit facility) with the lien of the Deed of Trust up to the aggregate of (i) the amount of available bond credits, and (ii) 85 % of the lower of the fair value or cost of certain property additions that could be certified to the Deed of Trust collateral agent. At December 31, 2014, the amount of available bond credits was approximately $ 2.208 billion and the amount of future debt we could secure with property additions, subject to those property additions being certified to the Deed of Trust collateral agent, was $ 1.570 billion. Maturities Long-term debt maturities at December 31, 2014, are as follows: Year Amount 2015 $ 2016 2017 2018 2019 Thereafter Unamortized discount Total $ Fair Value of Long-Term Debt At December 31, 2014 and 2013, the estimated fair value of our long-term debt (including current maturities) totaled $ 6.844 billion and $ 6.188 billion, respectively, and the carrying amount totaled $ 5.636 billion and $ 5.512 billion, respectively. The fair value is estimated based upon the market value as determined by quoted market prices, representing Level 1 valuations under accounting standards related to the determination of fair value.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Commitments and Contingencies [Abstract]
COMMITMENTS AND CONTINGENCIES	7. COMMITMENTS AND CONTINGENCIES EFH Bankruptcy Proceedings On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. T he Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. See Notes 2 and 10 for a discussion of the potential impacts on us as a result of the EFH Bankruptcy Proceedings and our related-party transactions involving members of the Texas Holdings Group, respectively. Legal/Regulatory Proceedings We are involved in various legal and administrative proceedings in the normal course of business, the ultimate resolution of which, in the opinion of management, should not have a material effect upon our financial position, results of operations or cash flows. See Note 3 in this report and Note 8 to Financial Statements in our 2014 Form 10-K for additional information regarding our legal and regulatory proceedings.	8 . COMMITMENTS AND CONTINGENCIES EFH Bankruptcy Proceedings On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. T he Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. See Notes 2 and 12 for a discussion of the potential impacts on us as a result of the EFH Bankruptcy Proceedings and our related-party transactions involving members of the Texas Holdings Group, respectively. Leases At December 31, 201 4 , our future minimum lease payments under operating leases (with initial or remaining noncancelable lease terms in excess of one year) were as follows: Year Amount 2015 $ 2016 2017 2018 - 2019 - Thereafter - Total future minimum lease payments $ Rent charged to operation and maintenance expense totaled $9 million, $ 10 million and $ 15 million for the years ended December 31, 2014, 2013 and 2012, respectively. Efficiency Spending We are required to annually invest in programs designed to improve customer electricity demand efficiencies to satisfy ongoing regulatory requirements. The 2015 requirement is $ 50 million. Guarantees We are the lessee under various operating leases that obligate us to guarantee the residual values of the leased assets. At December 31, 2014, both the aggregate maximum amount of residual values guaranteed and the estimated residual recoveries totaled $ 6 million. These leased assets consist primarily of vehicles used in distribution activities. The average life of the residual value guarantees under the lease portfolio is approximately 2.5 years. Legal/Regulatory Proceedings We are involved in various legal and administrative proceedings in the normal course of business, the ultimate resolution of which, in the opinion of management, should not have a material effect upon our financial position, results of operations or cash flows. See Note 3 for additional information regarding contingencies. Labor Contracts At December 31, 2014, approximately 19% of our full time employees were represented by a labor union and covered by a collective bargaining agreement with an expiration date of October 25, 2015. Environmental Contingencies We must comply with environmental laws and regulations applicable to the handling and disposal of hazardous waste. We are in compliance with all current laws and regulations; however, the impact, if any, of changes to existing regulations or the implementation of new regulations is not determinable. The costs to comply with environmental regulations can be significantly affected by the following external events or conditions: · changes to existing state or federal regulation by governmental authorities having jurisdiction over control of toxic substances and hazardous and solid wastes, and other environmental matters, and · the identification of additional sites requiring clean-up or the filing of other complaints in which we may be asserted to be a potential responsible party.

Membership Interests

Membership Interests	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Membership Interests [Abstract]
MEMBERSHIP INTERESTS	8. MEMBERSHIP INTERESTS Cash Distributions Distributions are limited by our required regulatory capital structure to be at or below the assumed debt-to-equity ratio established by the PUCT for ratemaking purposes, which is currently set at 60% debt to 40% equity. At June 30, 2015, $68 million was available for distribution to our members as our regulatory capitalization ratio was 59.6% debt and 40.4% equity. The PUCT has the authority to determine what types of debt and equity are included in a utility’s debt-to-equity ratio. For purposes of this ratio, debt is calculated as long-term debt plus unamortized gains on reacquired debt less unamortized issuance expenses, premiums and losses on reacquired debt. The debt calculation excludes transition bonds issued by Bondco. Equity is calculated as membership interests determined in accordance with US GAAP, excluding the effects of purchase accounting (which included recording the initial goodwill and fair value adjustments and the subsequent related impairments and amortization). On July 29, 2015, our board of directors declared a cash distribution between $110 million and $120 million, to be paid to our members in August 2015 with the exact amount to be determined by management using estimated earnings through July 31, 2015. During the six months ended June 30, 2015, our board of directors declared, and we paid the following cash distributions to our members: Declaration Date Payment Date Amount April 29, 2015 May 15, 2015 $ February 25, 2015 February 26, 2015 $ Membership Interests The following tables present the changes to membership interests during the six months ended June 30, 2015 and 2014: Capital Accounts Accumulated Other Comprehensive Income (Loss) Total Membership Interests Balance at December 31, 2014 $ $ $ Net income - Distributions - Net effects of cash flow hedges (net of tax) - Defined benefit pension plans (net of tax) - Balance at June 30, 2015 $ $ $ Capital Accounts Accumulated Other Comprehensive Income (Loss) Total Membership Interests Balance at December 31, 2013 $ $ $ Net income - Distributions - Net effects of cash flow hedges (net of tax) - Balance at June 30, 2014 $ $ $ Accumulated Other Comprehensive Income (Loss) The following tables present the changes to accumulated other comprehensive income (loss) for the six months ended June 30, 2015 and 2014: Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2014 $ $ $ Defined benefit pension plans (net of tax) - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at June 30, 2015 $ $ $ Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2013 $ $ $ Defined benefit pension plans (net of tax) - - - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at June 30, 2014 $ $ $	9 . MEMBERSHIP INTERESTS Cash Distributions On February 25 , 2015, our board of directors declared a cash distribution of $ 100 million, which was p aid to our members on February 26 , 2015. During 2014, our board of directors declared, and we paid , the following cash distributions to our members: Declaration Date Payment Date Amount October 21, 2014 October 22, 2014 $ July 30, 2014 July 31, 2014 $ April 30, 2014 May 1, 2014 $ February 19, 2014 February 20, 2014 $ During 2013, our board of directors declared, and we paid , the following cash distributions to our members: Declaration Date Payment Date Amount October 29, 2013 October 31, 2013 $ July 31, 2013 August 1, 2013 $ May 1, 2013 May 2, 2013 $ February 13, 2013 February 15, 2013 $ Distributions are limited by our required regulatory capital structure to be at or below the assumed debt-to-equity ratio established periodically by the PUCT for ratemaking purposes, which is currently set at 60 % debt to 40 % equity. At December 31, 2014, our regulatory capitalization ratio was 58.8 % debt and 41.2 % equity. The PUCT has the authority to determine what types of debt and equity are included in a utility’s debt-to-equity ratio. For purposes of this ratio, debt is calculated as long-term debt plus unamortized gains on reacquired debt less unamortized issuance expenses, premiums and losses on reacquired debt. The debt calculation excludes transition bonds issued by Bondco. Equity is calculated as membership interests determined in accordance with US GAAP, excluding the effects of purchase accounting (which included recording the initial goodwill and fair value adjustments and the subsequent related impairments and amortization). At December 31, 2014, $ 184 million was available for distribution to our members under the capital structure restriction. Accumulated Other Comprehensive Income (Loss) The following table presents the changes to accumulated other comprehensive income (loss) for the year ended December 31, 201 4 . Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2013 $ $ $ Defined benefit pension plans (net of tax) - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at December 31, 2014 $ $ $ The following table presents the changes to accumulated other comprehensive income (loss) for the year ended December 31, 201 3 . Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2012 $ $ $ Defined benefit pension plans (net of tax) - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at December 31, 2013 $ $ $

Pension and Other Postretiremen

Pension and Other Postretirement Employee Benefits (OPEB) Plans	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Pension And Other Postretirement Employee Benefits (OPEB) Plans [Abstract]
PENSION AND OTHER POSTRETIREMENT EMPLOYEE BENEFITS (OPEB) PLANS	9. PENSION AND OTHER POSTRETIREMENT EMPLOYEE BENEFITS PLANS We participate in and have liabilities under the Oncor Retirement Plan and the EFH Retirement Plan, both of which are qualified pension plans under Section 401(a) of the Internal Revenue Code of 1986, as amended (Code), and are subject to the provisions of ERISA. Employees do not contribute to either plan. These pension plans provide benefits to participants under one of two formulas: (i) a Cash Balance Formula under which participants earn monthly contribution credits based on their compensation and a combination of their age and years of service, plus monthly interest credits or (ii) a Traditional Retirement Plan Formula based on years of service and the average earnings of the three years of highest earnings. The interest component of the Cash Balance Formula is variable and is determined using the yield on 30-year Treasury bonds. Under the Cash Balance Formula, future increases in earnings will not apply to prior service costs. See Note 10 to Financial Statements in our 2014 Form 10-K for additional information regarding our pension plans and the EFH OPEB Plan. In April 2014, we entered into an agreement with EFH Corp. in which we agreed to transfer to the Oncor OPEB Plan effective July 1, 2014, the assets and liabilities related to our eligible current and future retirees as well as certain eligible retirees of EFH Corp. whose employment included service with both Oncor (or a predecessor regulated electric business) and a non-regulated business of EFH Corp. Pursuant to the agreement, EFH Corp. will retain its portion of the liability for retiree benefits related to those retirees. Since the Oncor OPEB Plan offers identical coverages as the EFH OPEB Plan and we and EFH Corp. retain the same responsibility for participants as before, there was no financial impact as a result of the transfer other than from a remeasurement of the Oncor OPEB Plan’s asset values and obligations. As we are not responsible for EFH Corp.’s portion of the Oncor OPEB Plan’s unfunded liability, that amount is not reported on our balance sheet. Our net costs related to pension and OPEB plans for the three and six months ended June 30, 2015 and 2014 were comprised of the following: Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Components of net allocated pension costs: Service cost $ $ $ $ Interest cost Expected return on assets Amortization of net loss Net pension costs Components of net OPEB costs: Service cost Interest cost Expected return on assets Amortization of prior service cost Amortization of net loss Net OPEB costs Total net pension and OPEB costs Less amounts deferred principally as property or a regulatory asset Net amounts recognized as expense $ $ $ $ The discount rates reflected in net pension and OPEB costs in 2015 are 3.95% , 4.19% and 4.23% for the Oncor Retirement Plan, the EFH Retirement Plan and the OPEB plans, respectively. The expected return on pension and OPEB plan assets reflected in the 2015 cost amounts are 5.25% , 5.38% and 6.65% for the Oncor Retirement Plan, the EFH Retirement Plan and the OPEB plans, respectively. We made cash contributions to the pension plans and OPEB plans of $2 million and $13 million, respectively, during the six months ended June 30, 2015. We expect to make additional cash contributions to the pension plans and OPEB plans of $49 million and $12 million, respectively, during the remainder of 2015 and approximately $373 million and $147 million, respectively, in the 2015 to 2019 period.	10 . PENSION AND OTHER POSTRETIREMENT EMPLOYEE BENEFITS (OPEB) PLANS Regulatory Recovery of Pension and OPEB Costs PURA provides for our recovery of pension and OPEB costs applicable to services of our active and retired employees, as well as services of other EFH Corp. active and retired employees prior to the deregulation and disaggregation of EFH Corp.’s electric utility businesses effective January 1, 2002 (recoverable service). Accordingly, we entered into an agreement with EFH Corp. whereby we assumed responsibility for applicable pension and OPEB costs related to those personnel’s recoverable service. We are authorized to establish a regulatory asset or liability for the difference between the amounts of pension and OPEB costs approved in current billing rates and the actual amounts that would otherwise have been recorded as charges or credits to earnings related to recoverable service. Amounts deferred are ultimately subject to regulatory approval. At December 31, 2014 and 2013, we had recorded regulatory assets totaling $ 1.166 billion and $ 786 million, respectively, related to pension and OPEB costs, including amounts related to deferred expenses as well as amounts related to unfunded liabilities that otherwise would be recorded as other comprehensive income. In a 2012 agreement described below, we assumed primary responsibility for retirement costs related to certain non-recoverable service. Any retirement costs associated with non-recoverable service is not recoverable through rates. Pension Plan s We participate in and have liabilities under the Oncor Retirement Plan and the EFH Retirement Plan, both of which are qualified pension plans under Section 401(a) of the Internal Revenue Code of 1986, as amended (Code), and are subject to the provisions of ERISA. Employees do not contribute to either plan. These pension plans provide benefits to participants under one of two formulas: (i) a Cash Balance Formula under which participants earn monthly contribution credits based on their compensation and a combination of their age and years of service, plus monthly interest credits or (ii) a Traditional Retirement Plan Formula based on years of service and the average earnings of the three years of highest earnings. The interest component of the Cash Balance Formula is variable and is determined using the yield on 30-year Treasury bonds. Under the Cash Balance Formula, future increases in earnings will not apply to prior service costs. All eligible employees hired after January 1, 2001 participate under the Cash Balance Formula. Certain employees, who, prior to January 1, 2002, participated under the Traditional Retirement Plan Formula, continue their participation under that formula. It is the sponsors’ policy to fund the plans on a current basis to the extent required under existing federal tax and ERISA regulations. In August 2012, EFH Corp. approved certain amendments to the EFH Retirement Plan. These actions were completed in the fourth quarter of 2012, and the amendments resulted in: · the splitting off of assets and liabilities under the plan associated with our employees and all retirees and terminated vested participants of EFH Corp. and its subsidiaries (including discontinued businesses) to a new qualified pension plan that provides benefits identical to those provided under the EFH Retirement Plan, for which we assumed sponsorship from EFH Corp. effective January 1, 2013 (Oncor Retirement Plan); · maintaining assets and liabilities under the plan associated with active collective bargaining unit (union) employees of EFH Corp.'s competitive subsidiaries under the current plan; · the splitting off of assets and liabilities under the plan associated with all other plan participants (active nonunion employees of EFH Corp.’s competitive businesses) to a terminating plan, freezing benefits and vesting all accrued plan benefits for these participants, and · the termination of, distributions of benefits under, and settlement of all of EFH Corp.'s liabilities under the terminating plan. As a result of these actions and in connection with assuming sponsorship of the Oncor Retirement Plan, we entered into an agreement with EFH Corp. to assume primary responsibility for benefits of certain participants for whom EFH Corp. bore primary funding responsibility (a closed group of retired and terminated vested plan participants not related to our regulated utility business) at December 31, 2012 . As we received a corresponding amount of assets with the assumed liabilities, execution of the agreement did not have a material impact on our reported results of operations or financial condition. In the fourth quarter of 2012, EFH Corp. made cash contributions totaling $ 259 million to settle the terminating plan obligations and fully fund its obligations under the Oncor Retirement Plan. We also have the S upplemental Retirement P lan for certain employees whose retirement benefits cannot be fully earned under the qualified retirement plan, the information for which is included below. OPEB Plan Until July 1, 2014, we participated with EFH Corp. and other subsidiaries of EFH Corp. to offer certain health care and life insurance benefits to eligible employees and their eligible dependents upon the retirement of such employees (EFH OPEB Plan). As discussed below, we ceased participation in the EFH OPEB Plan and established our own OPEB plan for our eligible employees and their dependents (Oncor OPEB Plan). For employees retiring on or after January 1, 2002, the retiree contributions required for such coverage vary based on a formula depending on the retiree’s age and years of service. In April 2014, we entered into an agreement with EFH Corp. in which we agreed to transfer to the Oncor OPEB Plan effective July 1, 2014, the assets and liabilities related to our eligible current and future retirees as well as certain eligible retirees of EFH Corp. whose employment included service with both Oncor (or a predecessor regulated electric business) and a non-regulated business of EFH Corp. Pursuant to the agreement, EFH Corp. will retain its portion of the liability for retiree benefits related to those retirees. Since the Oncor OPEB Plan offers identical coverages as the EFH OPEB Plan and we and EFH Corp. retain the same responsibility for participants as before, there was no financial impact as a result of the transfer other than from a remeasurement of the Oncor OPEB Plan’s asset values and obligations. As we are not responsible for EFH Corp.’s portion of the Oncor OPEB Plan’s unfunded liability totaling $101 million as of December 31, 2014, that amount is not reported on our balance sheet. Pension and OPEB Costs Recognized as Expense P ension and OPEB amounts p rovided herein include amounts related only to our portion of the various plans based on actuarial computations and reflect our employee and retiree demographics as described above. Our net costs related to pension and OPEB plans for the years ended December 31, 2014, 2013 and 2012 were comprised of the following : Year Ended December 31, 2014 2013 2012 Pension costs $ $ $ OPEB costs Total benefit costs Less amounts deferred principally as property or a regulatory asset Net amounts recognized as expense $ $ $ We and EFH Corp. use the calculated value method to determine the market-related value of the assets held in the trust for purposes of calculating our pension costs. We and EFH Corp. include the realized and unrealized gains or losses in the market-related value of assets over a rolling four -year period. Each year, 25 % of such gains and losses for the current year and for each of the preceding three years is included in the market-related value. Each year, the market-related value of assets is increased for contributions to the plan and investment income and is decreased for benefit payments and expenses for that year. We and EFH Corp. use the fair value method to determine the market-related value of the assets held in the trust for purposes of calculating OPEB cost. Detailed Information Regarding Pension and OPEB Benefits The following pension and OPEB information is based on December 31, 201 4 , 201 3 and 201 2 measurement dates: Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2012 2014 2013 2012 Assumptions Used to Determine Net Periodic Pension and OPEB Costs: Discount rate (a) Expected return on plan assets Rate of compensation increase - - - Components of Net Pension and OPEB Costs: Service cost $ $ $ $ $ $ Interest cost Expected return on assets Amortization of net transition obligation - - - - - Amortization of prior service cost (credit) - - - Amortization of net loss Settlement charges - - - - Net periodic pension and OPEB costs $ $ $ $ $ $ Other Changes in Plan Assets and Benefit Obligations Recognized as Regulatory Assets or in Other Comprehensive Income: Net loss (gain) $ $ $ $ $ - $ Amortization of net loss Amortization of transition obligation (asset) - - - - - Amortization of prior service (cost) credit - - - Settlement charges - - - - Curtailment - - - - - Total recognized as regulatory assets or other comprehensive income Total recognized in net periodic pension and OPEB costs and as regulatory assets or other comprehensive income $ $ $ $ $ $ _______________ (a) As a result of the 2012 amendments discussed above, the discount rate reflected in net pension costs for January through July 2012 was 5.00 %, for August through September 2012 was 4.15 % and for October through December 2012 was 4.20 %. As a result of the transfer of OPEB plan assets and liabilities from the EFH OPEB Plan to the Oncor OPEB Plan discussed above, the discount rate reflected in OPEB costs for January through Ju ne 2014 was 4.98% and for July through December 2014 was 4.39% . Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2012 2014 2013 2012 Assumptions Used to Determine Benefit Obligations at Period End: Discount rate Rate of compensation increase - - - Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2014 2013 Change in Projected Benefit Obligation: Projected benefit obligation at beginning of year $ $ $ $ Service cost Interest cost Participant contributions - - Medicare Part D reimbursement - - - Settlement charges - - - Actuarial (gain) loss Benefits paid Projected benefit obligation at end of year $ $ $ $ Accumulated benefit obligation at end of year $ $ $ - $ - Change in Plan Assets: Fair value of assets at beginning of year $ $ $ $ Actual return (loss) on assets Employer contributions Settlement charges - - - Participant contributions - - Benefits paid Fair value of assets at end of year $ $ $ $ Funded Status: Projected benefit obligation at end of year $ $ $ $ Fair value of assets at end of year Funded status at end of year $ $ $ $ Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2014 2013 Amounts Recognized in the Balance Sheet Consist of: Liabilities: Other current liabilities $ $ $ - $ - Other noncurrent liabilities Net liability recognized $ $ $ $ Regulatory assets: Net loss $ $ $ $ Prior service cost (credit) - - Net regulatory asset recognized $ $ $ $ Accumulated other comprehensive net loss $ $ $ $ The following tables provide information regarding the assumed health care cost trend rates. Year Ended December 31, 2014 2013 Assumed Health Care Cost Trend Rates – Not Medicare Eligible: Health care cost trend rate assumed for next year Rate to which the cost trend is expected to decline (the ultimate trend rate) Year that the rate reaches the ultimate trend rate Assumed Health Care Cost Trend Rates – Medicare Eligible: Health care cost trend rate assumed for next year Rate to which the cost trend is expected to decline (the ultimate trend rate) Year that the rate reaches the ultimate trend rate 1-Percentage Point Increase 1-Percentage Point Decrease Sensitivity Analysis of Assumed Health Care Cost Trend Rates: Effect on accumulated postretirement obligation $ $ Effect on postretirement benefits cost The following table provides information regarding pension plans with projected benefit obligations (PBO) and accumulated benefit obligations (ABO) in excess of the fair value of plan assets. At December 31, 2014 2013 Pension Plans with PBO and ABO in Excess of Plan Assets: Projected benefit obligations $ $ Accumulated benefit obligations Plan assets Pension and OPEB Plan s Investment Strategy and Asset Allocations Our investment objective for the retirement plans is to invest in a suitable mix of assets to meet the future benefit obligations at an acceptable level of risk, while minimizing the volatility of contributions. Equity securities are held to achieve returns in excess of passive indexes by participating in a wide range of investment opportunities. International equity and real estate securities are used to further diversify the equity portfolio . International equity securities may include investments in both developed and emerging international markets. Fixed income securities include primarily corporate bonds from a diversified range of companies, US Treasuries and agency securities and money market instruments. Our investment strategy for fixed income investments is to maintain a high grade portfolio of securities, which assists us in managing the volatility and magnitude of plan contributions and expense while maintaining sufficient cash and short-term investments to pay near-term benefits and expenses. The retirement plans’ investments are managed in two pools: one associated with the recoverable service portion of plan obligations related to our regulated utility business, and the other associated with plan obligations for the closed group of retired and terminated plan participants not related to our regulated utility business that we assumed from EFH Corp. as discussed above. The recoverable service portion is invested in a broadly diversified portfolio of equity and fixed income securities. The nonrecoverable service portion is invested in fixed income securities intended to fully hedge the obligations, within practical limitations. The target asset allocation ranges of the pension plan s investments by asset category are as follows: Target Allocation Ranges Asset Category Recoverable Nonrecoverable US equities 19% - 25% — International equities 14% - 20% — Fixed income 48% - 65% 100% Real estate 2% - 7% — Our investment objective for the OPEB p lan primarily follows the objectives of the pension plans discussed above, while maintaining sufficient cash and short-term investments to pay near-term benefits and expenses. The actual amounts at December 31, 2014 provided below are consistent with the asset allocation targets. Fair Value Measurement of Pension Plan s Assets At December 31, 201 4 and 201 3 , pension plan s assets measured at fair value on a recurring basis consisted of the following: At December 31, 2014 At December 31, 2013 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Asset Category Interest-bearing cash $ - $ $ - $ $ - $ $ - $ Equity securities: US - - International - - Fixed income securities: Corporate bonds (a) - - - - US Treasuries - - - - Other (b) - - - - Real estate - - - Total assets $ $ $ $ $ $ $ $ _____________ (a) Substantially all corporate bonds are rated investment grade by a major ratings agency such as Moody’s. (b) Other consists primarily of municipal bonds , emerging market debt, bank loans and fixed income derivative instruments. There was no significant change in the fair value of Level 3 assets in the periods presented. Fair Value Measurement of OPEB P lan Assets At December 31, 201 4 and 201 3, OPEB p lan assets measured at fair value on a recurring basis consisted of the following: At December 31, 2014 At December 31, 2013 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Asset Category Interest-bearing cash $ $ $ - $ $ - $ $ - $ Equity securities: US - - International - - - - Fixed income securities: Corporate bonds (a) - - - - US Treasuries - - - - Other (b) - - Total assets $ $ $ - $ $ $ $ - $ _____________ (a) Substantially all corporate bonds are rated investment grade by a major ratings agency such as Moody’s. (b) Other consists primarily of diversified bond mutual funds. Expected Long-Term Rate of Return on Assets Assumption The retirement plans’ strategic asset allocation is determined in conjunction with the plans’ advisors and utilizes a comprehensive Asset-Liability modeling approach to evaluate potential long-term outcomes of various investment strategies. The modeling incorporates long-term rate of return assumptions for each asset class based on historical and future expected asset class returns, current market conditions, rate of inflation, current prospects for economic growth, and taking into account the diversification benefits of investing in multiple asset classes and potential benefits of employing active investment management. Pension Plans OPEB Plan Asset Class Expected Long-Term Rate of Return Asset Class Expected Long-Term Rate of Return International equity securities 7.50% 401(h) accounts 6.96% US equity securities 6.80% Life insurance VEBA 6.45% Real estate 6.10% Union VEBA 6.45% Credit strategies 4.74% Non-union VEBA 2.90 % Fixed income securities 4.40 % Weighted average 6.65% Weighted average (a) 5.94% _____________ (a) The 2015 expected long-term rate of return for the nonregulated portion of the Oncor Retirement Plan is 3.95 %. Significant Concentrations of Risk The plans’ investments are exposed to risks such as interest rate, capital market and credit risks. We and EFH Corp. seek to optimize return on investment consistent with levels of liquidity and investment risk which are prudent and reasonable, given prevailing capital market conditions and other factors specific to participating employers. While we and EFH Corp. recognize the importance of return, investments will be diversified in order to minimize the risk of large losses unless, under the circumstances, it is clearly prudent not to do so. There are also various restrictions and guidelines in place including limitations on types of investments allowed and portfolio weightings for certain investment securities to assist in the mitigation of the risk of large losses. Assumed Discount Rate For the Oncor retirement plans at December 31, 2014, we selected the assumed discount rate using the Aon Hewitt AA-AAA Bond Universe yield curve, which is based on corporate bond yields and at December 31, 2014 consisted of 1,160 corporate bonds with an average rating of AA and AAA using Moody’s, S&P and Fitch ratings. For the Oncor OPEB P lan and the EFH Retirement Plan at December 31, 2014 , we and EFH Corp. , respectively, selected the assumed discount rate using the Aon Hewitt AA Above Median yield curve, which is based on corporate bond yields and at December 31, 2014 consisted of 415 corporate bonds with an average rating of AA using Moody’s, S&P and Fitch ratings. Amortization in 201 5 In 2015, amortization of the net actuarial loss and prior service c redit for the defined benefit pension plans from regulatory assets and other comprehensive income into net periodic benefit cost is expected to be $ 63 million and a less than $ 1 million credit , respectively. Amortization of the net actuarial loss and prior service credit for the OPEB plans from regulatory assets into net periodic benefit cost is expected to be $ 33 million and a $ 20 million credit, respectively. Pension and OPEB Plan s Cash Contributions Our contributions to the benefit plans were as follows: Year Ended December 31, 2014 2013 2012 Pension plans contributions $ $ $ OPEB plan contributions Total contributions $ $ $ Our funding for the pension plans and the Oncor OPEB P lan is expected to total $ 45 million and $ 31 million, respectively in 2015 and approximately $ 407 million and $ 156 million, respectively, in the 2015 to 2019 period. Future Benefit Payments Estimated future benefit payments to beneficiaries are as follows: 2015 2016 2017 2018 2019 2020-24 Pension plans $ $ $ $ $ $ OPEB plan $ $ $ $ $ $ Thrift Plan Our employees are eligible to participate in a qualified savings plan, a participant-directed defined contribution plan intended to qualify under Section 401(a) of the Code, and is subject to the provisions of ERISA. Under the p lan, employees may contribute, through pre-tax salary deferrals and/or after-tax applicable payroll deductions, a portion of t heir regular salary or wages as permitted under law. Employer matching contributions are made in an amount equal to 100 % of the first 6 % of employee contributions for employees who are covered under the Cash Balance Formula of the Oncor Retirement Plan, and 75 % of the first 6 % of employee contributions for employees who are covered under the Traditional Retirement Plan Formula of the Oncor Retirement Plan. Employer matching contributions are made in cash and may be allocated by participants to any of the plan's investment options. Until January 1, 2015, the thrift plan in which our eligible employees were able to participate was sponsored by EFH Corp. (EFH Thrift Plan). Our contributions to the EFH Thrift Plan totaled $13 million, $13 million and $12 million for the years ended December 31, 2014, 2013 and 2012, respectively. Effective January 1, 2015, the accounts of Oncor participants were transferred from the EFH Thrift Plan to an Oncor-sponsored spin-off of the EFH Thrift Plan (Oncor Thrift Plan). Our matching contributions are the same under the Oncor Thrift Plan as they were under the EFH Thrift Plan at the time of the transfer. Since the Oncor Thrift Plan offers identical benefits to our employees, transfer to the Oncor Thrift Plan is not expected to have an impact on our results of operations, financial condition or cash flows.

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2014
Stock-Based Compensation [Abstract]
STOCK-BASED COMPENSATION	11. STOCK-BASED COMPENSATION We currently do not offer stock-based compensation to our employees or directors. In 2008, we established the SARs Plan under which certain of our executive officers and key employees were granted stock appreciation rights payable in cash, or in some circumstances, Oncor membership interests. In February 2009, we established the Oncor Electric Delivery Company LLC Director Stock Appreciation Rights Plan (the Director SARs Plan) under which certain non-employee members of our board of directors and other persons having a relationship with us were granted SARs payable in cash, or in some circumstances, Oncor membership interests. In November 2012, we accepted the early exercise of all outstanding SARs (both vested and unvested, totaling 14,322,219 SARs under the SARs Plan and 55,000 SARs under the Director SARs Plan) issued to date pursuant to both SARs Plans. The early exercise was permitted by our board of directors pursuant to the provision of the SARs Plan that permits the board to accelerate the vesting and exercisability of SARs. The early exercise of SARs entitled each participant in the SARs Plan to: (1) an exercise payment (Exercise Payment) equal to the number of SARs exercised multiplied by the difference between $ 14.54 and the base price of the SARs (as stated in the award letter for each SARs grant); and (2) the accrual of interest on all dividends declared to date with respect to the SARs, but no further dividend accruals. As a result of the early exercise, in 2012 we paid an aggregate of approximately $ 64 million related to Exercise Payments ($ 57 million charged to expense), and began accruing interest on approximately $ 18 million in aggregate dividends . Additionally, certain executive officers agreed to defer payment of a portion of his/her Exercise Payment into a bankruptcy remote investment trust until the earlier of November 7, 2016 or the occurrence of an event triggering SAR exercisability pursuant to Section 5(c)(ii) of the SARs Plan. These deferred payments totaled approximately $ 6 million in the aggregate. In July 2014, the O&C Committee of our board of directors approved the early distribution of these deferred amounts and the winding up of the trust. As a result, in August 2014 the trust was dissolved and all deferred payments held in the trust were distributed to the respective executive officers, together with a proportionate share of the trust’s aggregate investment earnings. As described above, as part of the 2012 early exercise of SARs we began accruing interest on dividends declared with respect to the SARs. Under both SARs plans, dividends that are paid in respect of Oncor membership interests while the SARs were outstanding were credited to the SARs holder’s account as if the SARs were units, payable upon the earliest to occur of death, disability, separation from service, unforeseeable emergency, a change in control, or the exercise of the SARs. As a result, in 2012 we recorded compensation expense of approximately $ 6 million relating to dividend accruals through November 2012. For accounting purposes, the liability is discounted based on an employee’s or director’s expected retirement date . We recognized approximately $1 million, $2 million and $1 m illion in accretion and interest with respect to such dividends in 2014, 2013 and 2012, respectively.

Related-Party Transactions

Related-Party Transactions	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Related-Party Transactions [Abstract]
RELATED-PARTY TRANSACTIONS	10. RELATED-PARTY TRANSACTIONS The following represent our significant related-party transactions. See Note 2 for additional information regarding related-party contingencies resulting from the EFH Bankruptcy Proceedings. · We record revenue from TCEH, principally for electricity delivery fees, which totaled $224 million and $225 million for the three months ended June 30, 2015 and 2014, respectively, and $460 million and $465 million for the six months ended June 30, 2015 and 2014, respectively. The fees are based on rates regulated by the PUCT that apply to all REPs. These revenues included less than $1 million for each of the three- and six-month periods ended June 30, 2015 and 2014 pursuant to a transformer maintenance agreement with TCEH. Trade accounts and other receivables from EFH Corp. affiliates – net reported on our balance sheet, primarily consisting of trade receivables from TCEH related to these electricity delivery fees, are as follows: At June 30, At December 31, 2015 2014 Trade accounts and other receivables from affiliates - billed $ $ Trade accounts and other receivables from affiliates - unbilled Trade accounts and other payables to affiliates Trade accounts and other receivables from affiliates – net $ $ · EFH Corp. subsidiaries charge us for certain administrative services at cost. Our payments to EFH Corp. subsidiaries for administrative services, which are primarily reported in operation and maintenance expenses, totaled $4 million and $7 million for the three months ended June 30, 2015 and 2014, respectively, and $9 million and $15 million for the six months ended June 30 2015 and 2014, respectively. We also charge each other for shared facilities at cost. Our payments to EFH Corp. for shared facilities totaled $1 million for the each of the three-month periods ended June 30, 2015 and 2014 and $2 million for each of the six-month periods ended June 30, 2015 and 2014. Payments we received from EFH Corp. subsidiaries related to shared facilities totaled less than $1 million for the each of the three-month periods ended June 30, 2015 and 2014 and $1 million for each of the six-month periods ended June 30, 2015 and 2014. · Through June 30, 2014, we participated in the Energy Future Holdings Health and Welfare Benefit Program, which provided employee benefits to our workforce. In October 2013, we notified EFH Corp. of our intention to withdraw from the benefit program effective June 30, 2014 and entered into an agreement with EFH Corp. pursuant to which, we agreed to pay EFH Corp. $1 million to reimburse EFH Corp. for its increased costs under the program as a result of our withdrawal from the program and the additional administrative work required to effectuate our withdrawal from the benefit program and transition to the new benefit program. This one-time payment was paid to EFH Corp. in June 2014. In April 2014, we entered into a welfare benefit administration agreement with EFH Corp., pursuant to which EFH Corp. provided us with welfare benefit administration services under our new benefit plans from July 1, 2014 until December 31, 2014. · We are not a member of EFH Corp.’s consolidated tax group, but EFH Corp.’s consolidated federal income tax return includes EFH Corp.’s portion of our results due to EFH Corp.’s equity ownership in us. Under the terms of a tax sharing agreement among us, Oncor Holdings, Texas Transmission, Investment LLC and EFH Corp., we are generally obligated to make payments to Texas Transmission, Investment LLC and EFH Corp., pro rata in accordance with their respective membership interests, in an aggregate amount that is substantially equal to the amount of federal income taxes that we would have been required to pay if we were filing our own corporate income tax return. For periods prior to the tax sharing agreement (entered into in October 2007 and amended and restated in November 2008), we are responsible for our share, if any, of redetermined tax liability for the EFH Corp. consolidated tax group. EFH Corp. also includes our results in its consolidated Texas margin tax payments, which are accounted for as income taxes and calculated as if we were filing our own return. See discussion in Note 1 to Financial Statements in our 2014 Form 10-K under “Income Taxes.” Under the “in lieu of” tax concept, all in lieu of tax assets and tax liabilities represent amounts that will eventually be settled with our members. Amounts payable to (receivable from) members related to income taxes under the tax sharing agreement and reported on our balance sheet consisted of the following: At June 30, 2015 At December 31, 2014 EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total Federal income taxes receivable $ $ $ $ $ $ Federal income taxes payable - - - - - - Texas margin taxes payable - - Net payable (receivable) $ $ $ $ $ $ Cash payments made to members related to income taxes consisted of the following: Six Months Ended June 30, 2015 Six Months Ended June 30, 2014 EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total Federal income taxes $ - $ - $ - $ $ $ Texas margin taxes - - Total payments (receipts) $ $ - $ $ $ $ · In September 2014, EFH Corp. signed the final agreed Revenue Agent Report and associated documentation (RAR) for the 2007 tax year and filed a motion seeking approval of the bankruptcy court in the EFH Bankruptcy Proceedings of its signing of the RAR. The cash income tax impact related to the conclusion of the 2007 audit is a refund from our members of approximately $45 million that is recorded in liability in lieu of deferred income taxes. In the fourth quarter of 2014, the Department of Justice filed a claim with the bankruptcy court for open tax years through 2013 that was consistent with the settlement EFH Corp. reached with the IRS for tax years 2003 through 2006. The cash income tax impact related to the conclusion of the 2003 through 2006 audit is expected to be a refund of approximately $11 million and is recorded in liability in lieu of deferred income taxes. In the second quarter of 2015, EFH Corp. received the final RAR and associated documentation for the 2008 tax year which includes the results of Oncor. In addition, we received the final RAR and associated documentation for tax years 2008 and 2009 in which we filed a partnership tax return. The RARs reflect additional deductions for Oncor resulting in approximately $8 million in tax refunds from our members. Of the expected refunds, $4 million is related to pre-partnership formation and is recorded in liability in lieu of deferred income taxes and $4 million is related to post-partnership formation and is recorded as a current income tax receivable. We expect to collect the refund related to our 2008 and 2009 partnership tax return audit during 2015. · Our PUCT-approved tariffs include requirements to assure adequate credit worthiness of any REP to support the REP’s obligation to collect transition bond-related charges on behalf of Bondco. Under these tariffs, as a result of TCEH’s credit rating being below investment grade, TCEH is required to post collateral support in an amount equal to estimated transition charges over specified time periods. Accordingly, at both June 30, 2015 and December 31, 2014, TCEH had posted security in the amount of $9 million for our benefit. · Under Texas regulatory provisions, the trust fund for decommissioning TCEH’s Comanche Peak nuclear generation facility is funded by a delivery fee surcharge we collect from REPs and remit monthly to TCEH. Delivery fee surcharges totaled $4 million for each of the three-month periods ended June 30, 2015 and 2014 and $8 million for each of the six-month periods ended June 30, 2015 and 2014. Our sole obligation with regard to nuclear decommissioning is as the collection agent of funds charged to ratepayers for nuclear decommissioning activities. If, at the time of decommissioning, actual decommissioning costs exceed available trust funds, we would not be obligated to pay any shortfalls but would be required to collect any rates approved by the PUCT to recover any additional decommissioning costs. Further, if there were to be a surplus when decommissioning is complete, such surplus would be returned to ratepayers under terms prescribed by the PUCT. · Affiliates of the Sponsor Group have (1) sold, acquired or participated in the offerings of our debt or debt securities in open market transactions or through loan syndications, and (2) performed various financial advisory, dealer, commercial banking and investment banking services for us and certain of our affiliates for which they have received or will receive customary fees and expenses, and may from time to time in the future participate in any of the items in (1) and (2) above. See Note 8 for information regarding distributions to members and Note 9 for information regarding our participation in EFH Corp. pension and OPEB plans and transactions with EFH Corp. involving employee benefit matters.	1 2 . RELATED-PARTY TRANSACTIONS The following represent our significant related-party transactions and related matters . See Note 2 for additional information regarding related-party contingencies resulting from the EFH Bankruptcy Proceedings. · We record revenue from TCEH, principally for electricity delivery fees, which totaled $ 97 1 million, $967 million and $ 962 m illion for the years ended December 31, 2014, 2013 and 2012, respectively. The fees are based on rates regulated by the PUCT that apply to all REPs. The balance sheets at December 31, 2014 and 2013 reflect net accounts receivable from affiliates totaling $ 118 million ($ 52 million of which was unbilled) and $ 135 million ($ 56 million of which was unbilled), respectively, primarily consisting of trade receivables from TCEH related to these electricity delivery fees . Trade accounts and other receivables from EFH Corp. affiliates – net reported on our balance sheet consisted of the following: At December 31, 2014 2013 Trade accounts and other receivables from affiliates $ $ Trade accounts and other payables to affiliates Trade accounts and other receivables from affiliates – net $ $ · EFH Corp. subsidiaries charge us for certain administrative services at cost. Our payments to EFH Corp. subsidiaries for administrative services, which are primarily reported in operation and maintenance expenses, totaled $ 32 million, $ 30 million and $ 32 million for the years ended December 31, 2014, 2013 and 2012, respectively. We also charge each other for shared facilities at cost. Our payments to EFH Corp. subsidiaries for shared facilities totaled $4 million, $4 million and $5 million for the years ended December 31, 2014, 2013 and 2012, respectively. Payments we received from EFH Corp. subsidiaries related to shared facilities, totaled $ 2 million for each of the years ended December 31, 2014, 2013 and 2012. · Through June 30, 2014, we participated in the Energy Future Holdings Health and Welfare Benefit Program, which provided employee benefits to our workforce. In October 2013, we notified EFH Corp. of our intention to withdraw from the benefit program effective June 30, 2014 and entered into an agreement with EFH Corp. pursuant to which we paid EFH Corp. $1 million in June 2014 to reimburse EFH Corp. for its increased costs under the program as a result of our withdrawal from the program and the additional administrative work required to effectuate our withdrawal from the benefit program and transition to the new benefit program. In April 2014, we entered into a welfare benefit administration agreement with EFH Corp., pursuant to which EFH Corp. continued to provide us with welfare benefit administration services under our new benefit plans from July 1, 2014 until December 31, 2014. These amounts are included in the administrative services payments to EFH Corp. subsidiaries reported above. · We are not a member of EFH Corp.’s consolidated tax group, but EFH Corp.’s consolidated federal income tax return includes EFH Corp.’s portion of our results due to EFH Corp.’s equity ownership in us. Under the terms of a tax sharing agreement among us, Oncor Holdings, Texas Transmission, Investment LLC and EFH Corp., we are generally obligated to make payments to Texas Transmission, Investment LLC and EFH Corp., pro rata in accordance with their respective membership interests, in an aggregate amount that is substantially equal to the amount of federal income taxes that we would have been required to pay if we were filing our own corporate income tax return. For periods prior to the tax sharing agreement (entered into in October 2007 and amended and restated in November 2008), we are responsible for our share of redetermined tax liability for the EFH Corp. consolidated tax group. EFH Corp. also includes our results in its consolidated Texas margin tax payments, which we account for as income taxes and calculate as if we were filing our own return. See discussion in Note 1 under “Income Taxes.” Under the “in lieu of” tax concept, all in lieu of tax assets and tax liabilities represent amounts that will eventually be settled with our members. In the unlikely event such amounts are not paid under the tax sharing agreement, it is probable that they would be reimbursed to rate payers. Amounts payable to (receivable from) members related to income taxes under the agreement and reported on our balance sheet consisted of the following: At December 31, 2014 At December 31, 2013 EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total Federal income taxes receivable $ $ $ $ $ $ Texas margin taxes payable - - Net payable (receivable) $ $ $ $ $ $ - Cash payments made to (received from) members related to income taxes consisted of the following: Year Ended December 31, 2014 Year Ended December 31, 2013 Year Ended December 31, 2012 EFH Corp. Texas Transm. Total EFH Corp. Texas Transm. Total EFH Corp. Texas Transm. Total Federal income taxes (a) $ $ $ $ $ $ $ $ $ Texas margin taxes (b) - - - Total payments (receipts) $ $ $ $ $ $ $ $ $ ______________ (a) Includes $33 million payment made to EFH Corp. in 2013 related to the 1997-2002 IRS appeals settlement. (b) Includes $10 million refund received from EFH Corp. in 2013 related to 1997-2001 amended Texas franchise tax returns. · Our PUCT-approved tariffs include requirements to assure adequate credit worthiness of any REP to support the REP’s obligation to collect transition bond-related charges on behalf of Bondco. Under these tariffs, as a result of TCEH’s credit rating being below investment grade, TCEH is required to post collateral support in an amount equal to estimated transition charges over specified time periods. Accordingly, at both December 31, 201 4 and 201 3 , TCEH had posted letters of credit each in the amount of $ 9 million for our benefit. · Under Texas regulatory provisions, the trust fund for decommissioning TCEH’s Comanche Peak nuclear generation facility is funded by a delivery fee surcharge we collect from REPs and remit monthly to TCEH. Delivery fee surcharges totaled $17 million for the year ended December 31, 2014 and $ 16 million for each of the years ended December 31, 2013 and 2012. Our sole obligation with regard to nuclear decommissioning is as the collection agent of funds charged to ratepayers for nuclear decommissioning activities. If, at the time of decommissioning , actual decommissioning costs exceed available trust funds, we would not be obligated to pay any shortfalls but would be required to collect any rates approved by the PUCT to recover any additional decommissioning costs. Further, if there were to be a surplus when decommissioning is complete, such surplus would be returned to ratepayers under terms prescribed by the PUCT. · Prior to August 2012, we recognized interest income from TCEH under an agreement related to our generation-related regulatory assets, which have been securitized through the issuance of transition bonds by Bondco. This interest income, which served to offset our interest expense on the transition bonds, totaled $ 16 million for the year ended December 31, 2012. Also prior to August 2012, we received reimbursement under a note receivable from TCEH for incremental amounts payable related to income taxes as a result of delivery fee surcharges related to the transition bonds. Amounts received under the note receivable for the year ended December 31, 2012 totaled $ 20 million. In August 2012, we sold to EFIH all future interest reimbursements and the remaining $ 159 million obligation under the note with TCEH. As a result, EFIH paid, and we received, an aggregate $ 159 million for the agreements. The sale of the related-party agreements was reported as a $ 2 million (after tax) decrease in total membership interests in 2012 in accordance with accounting rules for related-party transactions. · In connection with assuming sponsorship of the Oncor Retirement Plan in 2012, we entered into an agreement with EFH Corp. to assume primary responsibility for retirement benefits of a closed group of retired and terminated vested retirement plan participants not related to our regulated utility business . As the Oncor Retirement Plan received an amount of plan assets equal to the liabilities we assumed for those participants, execution of the agreement did not have a material impact on our reported results of operations or financial condition. See Note 10 for further information regarding funding for the pension plans. · Affiliates of the Sponsor Group have (1) sold, acquired or participated in the offerings of our debt or debt securities in open market transactions or through loan syndications, and (2) performed various financial advisory, dealer, commercial banking and investment banking services for us and certain of our affiliates for which they have received or will receive customary fees and expenses, and may from time to time in the future participate in any of the items in (1) and (2) above. See Notes 4 , 9 and 10 for information regarding the tax sharing agreement, distributions to members and our participation in EFH Corp. pension and OPEB plans, respectively.

Supplementary Financial Informa

Supplementary Financial Information	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Supplementary Financial Information [Abstract]
SUPPLEMENTARY FINANCIAL INFORMATION	11. SUPPLEMENTARY FINANCIAL INFORMATION Major Customers Revenues from TCEH represented 24% and 25% of our total operating revenues for the three months ended June 30, 2015 and 2014, respectively, and 24% and 25% for the six months ended June 30, 2015 and 2014, respectively. Revenues from REP subsidiaries of NRG Energy, Inc., a nonaffiliated entity, collectively represented 15% and 16% of our total operating revenues for the three months ended June 30, 2015 and 2014, respectively, and 16% of our total operating revenues for each of the six-month periods ended June 30, 2015 and 2014. No other customer represented 10% or more of our total operating revenues. Other Income and Deductions Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Other income: Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting $ $ $ $ Other - - - Total other income $ $ $ $ Other deductions: Professional fees $ $ $ $ Other - - Total other deductions $ $ $ $ Interest Expense and Related Charges Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Interest expense $ $ $ $ Amortization of debt issuance costs and discounts Allowance for funds used during construction – capitalized interest portion Total interest expense and related charges $ $ $ $ Restricted Cash All restricted cash amounts reported on our balance sheet at June 30, 2015 and December 31, 2014 relate to the transition bonds. Trade Accounts and Other Receivables Trade accounts and other receivables reported on our balance sheet consisted of the following: At June 30, At December 31, 2015 2014 Gross trade accounts and other receivables $ $ Trade accounts and other receivables from affiliates Allowance for uncollectible accounts Trade accounts receivable from nonaffiliates – net $ $ Gross trade accounts receivable at June 30, 2015 and December 31, 2014 included unbilled revenues of $192 million and $182 million, respectively. At June 30, 2015 and December 31, 2014, REP subsidiaries of NRG Energy, Inc., a nonaffiliated entity, collectively represented approximately 13% and 12% of the nonaffiliated trade accounts receivable amount, respectively. Under a PUCT rule relating to the Certification of Retail Electric Providers, write-offs of uncollectible amounts owed by REPs are deferred as a regulatory asset. Due to commitments made to the PUCT in 2007, we are not allowed to recover bad debt expense, or certain other costs and expenses, from ratepayers in the event of a default or bankruptcy by an affiliate REP. Investments and Other Property Investments and other property reported on our balance sheet consisted of the following: At June 30, At December 31, 2015 2014 Assets related to employee benefit plans, including employee savings programs $ $ Land Total investments and other property $ $ Property, Plant and Equipment Property, plant and equipment reported on our balance sheet consisted of the following: At June 30, At December 31, 2015 2014 Total assets in service $ $ Less accumulated depreciation Net of accumulated depreciation Construction work in progress Held for future use Property, plant and equipment – net $ $ Intangible Assets Intangible assets (other than goodwill) reported on our balance sheet consisted of the following: At June 30, 2015 At December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Net Amount Amortization Net Identifiable intangible assets subject to amortization included in property, plant and equipment: Land easements $ $ $ $ $ $ Capitalized software Total $ $ $ $ $ $ A ggregate amortization expense for intangible assets totaled $16 million and $14 million for the three months ended June 30, 2015 and 2014, respectively, and $32 and $28 for the six months ended June 30, 2015 and 2014, respectively. The estimated aggregate amortization expense for each of the next five fiscal years is as follows: Year Amortization Expense 2015 $ 2016 2017 2018 2019 At both June 30, 2015 and December 31, 2014, goodwill totaling $4.1 billion was reported on our balance sheet. None of this goodwill is being deducted for tax purposes. Other Noncurrent Liabilities and Deferred Credits Other noncurrent liabilities and deferred credits reported on our balance sheet consisted of the following: At June 30, At December 31, 2015 2014 Retirement plans and other employee benefits $ $ Uncertain tax positions (including accrued interest) Amount payable related to income taxes Investment tax credits Other Total other noncurrent liabilities and deferred credits $ $ Supplemental Cash Flow Information Six Months Ended June 30, 2015 2014 Cash payments (receipts) related to: Interest $ $ Capitalized interest Interest (net of amounts capitalized) $ $ Amount in lieu of income taxes (a): Federal $ - $ State Total amount in lieu of income taxes $ $ Noncash construction expenditures (b) $ $ _____________ (a) See Note 10 for income tax detail. (b) Represents end-of-period accruals .	13 . SUPPLEMENTARY FINANCIAL INFORMATION Variable Interest Entities We are the primary beneficiary and consolidate a wholly-owned VIE, Bondco, which was organized for the limited purpose of issuing specific transition bonds and purchasing and owning transition property acquired from us that is pledged as collateral to secure the bonds. We act as the servicer for this entity to collect transition charges authorized by the PUCT. These funds are remitted to the trustee and used for interest and principal payments on the transition bonds and related costs. The material assets and liabilities of Bondco are presented separately on the face of our Consolidated Balance Sheet because the assets are restricted and can only be used to settle the obligations of Bondco, and Bondco’s creditors do not have recourse to our general credit or assets. Our maximum exposure does not exceed our equity investment in Bondco, which was $ 16 million at both December 31, 2014 and 2013. We did not provide any financial support to Bondco during the years ended December 31, 2014 and 2013. Major Customers Revenues from TCEH represented 25 %, 27 % and 29 % of our total operating revenues for the years ended December 31, 2014, 2013 and 2012, respectively. Revenues from REP subsidiaries of a nonaffiliated entity, collectively represented 16% of total operating revenues for the year ended December 31, 2014 and 15% of total operating revenues for each of the years ended December 31, 2013 and 2012. No other customer represented 10 % or more of our total operating revenues. Other Income and Deductions Year Ended December 31, 2014 2013 2012 Other income: Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting $ $ $ Net gain on sale of other properties and investments Total other income $ $ $ Other deductions: Professional fees $ $ $ SARs exercise (Note 11) - Other Total other deductions $ $ $ Interest Expense and Related Charges Year Ended December 31, 2014 2013 2012 Interest expense $ $ $ Amortization of debt issuance costs and discounts Allowance for funds used during construction – capitalized interest portion Total interest expense and related charges $ $ $ Restricted Cash Restricted cash amounts reported on our balance sheet consisted of the following: At December 31, 2014 At December 31, 2013 Current Assets Noncurrent Assets Current Assets Noncurrent Assets Customer collections related to transition bonds used only to service debt and pay expenses $ $ - $ $ - Reserve for fees associated with transition bonds - - Reserve for shortfalls of transition bond charges - - Total restricted cash $ $ $ $ Trade Accounts Receivable Trade accounts receivable reported on our balance sheet consisted of the following: At December 31, 2014 2013 Gross trade accounts receivable $ $ Trade accounts receivable from TCEH Allowance for uncollectible accounts Trade accounts receivable from nonaffiliates – net $ $ Gross trade accounts receivable at December 31, 2014 and 2013 included unbilled revenues of $ 182 million and $ 180 million, respectively. At both December 31, 2014 and 2013, REP subsidiaries of a nonaffiliated entity collectively represented approximately 12 % of the nonaffiliated trade accounts receivable amount. Under a PUCT rule relating to the Certification of Retail Electric Providers, write-offs of uncollectible amounts owed by REPs are deferred as a regulatory asset. Due to commitments made to the PUCT in 2007, we are not allowed to recover bad debt expense, or certain other costs and expenses, from ratepayers in the event of a default or bankruptcy by an affiliate REP. Investments and Other Property Investments and other property reported on our balance sheet consisted of the following: At December 31, 2014 2013 Assets related to employee benefit plans, including employee savings programs $ $ Land Total investments and other property $ $ The majority of these assets represent cash surrender values of life insurance policies that are purchased to fund liabilities under deferred compensation plans. At December 31, 2014 and 2013, the face amount of these policies totaled $167 million and $159 million, respectively, and the net cash surrender values (determined using a Level 2 valuation technique) totaled $76 million and $71 million, respectively. Changes in cash surrender value are netted against premiums paid. Other investment assets held to satisfy deferred compensation liabilities are recorded at market value. Property, Plant and Equipment Property, plant and equipment reported on our balance sheet consisted of the following: Composite Depreciation Rate/ At December 31, Avg. Life at December 31, 2014 2014 2013 Assets in service: Distribution 4.1% / 24.6 years $ $ Transmission 2.8% / 35.7 years Other assets 9.2% / 10.9 years Total Less accumulated depreciation Net of accumulated depreciation Construction work in progress Held for future use Property, plant and equipment – net $ $ Depreciation expense as a percent of average depreciable property approximated 3.6% , 3.7% and 3.9% for the years ended December 31, 2014, 2013 and 2012, respectively. Intangible Assets Intangible assets (other than goodwill) reported on our balance sheet consisted of the following: At December 31, 2014 At December 31, 2013 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Net Amount Amortization Net Identifiable intangible assets subject to amortization included in property, plant and equipment: Land easements $ $ $ $ $ $ Capitalized software Total $ $ $ $ $ $ A ggregate amortization expense for intangible assets totaled $ 58 million , $53 million and $53 million for each of the years ended December 31, 2014, 2013 and 2012 , respectively . At December 31, 2014, the weighted average remaining useful lives of capitalized land easements and software were 85 years and 3 years, respectively. The estimated aggregate amortization expense for each of the next five fiscal years is as follows: Year Amortization Expense 2015 $ 2016 2017 2018 2019 At both December 31, 201 4 and 201 3 , goodwill totaling $ 4.1 billion was reported on our balance sheet. None of this goodwill is being deducted for tax purposes. See Note 1 regarding goodwill impairment assessment and testing. Other Noncurrent Liabilities and Deferred Credits Other noncurrent liabilities and deferred credits reported on our balance sheet consisted of the following: At December 31, 2014 2013 Retirement plans and other employee benefits $ $ Uncertain tax positions (including accrued interest) Amount payable related to income taxes Investment tax credits Other Total other noncurrent liabilities and deferred credits $ $ Supplemental Cash Flow Information Year Ended December 31, 2014 2013 2012 Cash payments (receipts) related to: Interest $ $ $ Capitalized interest Interest (net of amounts capitalized) $ $ $ Amount in lieu of income taxes: Federal $ $ $ State Total amount in lieu of income taxes $ $ $ SARs exercise - Noncash construction expenditures (a) ______________ (a) Represents end-of-period accruals. Quarterly Information (unaudited) Results of operations by quarter for the years ended December 31, 2014 and 2013 are summarized below. In our opinion, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of such amounts have been made. Quarterly results are not necessarily indicative of a full year’s operations because of seasonal and other factors. 2014 First Quarter Second Quarter Third Quarter Fourth Quarter Operating revenues $ $ $ $ Operating income Net income 2013 First Quarter Second Quarter Third Quarter Fourth Quarter Operating revenues $ $ $ $ Operating income Net income

Description Of Business and S23

Description Of Business and Significant Accounting Policies (Policies)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Description Of Business and Significant Accounting Policies [Abstract]
Description Of Business	Description of Business References in this report to “we,” “our,” “us” and “the company” are to Oncor and/or its subsidiary as apparent in the context. See “Glossary” for definition of terms and abbreviations. We are a regulated electricity transmission and distribution company principally engaged in providing delivery services to REPs, including subsidiaries of TCEH, that sell power in the north-central, eastern and western parts of Texas. Revenues from TCEH represented 24% and 25% of our total operating revenues for the six months ended June 30, 2015 and 2014, respectively. We are a direct, majority-owned subsidiary of Oncor Holdings, which is a direct, wholly-owned subsidiary of EFIH, a direct, wholly-owned subsidiary of EFH Corp. EFH Corp. is a subsidiary of Texas Holdings, which is controlled by the Sponsor Group. Oncor Holdings owns 80.03% of our membership interests, Texas Transmission owns 19.75% of our membership interests and certain members of our management team and board of directors indirectly own the remaining membership interests through Investment LLC. We are managed as an integrated business; consequently, there are no separate reportable business segments. Our consolidated financial statements include our wholly-owned, bankruptcy-remote financing subsidiary, Bondco, a variable interest entity . This financing subsidiary was organized for the limited purpose of issuing certain transition bonds in 2003 and 2004. Bondco issued $1.3 billion principal amount of transition bonds to recover generation-related regulatory asset stranded costs and other qualified costs under an order issued by the PUCT in 2002. Various “ring-fencing” measures have been taken to enhance the separateness between the Oncor Ring-Fenced Entities and the Texas Holdings Group and our credit quality. These measures serve to mitigate our and Oncor Holdings’ credit exposure to the Texas Holdings Group and to reduce the risk that our assets and liabilities or those of Oncor Holdings would be substantively consolidated with the assets and liabilities of the Texas Holdings Group in connection with a bankruptcy of one or more of those entities, including the EFH Bankruptcy Proceedings discussed below. Such measures include, among other things: our sale of a 19.75% equity interest to Texas Transmission in November 2008; maintenance of separate books and records for the Oncor Ring-Fenced Entities; our board of directors being comprised of a majority of independent directors; and prohibitions on the Oncor Ring-Fenced Entities providing credit support to, or receiving credit support from, any member of the Texas Holdings Group. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of the Texas Holdings Group, including TXU Energy and Luminant, and none of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or contractual obligations of any member of the Texas Holdings Group. We do not bear any liability for debt or contractual obligations of the Texas Holdings Group, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from the Texas Holdings Group.	Description of Business References in this report to “we,” “our,” “us” and “the company” are to Oncor and/or its subsidiary as apparent in the context. See “Glossary” for definition of terms and abbreviations. We are a regulated electricity transmission and distribution company principally engaged in providing delivery services to REPs, including subsidiaries of TCEH, that sell power in the north-central, eastern and western parts of Texas. Revenues from TCEH represented 25 %, 27 % and 29 % of our total operating revenues for the years ended December 31, 2014, 2013 and 2012, respectively. We are a direct, majority-owned subsidiary of Oncor Holdings, which is a direct, wholly-owned subsidiary of EFIH, a direct, wholly-owned subsidiary of EFH Corp. EFH Corp. is a subsidiary of Texas Holdings, which is controlled by the Sponsor Group. Oncor Holdings owns 80.03 % of our membership interests, Texas Transmission owns 19.75 % of our membership interests and certain members of our management team and board of directors indirectly own the remaining membership interests through Investment LLC. We are managed as an integrated business; consequently, there are no separate reportable business segments. Our consolidated financial statements include our wholly-owned, bankruptcy-remote financing subsidiary, Bondco, a VIE (see Note 13) . This financing subsidiary was organized for the limited purpose of issuing certain transition bonds to recover generation-related regulatory asset stranded costs and other qualified costs under an order issued by the PUCT in 2002. Bondco issued an aggregate $ 1.3 billion principal amount of transition bonds during 2003 and 2004. At December 31, 2014, $ 180 million principal amount of transition bonds (maturing in 2015 and 2016) was outstanding (see Note 7). Various “ring-fencing” measures have been taken to enhance the separateness between the Oncor Ring-Fenced Entities and the Texas Holdings Group and our credit quality. These measures serve to mitigate our and Oncor Holdings’ credit exposure to the Texas Holdings Group and to reduce the risk that our assets and liabilities or those of Oncor Holdings would be substantively consolidated with the assets and liabilities of the Texas Holdings Group in connection with a bankruptcy of one or more of those entities , including the EFH Bankruptcy Proceedings discussed below . Such measures include, among other things: our sale of a 19.75% equity interest to Texas Transmission in November 2008; maintenance of separate books and records for the Oncor Ring-Fenced Entities; our board of directors being comprised of a majority of independent directors; and prohibitions on the Oncor Ring-Fenced Entities providing credit support to, or receiving credit support from, any member of the Texas Holdings Group. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of the Texas Holdings Group, including TXU Energy and Luminant, and none of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or contractual obligations of any member of the Texas Holdings Group. We do not bear any liability for debt or contractual obligations of the Texas Holdings Group, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from the Texas Holdings Group.
EFH Corp. Bankruptcy Proceedings	EFH Corp. Bankruptcy Proceedings On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. The Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. We believe the “ring-fencing” measures discussed above mitigate our potential exposure to the EFH Bankruptcy Proceedings. See Note 2 for a discussion of the potential impacts of the EFH Bankruptcy Proceedings on our financial statements.	EFH Bankruptcy Proceedings On the EFH Petition Date, EFH Corp. and the substantial majority of its direct and indirect subsidiaries that are members of the Texas Holdings Group, including EFIH, EFCH and TCEH, commenced proceedings under Chapter 11 of the US Bankruptcy Code. The Oncor Ring-Fenced Entities are not parties to the EFH Bankruptcy Proceedings. We believe the “ring-fencing” measures discussed above mitigate our potential exposure to the EFH Bankruptcy Proceedings. See Note 2 for a discussion of the potential impacts of the EFH Bankruptcy Proceedings on our financial statements.
Basis Of Presentation	Basis of Presentation Our condensed consolidated financial statements have been prepared in accordance with US GAAP and on the same basis as the audited financial statements in our 2014 Form 10-K. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. Certain information and footnote disclosures normally included in annual consolidated financial statements prepared in accordance with US GAAP have been omitted pursuant to the rules and regulations of the SEC . Because the condensed consolidated interim financial statements do not include all of the information and footnotes required by US GAAP, they should be read in conjunction with the audited financial statements and related notes in our 2014 Form 10-K. The results of operations for an interim period may not give a true indication of results for a full year due to seasonality. All dollar amounts in the financial statements and tables in the notes are stated in millions of US dollars unless otherwise indicated.	Basis of Presentation Our consolidated financial statements have been prepared in accordance with US GAAP and on the same basis as the audited financial statements in our Annual Report on Form 10-K for the year ended December 31, 2013. Adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been included therein. All intercompany items and transactions have been eliminated in consolidation. All dollar amounts in the financial statements and tables in the notes are stated in millions of US dollars unless otherwise indicated.
Consolidation Of Variable Interest Entities		Consolidation of Variable Interest Entities A VIE is an entity with which we have a relationship or arrangement that indicates some level of control over the entity or results in economic risks to us. We consolidate a VIE if we have: a) the power to direct the significant activities of the VIE and b) the right or obligation to absorb profit and loss from the VIE (primary beneficiary). See Note 13.
Income Taxes		Income Taxes Effective with the November 2008 sale of equity interests to Texas Transmission and Investment LLC, we became a partnership for US federal income tax purposes, and subsequently we are not a member of EFH Corp.’s consolidated tax group and only EFH Corp.’s share of our partnership income is included in its consolidated federal income tax return. Our tax sharing agreement with Oncor Holdings and EFH Corp. was amended in November 2008 to include Texas Transmission and Investment LLC. The tax sharing agreement provides for the calculation of tax liability substantially as if we and Oncor Holdings were taxed as corporations, and requires tax payments to members determined on that basis (without duplication for any income taxes paid by a subsidiary of Oncor Holdings). While partnerships are not subject to income taxes, in consideration of the tax sharing agreement and the presentation of our financial statements as an entity subject to cost-based regulatory rate-setting processes, with such costs including income taxes, the financial statements present amounts determined under the tax sharing agreement as “provision in lieu of income taxes” and “liability in lieu of deferred income taxes” for periods subsequent to the sales of equity interests discussed in Note 4. Such amounts are determined in accordance with the provisions of accounting guidance for income taxes and for uncertainty in income taxes and thus differences between the book and tax bases of assets and liabilities are accounted for as if we were taxed as a corporation. The accounting guidance for rate-regulated enterprises requires the recognition of regulatory assets or liabilities if it is probable such deferred tax amounts will be recovered from, or returned to customers in future rates. Investment tax credits are amortized to income over the estimated lives of the related properties. We classify interest and penalties expense related to uncertain tax positions as current provision in lieu of income taxes as discussed in Note 4.
Use Of Estimates	Use of Estimates Preparation of our financial statements requires management to make estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information.	Use of Estimates Preparation of our financial statements requires management to make estimates and assumptions about future events that affect the reporting of assets and liabilities at the balance sheet dates and the reported amounts of revenue and expense, including fair value measurements. In the event estimates and/or assumptions prove to be different from actual amounts, adjustments are made in subsequent periods to reflect more current information. No material adjustments were made to previous estimates or assumptions during the current year.
Derivative Instruments And Mark-To-Market Accounting	Derivative Instruments and Mark-to-Market Accounting We have from time-to-time entered into derivative instruments to hedge interest rate risk. If the instrument meets the definition of a derivative under accounting standards related to derivative instruments and hedging activities, the fair value of each derivative is recognized on the balance sheet as a derivative asset or liability and changes in the fair value are recognized in net income, unless criteria for certain exceptions are met. This recognition is referred to as “mark-to-market” accounting.	Derivative Instruments and Mark-to-Market Accounting We have from time-to-time entered into derivative instruments to hedge interest rate risk. If the instrument meets the definition of a derivative under accounting standards related to derivative instruments and hedging activities, the fair value of each derivative is recognized on the balance sheet as a derivative asset or liability and changes in the fair value are recognized in net income, unless criteria for certain exceptions are met. This recognition is referred to as “mark-to-market” accounting.
Reconcilable Tariffs	Reconcilable Tariffs The PUCT has designated certain tariffs (TCRF, EECRF surcharges, AMS surcharges and charges related to transition bonds) as reconcilable, which means the differences between amounts billed under these tariffs and the related incurred costs are deferred as either regulatory assets or regulatory liabilities. Accordingly, at prescribed intervals, future tariffs are adjusted to either repay regulatory liabilities or collect regulatory assets.	Reconcilable Tariffs The PUCT has designated certain tariffs (TCRF, EECRF surcharges, AMS surcharges and charges related to transition bonds) as reconcilable, which means the differences between amounts billed under these tariffs and the related incurred costs are deferred as either regulatory assets or regulatory liabilities. Accordingly, at prescribed intervals, future tariffs are adjusted to either repay regulatory liabilities or collect regulatory assets.
Revenue Recognition		Revenue Recognition R evenue includes an estimate for electricity delivery services provided from the billed meter reading date to the end of the period (unbilled revenue). For electricity delivery services billed on the basis of kWh volumes, unbilled revenue is based on data collected through our AMS. For other electricity delivery services, unbilled revenue is based on average daily revenues for the most recent period applied to the number of unmetered days through the end of the period.
Impairment Of Long-Lived Assets And Goodwill		Impairment of Long-Lived Assets and Goodwill We evaluate long-lived assets (including intangible assets with finite lives) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. We also evaluate goodwill for impairment annually (at December 1) and whenever events or changes in circumstances indicate that an impairment may exist. The determination of the existence of these and other indications of impairment involves judgments that are subjective in nature and may require the use of estimates in forecasting future results and cash flows. If at the assessment date our carrying value exceeds our estimated fair value (enterprise value), then the estimated enterprise value is compared to the estimated fair values of our operating assets (including identifiable intangible assets) and liabilities at the assessment date. The resultant implied goodwill amount is compared to the recorded goodwill amount. Any excess of the recorded goodwill amount over the implied goodwill amount is written off as an impairment charge. The goodwill impairment test performed in 2014 was based on a qualitative assessment in which we considered macroeconomic conditions, industry and market considerations, cost factors, overall financial performance and other relative factors. Goodwill impairment tests performed in 2013 and 2012 were based on determinations of enterprise value using discounted cash flow analyses, comparable company equity values and any relevant transactions indicative of enterprise values (quantitative assessment). Based on tests results, no impairments were recognized in 2014, 2013 or 2012 .
System Of Accounts		System of Accounts Our accounting records have been maintained in accordance with the FERC Uniform System of Accounts as adopted by the PUCT.
Defined Benefit Pension Plans And OPEB Plans		Defined Benefit Pension Plans and OPEB Plans We have liabilities under pension plans that offer benefits based on either a traditional defined benefit formula or a cash balance formula and an OPEB plan that offers certain health care and life insurance benefits to eligible employees and their eligible dependents upon the retirement of such employees from the company. Costs of pension and OPEB plans are dependent upon numerous factors, assumptions and estimates. In 2012, EFH Corp. made various changes to the EFH Retirement Plan, including splitting off into a new plan all of the assets and liabilities associated with Oncor employees and all retirees and terminated vested participants of EFH Corp. and its subsidiaries (including discontinued businesses). See Note 10 for additional information regarding pension and OPEB plans.
Contingencies	Contingencies We evaluate and account for contingencies using the best information available. A loss contingency is accrued and disclosed when it is probable that an asset has been impaired or a liability incurred and the amount of the loss can be reasonably estimated. If a range of probable loss is established, the minimum amount in the range is accrued, unless some other amount within the range appears to be a better estimate. If the probable loss cannot be reasonably estimated, no accrual is recorded, but the loss contingency is disclosed to the effect that the probable loss cannot be reasonably estimated. A loss contingency will be disclosed when it is reasonably possible that an asset has been impaired or a liability incurred. If the likelihood that an impairment or incurrence is remote, the contingency is neither accrued nor disclosed. Gain contingencies are recognized upon realization.	Contingencies We evaluate and account for contingencies using the best information available. A loss contingency is accrued and disclosed when it is probable that an asset has been impaired or a liability incurred and the amount of the loss can be reasonably estimated. If a range of probable loss is established, the minimum amount in the range is accrued, unless some other amount within the range appears to be a better estimate. If the probable loss cannot be reasonably estimated, no accrual is recorded, but the loss contingency is disclosed to the effect that the probable loss cannot be reasonably estimated. A loss contingency will be disclosed when it is reasonably possible that an asset has been impaired or a liability incurred. If the likelihood that an impairment or incurrence is remote, the contingency is neither accrued nor disclosed. Gain contingencies are recognized upon realization.
Fair Value Of Nonderivative Financial Instruments		Fair Value of Nonderivative Financial Instruments The carrying amounts for financial assets classified as current assets and the carrying amounts for financial liabilities classified as current liabilities approximate fair value due to the short maturity of such instruments. The fair values of other financial instruments, for which carrying amounts and fair values have not been presented, are not materially different than their related carrying amounts. The following discussion of fair value accounting standards applies primarily to our determination of the fair value of assets in the pension and OPEB plans trusts (see Note 10) and long-term debt (see Note 7). Accounting standards related to the determination of fair value define fair value 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. We use a “mid-market” valuation convention (the mid-point price between bid and ask prices) as a practical expedient to measure fair value for the majority of our assets and liabilities subject to fair value measurement on a recurring basis. We primarily use the market approach for recurring fair value measurements and use valuation techniques to maximize the use of observable inputs and minimize the use of unobservable inputs. We categorize our assets and liabilities recorded at fair value based upon the following fair value hierarchy: · Level 1 valuations use quoted prices in active markets for identical assets or liabilities that are accessible at the measurement date. An active market is a market in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. · Level 2 valuations use inputs that, in the absence of actively quoted market prices, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include: (a) quoted prices for similar assets or liabilities in active markets, (b) quoted prices for identical or similar assets or liabilities in markets that are not active, (c) inputs other than quoted prices that are observable for the asset or liability such as interest rates and yield curves observable at commonly quoted intervals and (d) inputs that are derived principally from or corroborated by observable market data by correlation or other means. Our Level 2 valuations utilize over-the-counter broker quotes, quoted prices for similar assets or liabilities that are corroborated by correlations or other mathematical means and other valuation inputs. · Level 3 valuations use unobservable inputs for the asset or liability. Unobservable inputs are used to the extent observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at the measurement date. We use the most meaningful information available from the market combined with internally developed valuation methodologies to develop our best estimate of fair value. We utilize several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those items that are measured on a recurring basis.
Franchise Taxes		Franchise Taxes Franchise taxes are assessed to us by local governmental bodies, based on kWh delivered and are the principal component of taxes other than amounts related to income taxes as reported in the income statement. Franchise taxes are not a “pass through” item. The rates we charge customers are intended to recover the franchise taxes, but we are not acting as an agent to collect the taxes from customers.
Cash And Cash Equivalents		Cash and Cash Equivalents For purposes of reporting cash and cash equivalents, temporary cash investments purchased with a remaining maturity of three months or less are considered to be cash equivalents. See Note 13 for details regarding restricted cash.
Property, Plant And Equipment		Property, Plant and Equipment Properties are stated at original cost. The cost of self-constructed property additions includes materials and both direct and indirect labor and applicable overhead and an allowance for funds used during construction. D epreciation of property, plant and equipment is calculated on a straight-line basis over the estimated service lives of the properties based on depreciation rates approved by the PUCT. As is common in the industry, depreciation expense is recorded using composite depreciation rates that reflect blended estimates of the lives of major asset groups as compared to depreciation expense calculated on a component asset-by-asset basis. Depreciation rates include plant removal costs as a component of depreciation expense, consistent with regulatory treatment. Actual removal costs incurred are charged to accumulated depreciation. When accrued removal costs exceed incurred removal costs, the difference is reclassified as a regulatory obligation to retire assets in the future.
Allowance For Funds Used During Construction (AFUDC)		Allowance for Funds Used During Construction (AFUDC) AFUDC is a regulatory cost accounting procedure whereby both interest charges on borrowed funds and a return on equity capital used to finance construction are included in the recorded cost of utility plant and equipment being constructed. AFUDC is capitalized on all projects involving construction periods lasting greater than thirty days. The equity portion of capitalized AFUDC is accounted for as other income. We recorded no equity AFUDC in the years ended December 31, 2014 and 2013 and $ 1 million in the year ended December 31, 2012. See Note 13 for detail of amounts charged to interest expense.
Regulatory Assets And Liabilities		Regulatory Assets and Liabilities Our financial statements reflect regulatory assets and liabilities under cost-based rate regulation in accordance with accounting standards related to the effect of certain types of regulation. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital and the timing and amount of assets to be recovered by rates. See Note 5 for details of regulatory assets and liabilities.
Changes In Accounting Standards	Changes in Accounting Standards In April 2015, the Financial Accounting Standards Board issued a new accounting standard update, which changes the presentation of debt issuance costs in the balance sheet. The update requires that such costs be presented as a direct reduction to the face value of the related debt rather than as an asset. This will make the presentation of debt issuance costs consistent with debt discounts. The update is effective for interim and annual periods beginning after December 15, 2015. Early application is permitted. When adopted, we anticipate that both other noncurrent assets and long-term debt amounts will decrease by approximately $40 million.	Changes in Accounting Standards In May 2014, the Financial Accounting Standards Board issued Accounting Standards Update No. 2014-09 (ASU 2014-09), Revenue from Contracts with Customers . ASU 2014-09 introduces new, increased requirements for disclosure of revenue in financial statements and is intended to eliminate inconsistencies in revenue recognition and thereby improve financial reporting comparability across entities, industries and capital markets. ASU 2014-09 is effective for annual reporting periods (including interim reporting periods within those periods) beginning after December 15, 2016 for public entities. Early application is not permitted. We are currently evaluating the potential impact of ASU 2014-09. The adoption of ASU 2014-09 is not expected to have a material effect on our reported results of operations, financial condition or cash flows.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Taxes [Abstract]
Components Of Income Tax Provisions (Benefits)	Year Ended December 31, 2014 2013 2012 Reported in operating expenses: Current: US federal $ $ $ State Deferred: US federal State - - Amortization of investment tax credits Total reported in operating expenses Reported in other income and deductions: Current: US federal State - - - Deferred federal Total reported in other income and deductions Total provision in lieu of income taxes $ $ $
Schedule Of Income Tax Reconciliation	Year Ended December 31, 2014 2013 2012 Income before provision in lieu of income taxes $ $ $ Provision in lieu of income taxes at the US federal statutory rate of 35% $ $ $ Amortization of investment tax credits – net of deferred tax effect Amortization (under regulatory accounting) of statutory tax rate changes Amortization of Medicare subsidy regulatory asset Texas margin tax, net of federal tax benefit Nondeductible losses (gains) on benefit plan investments Other, including audit settlements - Reported provision in lieu of income taxes $ $ $ Effective rate
Schedule Of Changes To Uncertain Tax Positions	2014 2013 2012 Balance at January 1, excluding interest and penalties $ $ $ Additions based on tax positions related to prior years - - Reductions based on tax positions related to prior years - Settlements with taxing authorities - Balance at December 31, excluding interest and penalties $ $ $

Regulatory Assets and Liabili25

Regulatory Assets and Liabilities (Tables)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Regulatory Assets and Liabilities [Abstract]
Components Of Regulatory Assets And Liabilities	Remaining Rate Recovery/Amortization Period at Carrying Amount At June 30, 2015 June 30, 2015 December 31, 2014 Regulatory assets: Generation-related regulatory assets securitized by transition bonds (a)(e) 1 year $ $ Employee retirement costs 5 years Employee retirement costs to be reviewed (b)(c) To be determined Employee retirement liability (a)(c)(d) To be determined Self-insurance reserve (primarily storm recovery costs) ― net 5 years Self-insurance reserve to be reviewed ― net (b)(c) To be determined Securities reacquisition costs (pre-industry restructure) 2 years Securities reacquisition costs (post-industry restructure) ― net Terms of related debt Recoverable amounts in lieu of deferred income taxes ― net Life of related asset or liability Deferred conventional meter and metering facilities depreciation Largely 5 years Deferred AMS costs To be determined Energy efficiency performance bonus (a) 1 year Under-recovered wholesale transmission service expense ― net (a) 1 year Other regulatory assets Various Total regulatory assets Regulatory liabilities: Estimated net removal costs Life of utility plant Investment tax credit and protected excess deferred taxes Various Over-collection of transition bond revenues (a)(e) 1 year Energy efficiency programs (a) Not applicable Total regulatory liabilities Net regulatory asset $ $ ____________ (a) Not earning a return in the regulatory rate-setting process. (b) Costs incurred since the period covered under the last rate review. (c) Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review. (d) Represents unfunded liabilities recorded in accordance with pension and OPEB accounting standards. Bondco net regulatory assets of $47 million at June 30, 2015 consisted of $78 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $31 million. Bondco net regulatory assets of $108 million at December 31, 2014 consisted of $140 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $32 million.	Remaining Rate Recovery/Amortization Period at Carrying Amount At December 31, 2014 December 31, 2014 December 31, 2013 Regulatory assets: Generation-related regulatory assets securitized by transition bonds (a)(e) 1 year $ $ Employee retirement costs 5 years Employee retirement costs to be reviewed (b)(c) To be determined Employee retirement liability (a)(c)(d) To be determined Self-insurance reserve (primarily storm recovery costs) ― net 5 years Self-insurance reserve to be reviewed ― net (b)(c) To be determined Securities reacquisition costs (pre-industry restructure) 2 years Securities reacquisition costs (post-industry restructure) ― net Lives of related debt Recoverable amounts in lieu of deferred income taxes ― net Life of related asset or liability Deferred conventional meter and metering facilities depreciation Largely 6 years Deferred AMS costs To be determined Energy efficiency performance bonus (a) 1 year Under-recovered wholesale transmission service expense ― net (a) 1 year Other regulatory assets Various Total regulatory assets Regulatory liabilities: Estimated net removal costs Lives of related assets Investment tax credit and protected excess deferred taxes Various Over-collection of transition bond revenues (a)(e) 1 year Energy efficiency programs (a) Not applicable Total regulatory liabilities Net regulatory asset $ $ ____________ (a) Not earning a return in the regulatory rate-setting process. (b) Costs incurred since the period covered under the last rate review. (c) Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review. (d) Represents unfunded liabilities recorded in accordance with pension and OPEB accounting standards. Bondco net regulatory assets of $ 108 million at December 31, 2014 consisted of $ 140 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $ 32 million. Bondco net regulatory assets of $ 226 million at December 31, 2013 consisted of $ 261 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $ 35 million.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Long-Term Debt [Abstract]
Schedule Of Long-Term Debt	June 30, December 31, 2015 2014 Oncor (a): 6.375% Fixed Senior Notes due January 15, 2015 $ - $ 5.000% Fixed Senior Notes due September 30, 2017 6.800% Fixed Senior Notes due September 1, 2018 2.150% Fixed Senior Notes due June 1, 2019 5.750% Fixed Senior Notes due September 30, 2020 4.100% Fixed Senior Notes due June 1, 2022 7.000% Fixed Debentures due September 1, 2022 2.950% Fixed Senior Notes due April 1, 2025 - 7.000% Fixed Senior Notes due May 1, 2032 7.250% Fixed Senior Notes due January 15, 2033 7.500% Fixed Senior Notes due September 1, 2038 5.250% Fixed Senior Notes due September 30, 2040 4.550% Fixed Senior Notes due December 1, 2041 5.300% Fixed Senior Notes due June 1, 2042 3.750% Fixed Senior Notes due April 1, 2045 - Unamortized discount Less amount due currently - Long-term debt, less amounts due currently — Oncor Bondco (b): 5.420% Fixed Series 2003 Bonds due in semiannual installments through August 15, 2015 5.290% Fixed Series 2004 Bonds due in semiannual installments through May 15, 2016 Less amount due currently Long-term debt, less amounts due currently — Bondco - Total long-term debt, less amounts due currently $ $ __________ (a) Secured by first priority lien on certain transmission and distribution assets equally and ratably with all of Oncor’s other secured indebtedness. See “Deed of Trust” below for additional information. (b) The transition bonds are nonrecourse to Oncor and were issued to securitize a regulatory asset.	December 31, 2014 2013 Oncor (a): 6.375% Fixed Senior Notes due January 15, 2015 $ $ 5.000% Fixed Senior Notes due September 30, 2017 6.800% Fixed Senior Notes due September 1, 2018 2.150% Fixed Senior Notes due June 1, 2019 - 5.750% Fixed Senior Notes due September 30, 2020 4.100% Fixed Senior Notes due June 1, 2022 7.000% Fixed Debentures due September 1, 2022 7.000% Fixed Senior Notes due May 1, 2032 7.250% Fixed Senior Notes due January 15, 2033 7.500% Fixed Senior Notes due September 1, 2038 5.250% Fixed Senior Notes due September 30, 2040 4.550% Fixed Senior Notes due December 1, 2041 5.300% Fixed Senior Notes due June 1, 2042 Unamortized discount Less amount due currently - Long-term debt, less amounts due currently — Oncor Bondco (b): 5.420% Fixed Series 2003 Bonds due in semiannual installments through August 15, 2015 5.290% Fixed Series 2004 Bonds due in semiannual installments through May 15, 2016 Unamortized fair value discount related to transition bonds - Less amount due currently Long-term debt, less amounts due currently — Bondco Total long-term debt, less amounts due currently $ $ __________ (a) Secured by first priority lien on certain transmission and distribution assets equally and ratably with all of Oncor’s other secured indebtedness. See “Deed of Trust” below for additional information. (b) The transition bonds are nonrecourse to Oncor and were issued to securitize a regulatory asset.
Schedule Of Long-Term Debt Maturity		Year Amount 2015 $ 2016 2017 2018 2019 Thereafter Unamortized discount Total $

Commitments And Contingencies (

Commitments And Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies [Abstract]
Schedule Of Future Miinimum Lease Payments Under Operating Leases	Year Amount 2015 $ 2016 2017 2018 - 2019 - Thereafter - Total future minimum lease payments $

Membership Interests (Tables)

Membership Interests (Tables)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Membership Interests [Abstract]
Schedule Of Distributions Paid	Declaration Date Payment Date Amount April 29, 2015 May 15, 2015 $ February 25, 2015 February 26, 2015 $	During 2014, our board of directors declared, and we paid , the following cash distributions to our members: Declaration Date Payment Date Amount October 21, 2014 October 22, 2014 $ July 30, 2014 July 31, 2014 $ April 30, 2014 May 1, 2014 $ February 19, 2014 February 20, 2014 $ During 2013, our board of directors declared, and we paid , the following cash distributions to our members: Declaration Date Payment Date Amount October 29, 2013 October 31, 2013 $ July 31, 2013 August 1, 2013 $ May 1, 2013 May 2, 2013 $ February 13, 2013 February 15, 2013 $
Schedule Of Changes To Membership Interests	Capital Accounts Accumulated Other Comprehensive Income (Loss) Total Membership Interests Balance at December 31, 2014 $ $ $ Net income - Distributions - Net effects of cash flow hedges (net of tax) - Defined benefit pension plans (net of tax) - Balance at June 30, 2015 $ $ $ Capital Accounts Accumulated Other Comprehensive Income (Loss) Total Membership Interests Balance at December 31, 2013 $ $ $ Net income - Distributions - Net effects of cash flow hedges (net of tax) - Balance at June 30, 2014 $ $ $
Schedule Of Changes To Accumulated Other Comprehensive Income (Loss)	Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2014 $ $ $ Defined benefit pension plans (net of tax) - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at June 30, 2015 $ $ $ Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2013 $ $ $ Defined benefit pension plans (net of tax) - - - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at June 30, 2014 $ $ $	The following table presents the changes to accumulated other comprehensive income (loss) for the year ended December 31, 201 4 . Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2013 $ $ $ Defined benefit pension plans (net of tax) - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at December 31, 2014 $ $ $ The following table presents the changes to accumulated other comprehensive income (loss) for the year ended December 31, 201 3 . Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss) Balance at December 31, 2012 $ $ $ Defined benefit pension plans (net of tax) - Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges - Balance at December 31, 2013 $ $ $

Pension and Other Postretirem29

Pension and Other Postretirement Employee Benefits (OPEB) Plans (Tables)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Pension And OPEB Plan Costs	Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Components of net allocated pension costs: Service cost $ $ $ $ Interest cost Expected return on assets Amortization of net loss Net pension costs Components of net OPEB costs: Service cost Interest cost Expected return on assets Amortization of prior service cost Amortization of net loss Net OPEB costs Total net pension and OPEB costs Less amounts deferred principally as property or a regulatory asset Net amounts recognized as expense $ $ $ $	Year Ended December 31, 2014 2013 2012 Pension costs $ $ $ OPEB costs Total benefit costs Less amounts deferred principally as property or a regulatory asset Net amounts recognized as expense $ $ $
Schedule Of Detailed Pension And OPEB Benefit Information		Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2012 2014 2013 2012 Assumptions Used to Determine Net Periodic Pension and OPEB Costs: Discount rate (a) Expected return on plan assets Rate of compensation increase - - - Components of Net Pension and OPEB Costs: Service cost $ $ $ $ $ $ Interest cost Expected return on assets Amortization of net transition obligation - - - - - Amortization of prior service cost (credit) - - - Amortization of net loss Settlement charges - - - - Net periodic pension and OPEB costs $ $ $ $ $ $ Other Changes in Plan Assets and Benefit Obligations Recognized as Regulatory Assets or in Other Comprehensive Income: Net loss (gain) $ $ $ $ $ - $ Amortization of net loss Amortization of transition obligation (asset) - - - - - Amortization of prior service (cost) credit - - - Settlement charges - - - - Curtailment - - - - - Total recognized as regulatory assets or other comprehensive income Total recognized in net periodic pension and OPEB costs and as regulatory assets or other comprehensive income $ $ $ $ $ $ _______________ (a) As a result of the 2012 amendments discussed above, the discount rate reflected in net pension costs for January through July 2012 was 5.00 %, for August through September 2012 was 4.15 % and for October through December 2012 was 4.20 %. As a result of the transfer of OPEB plan assets and liabilities from the EFH OPEB Plan to the Oncor OPEB Plan discussed above, the discount rate reflected in OPEB costs for January through Ju ne 2014 was 4.98% and for July through December 2014 was 4.39% . Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2012 2014 2013 2012 Assumptions Used to Determine Benefit Obligations at Period End: Discount rate Rate of compensation increase - - - Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2014 2013 Change in Projected Benefit Obligation: Projected benefit obligation at beginning of year $ $ $ $ Service cost Interest cost Participant contributions - - Medicare Part D reimbursement - - - Settlement charges - - - Actuarial (gain) loss Benefits paid Projected benefit obligation at end of year $ $ $ $ Accumulated benefit obligation at end of year $ $ $ - $ - Change in Plan Assets: Fair value of assets at beginning of year $ $ $ $ Actual return (loss) on assets Employer contributions Settlement charges - - - Participant contributions - - Benefits paid Fair value of assets at end of year $ $ $ $ Funded Status: Projected benefit obligation at end of year $ $ $ $ Fair value of assets at end of year Funded status at end of year $ $ $ $ Pension Plans OPEB Plan Year Ended December 31, Year Ended December 31, 2014 2013 2014 2013 Amounts Recognized in the Balance Sheet Consist of: Liabilities: Other current liabilities $ $ $ - $ - Other noncurrent liabilities Net liability recognized $ $ $ $ Regulatory assets: Net loss $ $ $ $ Prior service cost (credit) - - Net regulatory asset recognized $ $ $ $ Accumulated other comprehensive net loss $ $ $ $
Schedule Of Assumed Health Care Cost Trend Rates		Year Ended December 31, 2014 2013 Assumed Health Care Cost Trend Rates – Not Medicare Eligible: Health care cost trend rate assumed for next year Rate to which the cost trend is expected to decline (the ultimate trend rate) Year that the rate reaches the ultimate trend rate Assumed Health Care Cost Trend Rates – Medicare Eligible: Health care cost trend rate assumed for next year Rate to which the cost trend is expected to decline (the ultimate trend rate) Year that the rate reaches the ultimate trend rate 1-Percentage Point Increase 1-Percentage Point Decrease Sensitivity Analysis of Assumed Health Care Cost Trend Rates: Effect on accumulated postretirement obligation $ $ Effect on postretirement benefits cost
Schedule Of Projected Benefit Obligations And Accumulated Benefit Obligations In Excess Of Plan Assets Fair Value		At December 31, 2014 2013 Pension Plans with PBO and ABO in Excess of Plan Assets: Projected benefit obligations $ $ Accumulated benefit obligations Plan assets
Schedule Of Target Asset Allocation Ranges By Asset Category		Target Allocation Ranges Asset Category Recoverable Nonrecoverable US equities 19% - 25% — International equities 14% - 20% — Fixed income 48% - 65% 100% Real estate 2% - 7% —
Schedule Of Expected Long-Term Rate Of Return On Assets Assumptions		Pension Plans OPEB Plan Asset Class Expected Long-Term Rate of Return Asset Class Expected Long-Term Rate of Return International equity securities 7.50% 401(h) accounts 6.96% US equity securities 6.80% Life insurance VEBA 6.45% Real estate 6.10% Union VEBA 6.45% Credit strategies 4.74% Non-union VEBA 2.90 % Fixed income securities 4.40 % Weighted average 6.65% Weighted average (a) 5.94% _____________ (a) The 2015 expected long-term rate of return for the nonregulated portion of the Oncor Retirement Plan is 3.95 %.
Schedule Of Contributions		Year Ended December 31, 2014 2013 2012 Pension plans contributions $ $ $ OPEB plan contributions Total contributions $ $ $
Schedule Of Estimated Future Benefit Payments		2015 2016 2017 2018 2019 2020-24 Pension plans $ $ $ $ $ $ OPEB plan $ $ $ $ $ $
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Assets Fair Value Measured On Recurring Basis		At December 31, 2014 At December 31, 2013 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Asset Category Interest-bearing cash $ - $ $ - $ $ - $ $ - $ Equity securities: US - - International - - Fixed income securities: Corporate bonds (a) - - - - US Treasuries - - - - Other (b) - - - - Real estate - - - Total assets $ $ $ $ $ $ $ $ _____________ (a) Substantially all corporate bonds are rated investment grade by a major ratings agency such as Moody’s. (b) Other consists primarily of municipal bonds , emerging market debt, bank loans and fixed income derivative instruments.
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Assets Fair Value Measured On Recurring Basis		At December 31, 2014 At December 31, 2013 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Asset Category Interest-bearing cash $ $ $ - $ $ - $ $ - $ Equity securities: US - - International - - - - Fixed income securities: Corporate bonds (a) - - - - US Treasuries - - - - Other (b) - - Total assets $ $ $ - $ $ $ $ - $ _____________ (a) Substantially all corporate bonds are rated investment grade by a major ratings agency such as Moody’s. (b) Other consists primarily of diversified bond mutual funds.

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Related-Party Transactions [Abstract]
Schedule OF Trade Accounts And Other Receivables From Related Parties	At June 30, At December 31, 2015 2014 Trade accounts and other receivables from affiliates - billed $ $ Trade accounts and other receivables from affiliates - unbilled Trade accounts and other payables to affiliates Trade accounts and other receivables from affiliates – net $ $	At December 31, 2014 2013 Trade accounts and other receivables from affiliates $ $ Trade accounts and other payables to affiliates Trade accounts and other receivables from affiliates – net $ $
Schedule Of Related Party Transactions	Amounts payable to (receivable from) members related to income taxes under the tax sharing agreement and reported on our balance sheet consisted of the following: At June 30, 2015 At December 31, 2014 EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total Federal income taxes receivable $ $ $ $ $ $ Federal income taxes payable - - - - - - Texas margin taxes payable - - Net payable (receivable) $ $ $ $ $ $ Cash payments made to members related to income taxes consisted of the following: Six Months Ended June 30, 2015 Six Months Ended June 30, 2014 EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total Federal income taxes $ - $ - $ - $ $ $ Texas margin taxes - - Total payments (receipts) $ $ - $ $ $ $	Amounts payable to (receivable from) members related to income taxes under the agreement and reported on our balance sheet consisted of the following: At December 31, 2014 At December 31, 2013 EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total Federal income taxes receivable $ $ $ $ $ $ Texas margin taxes payable - - Net payable (receivable) $ $ $ $ $ $ - Cash payments made to (received from) members related to income taxes consisted of the following: Year Ended December 31, 2014 Year Ended December 31, 2013 Year Ended December 31, 2012 EFH Corp. Texas Transm. Total EFH Corp. Texas Transm. Total EFH Corp. Texas Transm. Total Federal income taxes (a) $ $ $ $ $ $ $ $ $ Texas margin taxes (b) - - - Total payments (receipts) $ $ $ $ $ $ $ $ $ ______________ (a) Includes $33 million payment made to EFH Corp. in 2013 related to the 1997-2002 IRS appeals settlement. (b) Includes $10 million refund received from EFH Corp. in 2013 related to 1997-2001 amended Texas franchise tax returns.

Supplementary Financial Infor31

Supplementary Financial Information (Tables)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Supplementary Financial Information [Abstract]
Schedule Of Other Income And Deductions	Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Other income: Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting $ $ $ $ Other - - - Total other income $ $ $ $ Other deductions: Professional fees $ $ $ $ Other - - Total other deductions $ $ $ $	Year Ended December 31, 2014 2013 2012 Other income: Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting $ $ $ Net gain on sale of other properties and investments Total other income $ $ $ Other deductions: Professional fees $ $ $ SARs exercise (Note 11) - Other Total other deductions $ $ $
Schedule Of Interest Expense And Related Charges	Three Months Ended June 30, Six Months Ended June 30, 2015 2014 2015 2014 Interest expense $ $ $ $ Amortization of debt issuance costs and discounts Allowance for funds used during construction – capitalized interest portion Total interest expense and related charges $ $ $ $	Year Ended December 31, 2014 2013 2012 Interest expense $ $ $ Amortization of debt issuance costs and discounts Allowance for funds used during construction – capitalized interest portion Total interest expense and related charges $ $ $
Schedule Of Restricted Cash		At December 31, 2014 At December 31, 2013 Current Assets Noncurrent Assets Current Assets Noncurrent Assets Customer collections related to transition bonds used only to service debt and pay expenses $ $ - $ $ - Reserve for fees associated with transition bonds - - Reserve for shortfalls of transition bond charges - - Total restricted cash $ $ $ $
Schedule Of Trade Accounts Receivable	At June 30, At December 31, 2015 2014 Gross trade accounts and other receivables $ $ Trade accounts and other receivables from affiliates Allowance for uncollectible accounts Trade accounts receivable from nonaffiliates – net $ $	At December 31, 2014 2013 Gross trade accounts receivable $ $ Trade accounts receivable from TCEH Allowance for uncollectible accounts Trade accounts receivable from nonaffiliates – net $ $
Summary of Investment Balance	At June 30, At December 31, 2015 2014 Assets related to employee benefit plans, including employee savings programs $ $ Land Total investments and other property $ $	At December 31, 2014 2013 Assets related to employee benefit plans, including employee savings programs $ $ Land Total investments and other property $ $
Schedule Of Property, Plant And Equipment	At June 30, At December 31, 2015 2014 Total assets in service $ $ Less accumulated depreciation Net of accumulated depreciation Construction work in progress Held for future use Property, plant and equipment – net $ $	Composite Depreciation Rate/ At December 31, Avg. Life at December 31, 2014 2014 2013 Assets in service: Distribution 4.1% / 24.6 years $ $ Transmission 2.8% / 35.7 years Other assets 9.2% / 10.9 years Total Less accumulated depreciation Net of accumulated depreciation Construction work in progress Held for future use Property, plant and equipment – net $ $
Schedule Of Intangible Assets	At June 30, 2015 At December 31, 2014 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Net Amount Amortization Net Identifiable intangible assets subject to amortization included in property, plant and equipment: Land easements $ $ $ $ $ $ Capitalized software Total $ $ $ $ $ $	At December 31, 2014 At December 31, 2013 Gross Gross Carrying Accumulated Carrying Accumulated Amount Amortization Net Amount Amortization Net Identifiable intangible assets subject to amortization included in property, plant and equipment: Land easements $ $ $ $ $ $ Capitalized software Total $ $ $ $ $ $
Schedule Of Estimated Aggregate Amortization Expenses	Year Amortization Expense 2015 $ 2016 2017 2018 2019	Year Amortization Expense 2015 $ 2016 2017 2018 2019
Schedule Of Other Noncurrent Liabilities And Deferred Credits	At June 30, At December 31, 2015 2014 Retirement plans and other employee benefits $ $ Uncertain tax positions (including accrued interest) Amount payable related to income taxes Investment tax credits Other Total other noncurrent liabilities and deferred credits $ $	At December 31, 2014 2013 Retirement plans and other employee benefits $ $ Uncertain tax positions (including accrued interest) Amount payable related to income taxes Investment tax credits Other Total other noncurrent liabilities and deferred credits $ $
Schedule Of Supplemental Cash Flow Information	Six Months Ended June 30, 2015 2014 Cash payments (receipts) related to: Interest $ $ Capitalized interest Interest (net of amounts capitalized) $ $ Amount in lieu of income taxes (a): Federal $ - $ State Total amount in lieu of income taxes $ $ Noncash construction expenditures (b) $ $ _____________ (a) See Note 10 for income tax detail. Represents end-of-period accruals .	Year Ended December 31, 2014 2013 2012 Cash payments (receipts) related to: Interest $ $ $ Capitalized interest Interest (net of amounts capitalized) $ $ $ Amount in lieu of income taxes: Federal $ $ $ State Total amount in lieu of income taxes $ $ $ SARs exercise - Noncash construction expenditures (a) ______________ (a) Represents end-of-period accruals.
Schedule Of Quarterly Information		2014 First Quarter Second Quarter Third Quarter Fourth Quarter Operating revenues $ $ $ $ Operating income Net income 2013 First Quarter Second Quarter Third Quarter Fourth Quarter Operating revenues $ $ $ $ Operating income Net income

Description Of Business And S32

Description Of Business And Significant Accounting Policies (Details) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015entity	Jun. 30, 2014	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2004USD ($)	Dec. 31, 2003USD ($)	Dec. 31, 2002USD ($)
Description of Business [Line Items]
Percentage of membership interest owned by company			80.03%
Percentage of membership interest owned by non-controlling owners	19.75%		19.75%
Number of entities that would possibly be bankrupt | entity			1
Principal amount of transition bonds issued									$ 1,300	$ 1,300	$ 1,300
Transition bonds outstanding					$ 180
Long-lived assets and goodwill impairments					$ 0	$ 0	$ 0
Equity AFUDC							$ 1
Scenario, Forecast [Member]
Description of Business [Line Items]
Expected decrease to other noncurrent assets and long-term debt								$ (40)
Sales [Member] | TCEH [Member]
Description of Business [Line Items]
Concentration Risk Percentage	24.00%	25.00%	24.00%	25.00%	25.00%	27.00%	29.00%
Oncor
Description of Business [Line Items]
Percentage of membership interest owned by company					80.03%
Texas Transmission [Member]
Description of Business [Line Items]
Percentage of membership interest owned by non-controlling owners	19.75%		19.75%		19.75%

EFH Bankruptcy Proceedings (Nar

EFH Bankruptcy Proceedings (Narrative) (Details) - USD ($) $ in Millions	Apr. 29, 2014	Dec. 31, 2014	Jun. 30, 2015	Apr. 28, 2014
EFH Bankruptcy Proceedings [Abstract]
Amount receivable from related party			$ 129	$ 129
Amount collected from related party	$ 127	$ 127

EFH Bankruptcy Proceedings (Sch

EFH Bankruptcy Proceedings (Schedule Of Accounts Receivable From EFH Corp.) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
EFH Corp [Member]
Subsequent Event [Line Items]
Trade accounts and other receivables from affiliates - net	$ 138	$ 118	$ 135

Regulatory Matters (Details)

Regulatory Matters (Details) - USD ($) $ in Millions	Feb. 19, 2015	Dec. 31, 2014
Regulatory Matters [Abstract]
Estimated impact on earnings, minimum	$ 0	$ 0
Estimated impact on earnings, maximum	$ 130	$ 130

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2014	Sep. 30, 2013	Jun. 30, 2015	Sep. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012
Related Party Transaction [Line Items]
Liability in lieu of deferred income taxes	$ 2,559		$ 2,514			$ 2,414
Increase (Decrease) in liability for uncertain tax positions	(35)				$ (18)
Increase (Decrease) in liability for deferred income taxes					16
Increase (Decrease) in liability in lieu of deferred income taxes	33
Increase (Decrease) in provision in lieu of income taxes	(2)
Reversal of provision in lieu of income taxes				$ 1
Reversal of accrued interest and tax					2
Reversal of accrued interest and tax after tax					$ 1
Uncertain tax positions related to timing of recognition	3					51
Accrued interest						2
Benefit (Expense) from interest and penalties	(1)					(15)			$ 3
Potential reduction in liability	1
EFH Corp [Member]
Related Party Transaction [Line Items]
Increase (Decrease) in liability for uncertain tax positions							$ (32)
Increase (Decrease) in liability for deferred income taxes							(10)	$ 58
Reversal of accrued interest and tax						$ 3	5	18
Reversal of accrued interest and tax after tax							$ 3	12
Income tax payments to members		$ 33
Income tax refunds from members		$ 10
Uncertain tax positions related to timing of recognition								$ 76
Tax Year 2003 To 2006 [Member] | EFH Corp [Member]
Related Party Transaction [Line Items]
Expected tax refund	$ 9
Tax Year 2007 [Member] | EFH Corp [Member]
Related Party Transaction [Line Items]
Expected tax refund				$ 44

Income Taxes (Components Of Inc

Income Taxes (Components Of Income Tax Provisions (Benefits)) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Current: US federal					$ 113	$ 51	$ 23
Current: State					24	12	21
Deferred: US federal					146	181	200
Deferred: State						6
Amortization of investment tax credits					(3)	(3)	(4)
Total reported in operating expenses	$ 57	$ 60	$ 115	$ 123	280	247	240
US federal					(4)	(5)	(14)
Deferred federal					2	7	8
Total reported in other income and deductions					(2)	2	(6)
Total provision in lieu of income taxes					$ 278	$ 249	$ 234

Income Taxes (Schedule Of Incom

Income Taxes (Schedule Of Income Tax Reconciliation) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Income before provision in lieu of income taxes	$ 728	$ 681	$ 583
Provision in lieu of income taxes at the US federal statutory rate of 35%	255	238	204
Amortization of investment tax credits - net of deferred tax effect	(3)	(3)	(4)
Amortization (under regulatory accounting) of statutory tax rate changes	(2)	(2)	(3)
Amortization of Medicare subsidy regulatory asset	14	14	14
Texas margin tax, net of federal tax benefit	16	15	14
Nondeductible losses (gains) on benefit plan investments	(2)	(3)	(2)
Other, including audit settlements		(10)	11
Total provision in lieu of income taxes	$ 278	$ 249	$ 234
Effective rate	38.20%	36.60%	40.10%
US federal statutory rate	35.00%	35.00%	35.00%

Income Taxes (Schedule Of Chang

Income Taxes (Schedule Of Changes To Uncertain Tax Positions) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
Balance at January 1, excluding interest and penalties	$ 54	$ 144	$ 126
Additions based on tax positions related to prior years			18
Reductions based on tax positions related to prior years	(16)	(66)
Settlements with taxing authorities	(36)	(24)
Balance at December 31, excluding interest and penalties	$ 2	$ 54	$ 144

Regulatory Assets And Liabili40

Regulatory Assets And Liabilities (Narrative) (Details) - USD ($)	Oct. 10, 2007	Dec. 31, 2014	Jun. 30, 2015	Dec. 31, 2013
Regulatory Assets And Liabilities [Line Items]
Expected surcharge		$ 1,023,000,000
Recovery period		11 years
Net regulatory asset		$ 1,429,000,000	$ 1,321,000,000	$ 1,324,000,000
Residential Retail Customer [Member]
Regulatory Assets And Liabilities [Line Items]
Cost recovery factor		2.19
Minimum [Member] | Non-Residential Retail Customer [Member]
Regulatory Assets And Liabilities [Line Items]
Cost recovery factor		2.39
Maximum [Member] | Non-Residential Retail Customer [Member]
Regulatory Assets And Liabilities [Line Items]
Cost recovery factor		5.15
Over Collection of Transition Bond Revenues [Member]
Regulatory Assets And Liabilities [Line Items]
Recovery period	9 years
Net regulatory asset		32,000,000	31,000,000	35,000,000
Deferred AMS Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Net regulatory asset		113,000,000		62,000,000
Generation Related Regulatory Assets Securitized by Transition Bonds [Member]
Regulatory Assets And Liabilities [Line Items]
Reduction in regulatory assets net of regulatory liability		213,000,000
Net regulatory asset		$ 140,000,000	$ 78,000,000	$ 261,000,000

Regulatory Assets And Liabili41

Regulatory Assets And Liabilities (Components Of Regulatory Assets And Liabilities) (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014		Dec. 31, 2013
Regulatory Assets And Liabilities [Line Items]
Carrying Amount, Regulatory Assets	$ 1,995	$ 2,023		$ 1,771
Carrying Amount, Regulatory Liabilities	674	594		447
Net regulatory asset	1,321	1,429		1,324
Bondco
Regulatory Assets And Liabilities [Line Items]
Net regulatory asset	$ 47	$ 108		226
Estimated Net Removal Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	Life of utility plant	Lives of related assets
Carrying Amount, Regulatory Liabilities	$ 608	$ 531		385
Investment Tax Credit and Protected Excess Deferred Taxes [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	Various	Various
Carrying Amount, Regulatory Liabilities	$ 15	$ 18		23
Over Collection of Transition Bond Revenues [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	1 year	1 year	[1],[2]
Carrying Amount, Regulatory Liabilities	$ 31	$ 32	[1],[2]	35	[1],[2]
Net regulatory asset	$ 31	$ 32		35
Energy Efficiency Programs [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	Not applicable	Not applicable	[2]
Carrying Amount, Regulatory Liabilities	$ 20	$ 13	[2]	4	[2]
Generation Related Regulatory Assets Securitized by Transition Bonds [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	1 year	1 year	[1],[2]
Carrying Amount, Regulatory Assets	$ 81	$ 148	[1],[2]	281	[1],[2]
Net regulatory asset	$ 78	$ 140		261
Employee Retirement Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	5 years	5 years
Carrying Amount, Regulatory Assets	$ 47	$ 55		71
Employee Retirement Costs to be Reviewed [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	To be determined	To be determined	[3],[4]
Carrying Amount, Regulatory Assets	$ 267	$ 246	[3],[4]	224	[3],[4]
Employee Retirement Liability [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	To be determined	To be determined	[2],[4],[5]
Carrying Amount, Regulatory Assets	$ 828	$ 865	[2],[4],[5]	491	[2],[4],[5]
Self Insurance Reserve (Primarily Storm Recovery Costs) - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	5 years	5 years
Carrying Amount, Regulatory Assets	$ 111	$ 127		158
Self Insurance Reserve to be Reviewed [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	To be determined	To be determined	[3],[4]
Carrying Amount, Regulatory Assets	$ 316	$ 242	[3],[4]	196	[3],[4]
Securities Reacquisition Costs (Pre-Industry Restructure) [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	2 years	2 years
Carrying Amount, Regulatory Assets	$ 19	$ 23		32
Securities Reacquisition Costs (Post Industry Restructure) - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	Terms of related debt	Lives of related debt
Carrying Amount, Regulatory Assets	$ 8	$ 7		5
Recoverable Amounts In Lieu Of Deferred Income Taxes - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	Life of related asset or liability	Life of related asset or liability
Carrying Amount, Regulatory Assets	$ 12	$ 14		42
Deferred Conventional Meter And Metering Facilities Depreciation [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	Largely 5 years	Largely 6 years
Carrying Amount, Regulatory Assets	$ 112	$ 123		146
Deferred AMS Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	To be determined	To be determined
Carrying Amount, Regulatory Assets	$ 140	$ 113		62
Net regulatory asset		$ 113		62
Energy Efficiency Performance Bonus [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	1 year	1 year	[2]
Carrying Amount, Regulatory Assets	$ 11	$ 22	[2]	12	[2]
Under Recovered Wholesale Transmission Service Expense - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	1 year	1 year	[2]
Carrying Amount, Regulatory Assets	$ 34	$ 26	[2]	37	[2]
Other Regulatory Assets [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	Various	Various
Carrying Amount, Regulatory Assets	$ 9	$ 12		$ 14
[1]	Bondco net regulatory assets of $108 million at December 31, 2014 consisted of $140 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $32 million. Bondco net regulatory assets of $226 million at December 31, 2013 consisted of $261 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $35 million.
[2]	Not earning a return in the regulatory rate-setting process.
[3]	Costs incurred since the period covered under the last rate review.
[4]	Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review.
[5]	Represents unfunded liabilities recorded in accordance with pension and OPEB accounting standards.

Borrowings Under Credit Facil42

Borrowings Under Credit Facilities (Details) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2015USD ($)item	Dec. 31, 2014USD ($)item	Dec. 31, 2013USD ($)
Line of Credit Facility [Line Items]
Secured revolving credit facility	$ 2,400	$ 2,400
Number of revolving credit facilities extension options | item	2	2
Extension period for revolving line of credit	1 year	1 year
Additional increase in borrowing capacity amount	$ 100	$ 100
Outstanding borrowing under the revolving credit facility	$ 780	$ 711	$ 745
Outstanding borrowing, interest rate	1.31%	1.29%	1.67%
Letters of credit	$ 7	$ 7	$ 6
Commitment fee	0.125%	0.125%
Borrowing capacity available under the credit facility	$ 1,613	$ 1,682	$ 1,649
Maximum [Member]
Line of Credit Facility [Line Items]
Commitment rate reduction under the revolving credit facility	0.275%	0.275%
Required debt-to-capitalization ratio	1	1
Debt-to-capitalization ratio		1
Minimum [Member]
Line of Credit Facility [Line Items]
Commitment rate reduction under the revolving credit facility	0.10%	0.10%
Required debt-to-capitalization ratio	0.65	0.65
Debt-to-capitalization ratio		0.45
Letter of Credit [Member]
Line of Credit Facility [Line Items]
Outstanding borrowing, interest rate	1.325%	1.325%
London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.125%	1.125%
London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.75%	1.75%
London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.00%	1.00%
Federal Funds Effective Rate [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	0.50%	0.50%
One Month LIBOR [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.00%	1.00%
One Month LIBOR [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	0.75%	0.75%
One Month LIBOR [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	0.00%	0.00%

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details) - USD ($)	1 Months Ended			6 Months Ended		12 Months Ended
	Mar. 31, 2015	May. 31, 2014	May. 31, 2013	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012	Nov. 30, 2011
Long-Term Debt [Line Items]
Repayments of long-term debt				$ 569,000,000	$ 65,000,000	$ 131,000,000		$ 125,000,000		$ 1,018,000,000
Note redemption price to principal amount, percentage				100.00%
Proceeds from issuance of long-term debt				$ 725,000,000	$ 250,000,000	$ 250,000,000		100,000,000		$ 900,000,000
Percentage of principal amount plus accrued and unpaid interest and make-whole premium				100.00%
Increase in basis points				0.50%
Percentage of fair value of cost of property additions certified to the Deed of Trust collateral agent				85.00%		85.00%
Estimated fair value of our long-term debt including current maturities				$ 6,622,000,000		$ 6,844,000,000		6,188,000,000
Carrying amount				5,791,000,000		5,636,000,000		$ 5,512,000,000
Available bond credits				2,637,000,000		2,208,000,000
Future debt subject to property additions to the Deed of Trust				1,103,000,000		1,570,000,000
6.375% Fixed Senior Notes Due January 15, 2015 [Member]
Long-Term Debt [Line Items]
Aggregate principal amount				$ 500,000,000		$ 500,000,000
Interest percentage				6.375%		6.375%	[1]	6.375%	[1]
Transition Bond [Member]
Long-Term Debt [Line Items]
Debt principal amount				$ 69,000,000
2.950% Fixed Senior Notes due April 1, 2025 [Member]
Long-Term Debt [Line Items]
Aggregate principal amount	$ 350,000,000			$ 350,000,000
Interest percentage	2.95%			2.95%
2.150% Fixed Senior Notes Due June 1, 2019 [Member]
Long-Term Debt [Line Items]
Aggregate principal amount		$ 250,000,000		$ 250,000,000		$ 250,000,000
Interest percentage		2.15%		2.15%		2.15%	[1]	2.15%	[1]
Proceeds from issuance of long-term debt	$ 714,000,000	$ 248,000,000
Percentage of principal amount plus accrued and unpaid interest and make-whole premium		100.00%
4.550% Fixed Senior Notes Due December 1, 2041 [Member]
Long-Term Debt [Line Items]
Aggregate principal amount			$ 100,000,000	$ 400,000,000		$ 400,000,000					$ 300,000,000
Interest percentage			4.55%	4.55%		4.55%	[1]	4.55%	[1]
Note redemption price to principal amount, percentage						100.00%
Proceeds from issuance of long-term debt			$ 107,000,000
3.750% Fixed Senior Notes due April 1, 2045 [Member]
Long-Term Debt [Line Items]
Aggregate principal amount	$ 375,000,000			$ 375,000,000
Interest percentage	3.75%			3.75%
[1]	Secured by first priority lien on certain transmission and distribution assets equally and ratably with all of Oncor's other secured indebtedness. See "Deed of Trust" below for additional information.

Long-Term Debt (Schedule Of Lon

Long-Term Debt (Schedule Of Long-Term Debt) (Details) - USD ($) $ in Millions		12 Months Ended				24 Months Ended
		Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2014		Jun. 30, 2015	Mar. 31, 2015	May. 31, 2014	May. 31, 2013	Nov. 30, 2011
Debt Instrument [Line Items]
Unamortized discount		$ (19)				$ (19)
Total long-term debt, less amounts due currently		4,997		$ 5,381		4,997		$ 5,680
6.375% Fixed Senior Notes Due January 15, 2015 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 500				$ 500		$ 500
Interest percentage		6.375%	[1]	6.375%	[1]	6.375%	[1]	6.375%
Due date	[1]					Jan. 15, 2015
5.000% Fixed Senior Notes Due September 30, 2017 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 324				$ 324		$ 324
Interest percentage		5.00%	[1]	5.00%	[1]	5.00%	[1]	5.00%
Due date	[1]					Sep. 30, 2017
6.800% Fixed Senior Notes Due September 1, 2018 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 550				$ 550		$ 550
Interest percentage		6.80%	[1]	6.80%	[1]	6.80%	[1]	6.80%
Due date	[1]					Sep. 1, 2018
2.150% Fixed Senior Notes Due June 1, 2019 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 250				$ 250		$ 250		$ 250
Interest percentage		2.15%	[1]	2.15%	[1]	2.15%	[1]	2.15%		2.15%
Due date	[1]					Jun. 1, 2019
5.750% Fixed Senior Notes Due September 30, 2020 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 126				$ 126		$ 126
Interest percentage		5.75%	[1]	5.75%	[1]	5.75%	[1]	5.75%
Due date	[1]					Sep. 30, 2020
4.100% Fixed Senior Notes Due June 1, 2022 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 400				$ 400		$ 400
Interest percentage		4.10%	[1]	4.10%	[1]	4.10%	[1]	4.10%
Due date	[1]					Jun. 1, 2022
7.000% Fixed Debentures Due September 1, 2022 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 800				$ 800		$ 800
Interest percentage		7.00%	[1]	7.00%	[1]	7.00%	[1]	7.00%
Due date	[1]					Sep. 1, 2022
2.950% Fixed Senior Notes due April 1, 2025 [Member]
Debt Instrument [Line Items]
Fixed Senior Note								$ 350	$ 350
Interest percentage								2.95%	2.95%
7.000% Fixed Senior Notes Due May 1, 2032 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 500				$ 500		$ 500
Interest percentage		7.00%	[1]	7.00%	[1]	7.00%	[1]	7.00%
Due date	[1]					May 1, 2032
7.250% Fixed Senior Notes Due January 15, 2033 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 350				$ 350		$ 350
Interest percentage		7.25%	[1]	7.25%	[1]	7.25%	[1]	7.25%
Due date	[1]					Jan. 15, 2033
7.500% Fixed Senior Notes Due September 1, 2038 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 300				$ 300		$ 300
Interest percentage		7.50%	[1]	7.50%	[1]	7.50%	[1]	7.50%
Due date	[1]					Sep. 1, 2038
5.250% Fixed Senior Notes Due September 30, 2040 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 475				$ 475		$ 475
Interest percentage		5.25%	[1]	5.25%	[1]	5.25%	[1]	5.25%
Due date	[1]					Sep. 30, 2040
4.550% Fixed Senior Notes Due December 1, 2041 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 400				$ 400		$ 400			$ 100	$ 300
Interest percentage		4.55%	[1]	4.55%	[1]	4.55%	[1]	4.55%			4.55%
Due date	[1]					Dec. 1, 2041
5.300% Fixed Senior Notes Due June 1, 2042 [Member]
Debt Instrument [Line Items]
Fixed Senior Note		$ 500				$ 500		$ 500
Interest percentage		5.30%	[1]	5.30%	[1]	5.30%	[1]	5.30%
Due date	[1]					Jun. 1, 2042
3.750% Fixed Senior Notes due April 1, 2045 [Member]
Debt Instrument [Line Items]
Fixed Senior Note								$ 375	$ 375
Interest percentage								3.75%	3.75%
5.420% Fixed Series 2003 Bonds Due Through August 15, 2015 [Member]
Debt Instrument [Line Items]
Fixed Bonds		$ 54				$ 54		$ 25
Interest percentage		5.42%	[2]	5.42%	[2]	5.42%	[2]	5.42%
Due date	[2]	Aug. 15, 2015		Aug. 15, 2015
5.290% Fixed Series 2004 Bonds Due Through May 15, 2016 [Member]
Debt Instrument [Line Items]
Fixed Bonds		$ 126				$ 126		$ 86
Interest percentage		5.29%	[2]	5.29%	[2]	5.29%	[2]	5.29%
Due date	[2]	May 15, 2016		May 15, 2016
Oncor
Debt Instrument [Line Items]
Unamortized discount		$ (19)	[1]	$ (23)	[1]	$ (19)	[1]	$ (20)
Less amount due currently	[1]	(500)				(500)
Total long-term debt, less amounts due currently		4,956	[1]	5,202	[1]	4,956	[1]	5,680
Oncor | 6.375% Fixed Senior Notes Due January 15, 2015 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	500		500		500
Oncor | 5.000% Fixed Senior Notes Due September 30, 2017 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	324		324		324
Oncor | 6.800% Fixed Senior Notes Due September 1, 2018 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	550		550		550
Oncor | 2.150% Fixed Senior Notes Due June 1, 2019 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	250				250
Oncor | 5.750% Fixed Senior Notes Due September 30, 2020 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	126		126		126
Oncor | 4.100% Fixed Senior Notes Due June 1, 2022 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	400		400		400
Oncor | 7.000% Fixed Debentures Due September 1, 2022 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	800		800		800
Oncor | 7.000% Fixed Senior Notes Due May 1, 2032 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	500		500		500
Oncor | 7.250% Fixed Senior Notes Due January 15, 2033 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	350		350		350
Oncor | 7.500% Fixed Senior Notes Due September 1, 2038 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	300		300		300
Oncor | 5.250% Fixed Senior Notes Due September 30, 2040 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	475		475		475
Oncor | 4.550% Fixed Senior Notes Due December 1, 2041 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	400		400		400
Oncor | 5.300% Fixed Senior Notes Due June 1, 2042 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	500		500		500
Bondco
Debt Instrument [Line Items]
Unamortized discount	[2]			(1)
Less amount due currently		(139)	[2]	(131)	[2]	(139)	[2]	$ (111)
Total long-term debt, less amounts due currently	[2]	41		179		41
Bondco | 5.420% Fixed Series 2003 Bonds Due Through August 15, 2015 [Member]
Debt Instrument [Line Items]
Fixed Bonds	[2]	54		106		54
Bondco | 5.290% Fixed Series 2004 Bonds Due Through May 15, 2016 [Member]
Debt Instrument [Line Items]
Fixed Bonds	[2]	$ 126		$ 205		$ 126
[1]	Secured by first priority lien on certain transmission and distribution assets equally and ratably with all of Oncor's other secured indebtedness. See "Deed of Trust" below for additional information.
[2]	The transition bonds are nonrecourse to Oncor and were issued to securitize a regulatory asset.

Long-Term Debt (Schedule Of L45

Long-Term Debt (Schedule Of Long-Term Debt Maturity) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Long-Term Debt [Abstract]
2,015		$ 639
2,016		41
2,017		324
2,018		550
2,019		250
Thereafter		3,851
Unamortized discount		(19)
Total	$ 5,791	$ 5,636	$ 5,512

Commitments And Contingencies46

Commitments And Contingencies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Commitments and Contingencies [Abstract]
Rent expenses	$ 9	$ 10	$ 15
Required efficiency spending amount	50
Aggregate maximum amount of residual values guaranteed	$ 6
Average life of the residual value guarantees under the lease portfolio	2 years 6 months
Percentage of full time employees represented by labor union	19.00%

Commitments And Contingencies47

Commitments And Contingencies (Schedule Of Future Miinimum Lease Payments Under Operating Leases) (Details) $ in Millions	Dec. 31, 2014USD ($)
Commitments and Contingencies [Abstract]
2,015	$ 5
2,016	4
2,017	1
Total future minimum lease payments	$ 10

Membership Interests (Narrative

Membership Interests (Narrative) (Details) - USD ($) $ in Millions	Jul. 29, 2015	Feb. 25, 2015	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Subsequent Event [Line Items]
Declaration of cash distribution to members			$ 165	$ 110	$ 282	$ 310	$ 225
Assumed debt to equity ratio, debt			60.00%		60.00%
Assumed debt to equity ratio, equity			40.00%		40.00%
Regulatory capitalization ratio, debt			59.60%		58.80%
Regulatory capitalization ratio, equity			40.40%		41.20%
Cash available for distribution under the capital structure restriction			$ 68		$ 184
Subsequent Event [Member]
Subsequent Event [Line Items]
Declaration of cash distribution to members		$ 100
Subsequent Event [Member] | Maximum [Member]
Subsequent Event [Line Items]
Declaration of cash distribution to members	$ 120
Subsequent Event [Member] | Minimum [Member]
Subsequent Event [Line Items]
Declaration of cash distribution to members	$ 110

Membership Interests (Schedule

Membership Interests (Schedule Of Distributions Paid) (Details) - USD ($) $ in Millions	6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Dividends Payable [Line Items]
Amount	$ 165	$ 110	$ 282	$ 310	$ 225
Payment One FY 2015 [Member]
Dividends Payable [Line Items]
Declaration Date	Feb. 25, 2015
Payment Date	Feb. 26, 2015
Amount	$ 100
Payment Two FY 2015 [Member]
Dividends Payable [Line Items]
Declaration Date	Apr. 29, 2015
Payment Date	May 15, 2015
Amount	$ 65
Payment Four FY 2014 [Member]
Dividends Payable [Line Items]
Declaration Date			Oct. 21, 2014
Payment Date			Oct. 22, 2014
Amount			$ 101
Payment Three FY 2014 [Member]
Dividends Payable [Line Items]
Declaration Date			Jul. 30, 2014
Payment Date			Jul. 31, 2014
Amount			$ 71
Payment Two FY 2014 [Member]
Dividends Payable [Line Items]
Declaration Date			Apr. 30, 2014
Payment Date			May 1, 2014
Amount			$ 57
Payment One FY 2014 [Member]
Dividends Payable [Line Items]
Declaration Date			Feb. 19, 2014
Payment Date			Feb. 20, 2014
Amount			$ 53
Payment Four FY 2013 [Member]
Dividends Payable [Line Items]
Declaration Date				Oct. 29, 2013
Payment Date				Oct. 31, 2013
Amount				$ 95
Payment Three FY 2013 [Member]
Dividends Payable [Line Items]
Declaration Date				Jul. 31, 2013
Payment Date				Aug. 1, 2013
Amount				$ 95
Payment Two FY 2013 [Member]
Dividends Payable [Line Items]
Declaration Date				May 1, 2013
Payment Date				May 2, 2013
Amount				$ 70
Payment One FY 2013 [Member]
Dividends Payable [Line Items]
Declaration Date				Feb. 13, 2013
Payment Date				Feb. 15, 2013
Amount				$ 50

Membership Interests (Schedul50

Membership Interests (Schedule Of Changes To Membership Interests) (Details) - USD ($) $ in Millions	3 Months Ended									6 Months Ended		12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Balance			$ 7,497		$ 7,409					$ 7,518	$ 7,409	$ 7,409
Net income	$ 98	$ 94	158	$ 94	104	$ 103	$ 146	$ 96	$ 87	196	197	450	$ 432	$ 349
Distributions										(165)	(110)	(282)	(310)	(225)
Net effects of cash flow hedges (net of tax)	1			1						1	1	2	2	3
Defined benefit pension plans (net of tax)										1		(61)	(19)	$ (3)
Balance	7,551	7,518		7,497		7,409				7,551	7,497	7,518	7,409
Capital Accounts [Member]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Balance			7,544		7,457					7,625	7,457	7,457
Net income										196	197
Distributions										(165)	(110)
Balance	7,656	7,625		7,544		7,457				7,656	7,544	7,625	7,457
Accumulated Other Comprehensive Income (Loss) [Member]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Balance			$ (47)		$ (48)					(107)	(48)	(48)
Net effects of cash flow hedges (net of tax)										1	1
Defined benefit pension plans (net of tax)										1
Balance	$ (105)	$ (107)		$ (47)		$ (48)				$ (105)	$ (47)	$ (107)	$ (48)

Membership Interests (Schedul51

Membership Interests (Schedule Of Changes To Accumulated Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions	6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (107)	$ (48)	$ (48)	$ (31)
Balance at end of period	(105)		(107)	(48)
Cash Flow Hedges - Interest Rate Swap [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(24)	(26)	(26)	(28)
Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges	1	1	2	2
Balance at end of period	(23)	(25)	(24)	(26)
Defined Benefit Pension and OPEB Plans [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(83)	(22)	(22)	(3)
Defined benefit pension plans (net of tax)	1		(61)	(19)
Balance at end of period	(82)	(22)	(83)	(22)
Accumulated Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(107)	(48)	(48)	(31)
Defined benefit pension plans (net of tax)	1		(61)	(19)
Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges	1	1	2	2
Balance at end of period	$ (105)	$ (47)	$ (107)	$ (48)

Pension And Other Postretirem52

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Narrative) (Details) $ in Millions		2 Months Ended	3 Months Ended			6 Months Ended			7 Months Ended	12 Months Ended
		Sep. 30, 2012	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Dec. 31, 2012USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 30, 2014USD ($)	Jul. 31, 2012	Dec. 31, 2014USD ($)item	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets			$ 1,995			$ 1,995	$ 2,023			$ 2,023	$ 1,771
Discount rate		4.15%			4.20%		4.39%	4.98%	5.00%
Earning period										3 years
Cash contributions										$ 86	20	$ 104
Rolling period										4 years
Percentage of gains and losses										25.00%
Oncor Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate						3.95%
Expected return on plan assets						5.25%
Number of corporate bonds | item										1,160
Pension And OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Regulatory assets							$ 1,166			$ 1,166	$ 786
EFH Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Unfunded liability							101			$ 101
Discount rate						4.19%
Expected return on plan assets						5.38%
Cash contributions					$ 259
Number of corporate bonds | item										415
Defined Benefit Pension Plans [Member]
Defined Benefit Plan Disclosure [Line Items]
Amortization of prior service costs										$ 1
Defined Benefit Plan, Amortization of Gains (Losses)										$ 63
Defined Benefit Pension Plans For 2015 To 2019 [Member]
Defined Benefit Plan Disclosure [Line Items]
Additional cash contributions						$ 373
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	[1]									4.74%	4.10%	5.00%
Expected return on plan assets										6.47%	6.14%	7.40%
Cash contributions						2				$ 68	$ 9	$ 93
Funded status of plans							(925)			(925)	(586)
Expected funding, 2015							45			45
Expected funding, 2015 to 2019							407			407
Defined Benefit Plan, Amortization of Gains (Losses)			$ (16)	$ (10)		(32)		$ (20)		(39)	(69)	(78)
Additional cash contributions						$ 49
OPEB Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate						4.23%
Expected return on plan assets						6.65%
Cash contributions						$ 13
Expected funding, 2015							31			31
Expected funding, 2015 to 2019							$ 156			156
Amortization of prior service costs										20
Defined Benefit Plan, Amortization of Gains (Losses)										$ 33
Additional cash contributions						12
OPEB Plan For 2015 To 2019 [Member]
Defined Benefit Plan Disclosure [Line Items]
Additional cash contributions						$ 147
Oncor Cash Balance Formula Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of employee's contribution match by employer										100.00%
Percentage of employee's contribution matched 100% by employer										6.00%
Oncor Traditional Retirement Plan Formula Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Percentage of employee's contribution match by employer										75.00%
Percentage of employee's contribution matched 100% by employer										6.00%
Thrift Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Cash contributions										$ 13	$ 13	$ 12
[1]	As a result of the 2012 amendments discussed above, the discount rate reflected in net pension costs for January through July 2012 was 5.00%, for August through September 2012 was 4.15% and for October through December 2012 was 4.20%. As

Pension And Other Postretirem53

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Recognized Net Periodic Pension And Benefit Costs) (Details) - USD ($) $ in Millions		2 Months Ended	3 Months Ended			6 Months Ended			7 Months Ended	12 Months Ended
		Sep. 30, 2012	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2012	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Jul. 31, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Discount rate		4.15%			4.20%		4.39%	4.98%	5.00%
Net costs			$ 39	$ 25		$ 78		$ 51		$ 106	$ 132	$ 206
Less amounts deferred principally as property or a regulatory asset			(28)	(16)		(56)		(33)
Net amounts recognized as expense			11	9		22		18
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	[1]									4.74%	4.10%	5.00%
Expected return on plan assets										6.47%	6.14%	7.40%
Rate of compensation increase										3.94%	3.94%	3.81%
Service cost			6	6		12		12		$ 23	$ 26	$ 23
Interest cost			33	33		66		66		132	122	106
Expected return on assets			(29)	(34)		(58)		(68)		(136)	(123)	(109)
Amortization of net loss			16	10		32		20		39	69	78
Settlement charges											1	81
Net costs			26	15		52		30		58	95	179
Less amounts deferred principally as property or a regulatory asset										349	(209)	(54)
Net amounts recognized as expense										$ 407	$ (114)	$ 125
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	[1]									4.98%	4.10%	4.95%
Expected return on plan assets										7.05%	6.70%	6.80%
Service cost			2	1		4		3		$ 6	$ 6	$ 5
Interest cost			11	11		22		22		44	36	39
Expected return on assets			(3)	(3)		(6)		(6)		(12)	(11)	(12)
Amortization of net transition obligation												1
Amortization of prior service cost			(5)	(5)		(10)		(10)		(20)	(20)	(20)
Amortization of net loss			8	6		16		12		30	26	14
Net costs			$ 13	$ 10		$ 26		$ 21		48	37	27
Less amounts deferred principally as property or a regulatory asset										118	(6)	88
Net amounts recognized as expense										$ 166	$ 31	$ 115
[1]	As a result of the 2012 amendments discussed above, the discount rate reflected in net pension costs for January through July 2012 was 5.00%, for August through September 2012 was 4.15% and for October through December 2012 was 4.20%. As

Pension And Other Postretirem54

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Pension And OPEB Plan Costs) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Total benefit costs	$ 39	$ 25	$ 78	$ 51	$ 106	$ 132	$ 206
Less amounts deferred principally as property or a regulatory asset					(69)	(95)	(169)
Net amounts recognized as expense					37	37	37
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total benefit costs	26	15	52	30	58	95	179
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total benefit costs	$ 13	$ 10	$ 26	$ 21	$ 48	$ 37	$ 27

Pension And Other Postretirem55

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Benefit Obligations Recognized In Other Comprehensive Income) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Total recognized as regulatory assets or other comprehensive income	$ (28)	$ (16)	$ (56)	$ (33)
Net amounts recognized as expense	$ 11	$ 9	$ 22	$ 18
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Net loss (gain)					$ 388	$ (139)	$ 110
Amortization of net loss					(39)	(69)	(78)
Settlement charges						(1)	(81)
Curtailment							(5)
Total recognized as regulatory assets or other comprehensive income					349	(209)	(54)
Net amounts recognized as expense					407	(114)	125
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Net loss (gain)					128		83
Amortization of net loss					(30)	(26)	(14)
Amortization of transition obligation (asset)							(1)
Amortization of prior service (costs) credit					20	20	20
Total recognized as regulatory assets or other comprehensive income					118	(6)	88
Net amounts recognized as expense					$ 166	$ 31	$ 115

Pension And Other Postretirem56

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Assumptions Used To Determine Benefit Obligations) (Details)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	3.96%	4.74%	4.10%
Rate of compensation increase	3.29%	3.94%	3.94%
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.23%	4.98%	4.10%

Pension And Other Postretirem57

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Change In Project Benefit Obligations) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at beginning of year			$ 3,379	$ 2,857	$ 2,857	$ 3,038
Service cost	$ 6	$ 6	12	12	23	26	$ 23
Interest cost	33	33	66	66	132	122	106
Settlement charges						(3)
Curtailment							(5)
Actuarial (gain) loss					515	(183)
Benefits paid					(148)	(143)
Projected benefit obligation at end of year					3,379	2,857	3,038
Accumulated benefit obligation at end of year					3,260	2,752
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at beginning of year			1,054	924	924	913
Service cost	2	1	4	3	6	6	5
Interest cost	$ 11	$ 11	$ 22	$ 22	44	36	39
Participant contributions					15	14
Medicare Part D reimbursement						2
Actuarial (gain) loss					128	10
Benefits paid					(63)	(57)
Projected benefit obligation at end of year					$ 1,054	$ 924	$ 913

Pension And Other Postretirem58

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Change In Plan Assets) (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Employer contributions		$ 86	$ 20	$ 104
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of assets at beginning of year	$ 2,454	2,271	2,327
Actual return (loss) on assets		263	80
Employer contributions	2	68	9	93
Settlement charges			(2)
Benefits paid		(148)	(143)
Fair value of assets at end of year		2,454	2,271	2,327
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of assets at beginning of year	$ 161	179	190
Actual return (loss) on assets		12	21
Employer contributions		18	11	11
Participant contributions		15	14
Benefits paid		(63)	(57)
Fair value of assets at end of year		$ 161	$ 179	$ 190

Pension And Other Postretirem59

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Funded Status) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at end of year	$ (3,379)	$ (2,857)	$ (3,038)
Fair value of assets at end of year	2,454	2,271	2,327
Funded status at end of year	(925)	(586)
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation at end of year	(1,054)	(924)	(913)
Fair value of assets at end of year	161	179	$ 190
Funded status at end of year	$ (893)	$ (745)

Pension And Other Postretirem60

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Amounts Recognized In Balance Sheet) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
Accumulated other comprehensive net loss	$ (105)	$ (107)	$ (48)	$ (31)	$ (31)
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Other current liabilities		(4)	(3)
Other noncurrent liabilities		(921)	(583)
Net liability recognized		(925)	(586)
Net loss		619	362
Net regulatory asset recognized		619	362
Accumulated other comprehensive net loss		126	33
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Other noncurrent liabilities		(893)	(745)
Net liability recognized		(893)	(745)
Net loss		316	220
Prior service cost (credit)		(70)	(91)
Net regulatory asset recognized		246	129
Accumulated other comprehensive net loss		$ 2	$ 1

Pension And Other Postretirem61

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Assumed Health Care Cost Trend Rates) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Effect on accumulated postretirement obligation, 1-Percentage Point Increase	$ 161
Effect on accumulated postretirement obligation, 1-Percentage Point Decrease		$ (129)
Effect on postretirement benefits cost, 1-Percentage Point Increase	$ 8
Effect on postretirement benefits cost, 1-Percentage Point Decrease		$ (7)
Not Medicare Eligible [Member]
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	8.00%	8.00%
Rate to which the cost trend is expected to decline (the ultimate trend rate)	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2,022	2,022
Medicare Eligible [Member]
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate assumed for next year	6.50%	7.00%
Rate to which the cost trend is expected to decline (the ultimate trend rate)	5.00%	5.00%
Year that the rate reaches the ultimate trend rate	2,021	2,021

Pension And Other Postretirem62

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Projected Benefit Obligations And Accumulated Benefit Obligations In Excess Of Plan Assets Fair Value) (Details) - USD ($) $ in Millions	Dec. 31, 2014	Dec. 31, 2013
Pension And Other Postretirement Employee Benefits (OPEB) Plans [Abstract]
Projected benefit obligations	$ 3,379	$ 2,857
Accumulated benefit obligations	3,260	2,752
Plan assets	$ 2,454	$ 2,271

Pension And Other Postretirem63

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Target Asset Allocation Ranges By Asset Category) (Details)	12 Months Ended
	Dec. 31, 2014
US Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation, Recoverable, Minimum	19.00%
Target asset allocation, Recoverable, Maximum	25.00%
International Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation, Recoverable, Minimum	14.00%
Target asset allocation, Recoverable, Maximum	20.00%
Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation, Recoverable, Minimum	48.00%
Target asset allocation, Recoverable, Maximum	65.00%
Target asset allocation, Nonrecoverable	100.00%
Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Target asset allocation, Recoverable, Minimum	2.00%
Target asset allocation, Recoverable, Maximum	7.00%

Pension And Other Postretirem64

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Assets Fair Value Measured On Recurring Basis) (Details) - USD ($) $ in Millions		Dec. 31, 2014	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]
Total assets		$ 2,454	$ 2,271
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		2,454	2,271
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		161	179
US Equities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		318	332
US Equities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		58	58
International Equities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		293	344
International Equities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		31	35
Corporate Bond Securities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[1]	1,384	1,265
Corporate Bond Securities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[1]	31	34
US Treasury Securities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		143	108
US Treasury Securities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		1	1
Other [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[2]	157	55
Other [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[2]	35	45
Real Estate [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		39	7
Fair Value, Inputs, Level 1 [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		514	587
Fair Value, Inputs, Level 1 [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		121	131
Fair Value, Inputs, Level 1 [Member] | US Equities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		233	250
Fair Value, Inputs, Level 1 [Member] | US Equities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		54	53
Fair Value, Inputs, Level 1 [Member] | International Equities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		281	337
Fair Value, Inputs, Level 1 [Member] | International Equities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		31	35
Fair Value, Inputs, Level 1 [Member] | Other [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[2]	34	43
Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		1,932	1,677
Fair Value, Inputs, Level 2 [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		40	48
Fair Value, Inputs, Level 2 [Member] | US Equities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		85	82
Fair Value, Inputs, Level 2 [Member] | US Equities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		4	5
Fair Value, Inputs, Level 2 [Member] | International Equities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		12	7
Fair Value, Inputs, Level 2 [Member] | Corporate Bond Securities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[1]	1,384	1,265
Fair Value, Inputs, Level 2 [Member] | Corporate Bond Securities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[1]	31	34
Fair Value, Inputs, Level 2 [Member] | US Treasury Securities [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		143	108
Fair Value, Inputs, Level 2 [Member] | US Treasury Securities [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		1	1
Fair Value, Inputs, Level 2 [Member] | Other [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[2]	157	55
Fair Value, Inputs, Level 2 [Member] | Other [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets	[2]	1	2
Fair Value, Inputs, Level 2 [Member] | Real Estate [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		31
Fair Value, Inputs, Level 3 [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		8	7
Fair Value, Inputs, Level 3 [Member] | Real Estate [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		8	7
Interest-bearing Cash [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		120	160
Interest-bearing Cash [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		5	6
Interest-bearing Cash [Member] | Fair Value, Inputs, Level 1 [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		2
Interest-bearing Cash [Member] | Fair Value, Inputs, Level 2 [Member] | Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		120	160
Interest-bearing Cash [Member] | Fair Value, Inputs, Level 2 [Member] | OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total assets		$ 3	$ 6
[1]	Substantially all corporate bonds are rated investment grade by a major ratings agency such as Moody's.
[2]	Other consists primarily of municipal bonds, emerging market debt, bank loans and fixed income derivative instruments.

Pension And Other Postretirem65

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Expected Long-Term Rate Of Return On Assets Assumptions) (Details)		12 Months Ended
		Dec. 31, 2014
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return	[1]	5.94%
Pension Plan [Member] | International Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		7.50%
Pension Plan [Member] | US Equities [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		6.80%
Pension Plan [Member] | Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		6.10%
Pension Plan [Member] | Credit Strategies [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		4.74%
Pension Plan [Member] | Fixed Income [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		4.40%
Pension Plan [Member] | Oncor Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		3.95%
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		6.65%
OPEB [Member] | 401(h) Accounts [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		6.96%
OPEB [Member] | Life Insurance VEBA [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		6.45%
OPEB [Member] | Union VEBA [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		6.45%
OPEB [Member] | Non-union VEBA [Member]
Defined Benefit Plan Disclosure [Line Items]
Weighted average expected long-term rate of return		2.90%
[1]	The 2015 expected long-term rate of return for the nonregulated portion of the Oncor Retirement Plan is 3.95%.

Pension And Other Postretirem66

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Contributions) (Details) - USD ($) $ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Defined Benefit Plan Disclosure [Line Items]
Total contributions		$ 86	$ 20	$ 104
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Total contributions	$ 2	68	9	93
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Total contributions		$ 18	$ 11	$ 11

Pension And Other Postretirem67

Pension And Other Postretirement Employee Benefits (OPEB) Plans (Schedule Of Estimated Future Benefit Payments) (Details) $ in Millions	Dec. 31, 2014USD ($)
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
2,015	$ 159
2,016	165
2,017	170
2,018	176
2,019	182
2020-24	990
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
2,015	44
2,016	46
2,017	48
2,018	51
2,019	53
2020-24	$ 295

Stock-Based Compensation (Detai

Stock-Based Compensation (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2012	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Exercise payments			$ 4	$ 64
Share-based compensation expense			2	57
SARs Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend accrual compensation expense			6
SARs [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SARs exercise price	$ 14.54
Exercise payments	$ 64
Share-based compensation expense	57
Aggregate dividends	18
Recognized dividend accretion and interest		$ 1	$ 2	$ 1
SARs [Member] | Certain Executive Officers [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Deferred dividends	$ 6
SARs [Member] | SARs Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SARs exercised	14,322,219
SARs [Member] | Director SARs Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
SARs exercised	55,000

Related-Party Transactions (Nar

Related-Party Transactions (Narrative) (Details) - USD ($) $ in Millions	Jul. 30, 2014	Jun. 30, 2014	Aug. 31, 2012	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Sep. 30, 2014
Related Party Transaction [Line Items]
Revenue from related party				$ 224	$ 225	$ 460	$ 465	$ 971	$ 967	$ 962
Interest income									16
Amounts received under the note receivable									20
Administrative and services costs								32	30	32
Shared facilities expense								4	4	5
Delivery fee surcharges								17	16	16
Letter of credit									9
TCEH [Member]
Related Party Transaction [Line Items]
Revenue from related party				1	1	1	1
Electricity delivery fee revenues				224	225	460	465
Note receivable from related party			$ 159
Delivery fee surcharges				4	4	8	8
Letter of credit				9		9		9
EFH Corp [Member]
Related Party Transaction [Line Items]
Revenue from related party								2	$ 2	2
Cash income tax refund 2007 audit											$ 45
Cash income tax refund 2003 to 2006 audit								$ 11
Cash income tax refund 2008 to 2009 audit				8		8
Noncurrent liability related to taxes				4		4
Amounts receivable from members under tax agreement				4		4
Amount received from sale of note to related party			$ 159
Increase (decrease) in membership interest										$ (2)
Administrative and services costs				4	7	9	15
Shared facilities expense				1	1	2	2
Reimbursement payment amount	$ 1	$ 1
Maximum [Member] | EFH Corp [Member]
Related Party Transaction [Line Items]
Shared facilities payments received				$ 1	$ 1	$ 1	$ 1

Related-Party Transactions (Sch

Related-Party Transactions (Schedule Of Accounts Receivable From Related Party) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Trade accounts and other receivables from affiliates - unbilled		$ 52	$ 56
EFH Corp [Member]
Related Party Transaction [Line Items]
Trade accounts and other receivables from affiliates - billed		123	141
Trade accounts and other receivables from affiliates - billed	$ 84	71
Trade accounts and other receivables from affiliates - unbilled	57	52
Trade accounts and other payables to affiliates	(3)	(5)	(6)
Trade accounts and other receivables from affiliates - net	$ 138	$ 118	$ 135

Related-Party Transactions (Amo

Related-Party Transactions (Amounts Payable To (Receivable From) Members In Lieu Of Income Taxes) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Federal income taxes receivable	$ (29)	$ (180)	$ (23)
Texas margin taxes payable	12	24	23
Net payable (receivable)	(17)	(156)
EFH Corp [Member]
Related Party Transaction [Line Items]
Federal income taxes receivable	(23)	(144)	(18)
Texas margin taxes payable	12	24	23
Net payable (receivable)	(11)	(120)	5
Texas Transmission and Investment LLC [Member]
Related Party Transaction [Line Items]
Federal income taxes receivable	(6)	(36)	(5)
Net payable (receivable)	$ (6)	$ (36)	$ (5)

Related-Party Transactions (Cas

Related-Party Transactions (Cash Payments Made To (Received From) Members In Lieu Of Income Taxes) (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended		12 Months Ended
	Sep. 30, 2013	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Related Party Transaction [Line Items]
Federal income taxes			$ (144)	$ 269	[1]	$ 89	[1]	$ (23)	[1]
Texas margin taxes		$ 22	20	22	[2]	12	[2]	21	[2]
Total payments (receipts)		22	164	291		101		(2)
EFH Corp [Member]
Related Party Transaction [Line Items]
Federal income taxes			(115)	215	[1]	78	[1]	(18)	[1]
Texas margin taxes		22	20	22	[2]	12	[2]	21	[2]
Total payments (receipts)		$ 22	135	237		90		3
Income tax payments to members	$ 33
Income tax refunds from members	$ 10
Texas Transmission and Investment LLC [Member]
Related Party Transaction [Line Items]
Federal income taxes			(29)	54	[1]	11	[1]	(5)	[1]
Total payments (receipts)			$ 29	$ 54		$ 11		$ (5)
[1]	Includes $33 million payment made to EFH Corp. in 2013 related to the 1997-2002 IRS appeals settlement.
[2]	Includes $10 million refund received from EFH Corp. in 2013 related to 1997-2001 amended Texas franchise tax returns.

Supplementary Financial Infor73

Supplementary Financial Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Mar. 31, 2014
Supplemental Financial Information [Line Items]
Face value of life insurance policies					$ 167	$ 159
Net cash surrender values					76	71
Unbilled revenue	$ 192		$ 192		$ 182	$ 180
Depreciation expense as percentage of average depreciable property					3.60%	3.70%	3.90%
Aggregate amortization expenses	16	$ 14	32	$ 28	$ 58	$ 53	$ 53
Goodwill	$ 4,064		$ 4,064		4,064	4,064
Uncertain tax positions related to timing of recognition					$ 3	$ 51
Increase (Decrease) in liability for deferred income taxes								$ 16
Reversal of accrued interest and tax								2
Reversal of accrued interest and tax after tax								$ 1
Sales [Member] | TCEH [Member]
Supplemental Financial Information [Line Items]
Concentration Risk Percentage	24.00%	25.00%	24.00%	25.00%	25.00%	27.00%	29.00%
Sales [Member] | Nonaffiliated REP [Member]
Supplemental Financial Information [Line Items]
Concentration Risk Percentage	15.00%	16.00%	16.00%	16.00%	16.00%	15.00%	15.00%
Nonaffiliated Trade Accounts Receivable [Member] | Nonaffiliated REP [Member]
Supplemental Financial Information [Line Items]
Concentration Risk Percentage			13.00%		12.00%	12.00%
Land Easements [Member]
Supplemental Financial Information [Line Items]
Weighted average remaining useful life					85 years
Capitalized Software [Member]
Supplemental Financial Information [Line Items]
Weighted average remaining useful life					3 years
Bondco Exposure [Member]
Supplemental Financial Information [Line Items]
Exposure amount					$ 16	$ 16

Supplementary Financial Infor74

Supplementary Financial Information (Schedule Of Other Income And Deductions) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplementary Financial Information [Abstract]
Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting	$ 1	$ 3	$ 4	$ 6	$ 12	$ 17	$ 23
Other				1	1	1	3
Total other income	1	3	4	7	13	18	26
Professional fees	5	4	7	7	14	10	3
SARs exercise (Note 10)						2	57
Other	2		5		1	3	4
Total other deductions	$ 7	$ 4	$ 12	$ 7	$ 15	$ 15	$ 64

Supplementary Financial Infor75

Supplementary Financial Information (Schedule Of Interest Expense And Related Charges) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplementary Financial Information [Abstract]
Interest expense					$ 355	$ 360	$ 366
Interest expense	$ 85	$ 89	$ 167	$ 178
Amortization of debt issuance costs and discounts					3	21	18
Amortization of debt issuance costs and discounts	1	1	1	2
Allowance for funds used during construction - capitalized interest portion					$ 5	$ 10	$ 10
Allowance for funds used during construction - capitalized interest portion	(2)	(1)	(3)	(3)
Total interest expense and related charges	$ 84	$ 89	$ 165	$ 177

Supplementary Financial Infor76

Supplementary Financial Information (Schedule Of Restricted Cash) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash - Current Assets	$ 64	$ 56	$ 52
Total restricted cash - Noncurrent Assets		16	16
Customer Collections Related To Transition Bonds Used Only To Service Debt And Pay Expenses[Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash - Current Assets		56	52
Reserve For Fees Associated With Transition Bonds [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash - Noncurrent Assets		10	10
Reserve For Shortfalls Of Transition Bond Charges [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total restricted cash - Noncurrent Assets		$ 6	$ 6

Supplementary Financial Infor77

Supplementary Financial Information (Schedule Of Trade Accounts Receivable) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplementary Financial Information [Abstract]
Gross trade accounts and other receivables		$ 531	$ 527
Gross trade accounts and other receivables	$ 573	528
Trade accounts treceivable from TCEH		(121)	(139)
Trade accounts and other receivables from affiliates	(138)	(118)	(135)
Allowance for uncollectible accounts	(5)	(3)	(3)
Trade accounts receivable from nonaffiliates - net	$ 430	$ 407	$ 385

Supplementary Financial Infor78

Supplementary Financial Information (Summary of Investment Balance) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplementary Financial Information [Abstract]
Assets related to employee benefit plans, including employee savings programs	$ 95	$ 94	$ 88
Land	3	3	3
Total investments and other property	$ 98	$ 97	$ 91

Supplementary Financial Infor79

Supplementary Financial Information (Schedule Of Property, Plant And Equipment) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Jun. 30, 2015
Property Plant and Equipment [Line Items]
Total assets in service	$ 18,238	$ 17,056	$ 18,735
Less accumulated depreciation	6,125	5,725	6,332
Net of accumulated depreciation	12,113	11,331	12,403
Construction work in progress	335	556	359
Held for future use	15	15	15
Property, plant and equipment - net	12,463	11,902	$ 12,777
Distribution [Member]
Property Plant and Equipment [Line Items]
Total assets in service	$ 10,423	$ 10,055
Composite depreciation rate	4.10%	4.10%
Avg. life	24 years 7 months 6 days	24 years 7 months 6 days
Transmission [Member]
Property Plant and Equipment [Line Items]
Total assets in service	$ 6,861	$ 6,133
Composite depreciation rate	2.80%	2.80%
Avg. life	35 years 8 months 12 days	35 years 8 months 12 days
Other Assets [Member]
Property Plant and Equipment [Line Items]
Total assets in service	$ 954	$ 868
Composite depreciation rate	9.20%	9.20%
Avg. life	10 years 10 months 24 days	10 years 10 months 24 days

Supplementary Financial Infor80

Supplementary Financial Information (Schedule Of Intangible Assets) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 911	$ 896	$ 825
Accumulated Amortization	360	328	271
Net	551	568	554
Land Easements [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	465	463	440
Accumulated Amortization	88	86	82
Net	377	377	358
Capitalized Software [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	446	433	385
Accumulated Amortization	272	242	189
Net	$ 174	$ 191	$ 196

Supplementary Financial Infor81

Supplementary Financial Information (Schedule Of Estimated Aggregate Amortization Expenses) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Supplementary Financial Information [Abstract]
2,015	$ 64	$ 62
2,016	61	59
2,017	52	51
2,018	47	45
2,019	$ 44	$ 42

Supplementary Financial Infor82

Supplementary Financial Information (Schedule Of Other Noncurrent Liabilities And Deferred Credits) (Details) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplementary Financial Information [Abstract]
Retirement plans and other employee benefits	$ 1,925	$ 1,894	$ 1,399
Uncertain tax positions (including accrued interest)	2	2	56
Amounts payable related to income taxes	17	17	17
Investment tax credits	16	17	20
Other	64	59	62
Total other noncurrent liabilities and deferred credits	$ 2,024	$ 1,989	$ 1,554

Supplementary Financial Infor83

Supplementary Financial Information (Schedule Of Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions		6 Months Ended				12 Months Ended
		Jun. 30, 2015		Jun. 30, 2014		Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplementary Financial Information [Abstract]
Interest		$ 177		$ 178		$ 356	$ 361	$ 378
Capitalized interest		(3)		(3)		(5)	(10)	(10)
Interest		174		175		351	351	368
Federal				144	[1]	269	89	(23)
State		22	[1]	20	[1]	22	12	21
Total amount is lieu of income taxes		22	[1]	164	[1]	291	101	(2)
SARs exercise							4	64
Noncash construction expenditures	[2]	$ 61		$ 37		$ 82	$ 84	$ 103
[1]	See Note 10 for income tax detail.
[2]	Represents end-of-period accruals.

Supplementary Financial Infor84

Supplementary Financial Information (Schedule Of Quarterly Information) (Details) - USD ($) $ in Millions	3 Months Ended									6 Months Ended		12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Supplementary Financial Information [Abstract]
Operating revenues	$ 938	$ 939	$ 1,054	$ 912	$ 917	$ 912	$ 966	$ 857	$ 817	$ 1,884	$ 1,829	$ 3,822	$ 3,552	$ 3,328
Operating income	186	179	247	183	191	190	239	189	180	366	373	800	798	731
Net income	$ 98	$ 94	$ 158	$ 94	$ 104	$ 103	$ 146	$ 96	$ 87	$ 196	$ 197	$ 450	$ 432	$ 349