Oncor Electric Delivery 10-Q 1 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Nov. 01, 2016
Entity Registrant Name	ONCOR ELECTRIC DELIVERY CO LLC
Entity Central Index Key	1,193,311
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		0
Oncor's Management and Board of Directors [Member]
Entity Outstanding Membership Interests		0.22%
Oncor Electric Delivery Holdings Company LLC [Member]
Entity Outstanding Membership Interests		80.03%
Texas Transmission [Member]
Entity Outstanding Membership Interests		19.75%

Condensed Statements of Consoli

Condensed Statements of Consolidated Income - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Operating revenues:
Nonaffiliates	$ 806	$ 793	$ 2,262	$ 2,218
Affiliates	265	279	700	739
Total operating revenues	1,071	1,072	2,962	2,957
Operating expenses:
Wholesale transmission service	224	201	663	595
Operation and maintenance (Note 10)	190	186	542	539
Depreciation and amortization	190	217	593	653
Provision in lieu of income taxes (Note 10)	99	99	211	214
Taxes other than amounts related to income taxes	118	116	338	336
Total operating expenses	821	819	2,347	2,337
Operating income	250	253	615	620
Other income and (deductions) - net (Note 11)	(3)	(9)	(11)	(17)
Nonoperating provision in lieu of income taxes	(1)	(3)	(3)	(6)
Interest expense and related charges (Note 11)	85	84	252	250
Net income	$ 163	$ 163	$ 355	$ 359

Condensed Statements of Consol3

Condensed Statements of Consolidated Comprehensive Income - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Statements Of Consolidated Comprehensive Income [Abstract]
Net income	$ 163	$ 163	$ 355	$ 359
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
Defined benefit pension plans (net of tax benefit of $–, $–, $– and $–) (Note 9)			1	1
Total other comprehensive income	1	1	2	2
Comprehensive income	$ 164	$ 164	$ 357	$ 361

Condensed Statements Of Consol4

Condensed Statements Of Consolidated Comprehensive Income (Parenthetical) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Statements Of Consolidated Comprehensive Income [Abstract]
Cash flow hedges - derivative value net loss recognized in net income, tax expense
Defined benefit pension plans- net tax benefit

Condensed Statements Of Consol5

Condensed Statements Of Consolidated Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash flows - operating activities:
Net income	$ 355	$ 359
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization	629	686
Provision in lieu of deferred income taxes - net	166	(65)
Other - net	(3)	(2)
Changes in operating assets and liabilities:
Regulatory accounts related to reconcilable tariffs (Note 4)	(60)	41
Other operating assets and liabilities	(127)	34
Cash provided by operating activities	960	1,053
Cash flows - financing activities:
Issuances of long-term debt (Note 6)	175	725
Repayments of long-term debt (Note 6)	(41)	(594)
Net increase in short-term borrowings (Note 5)	40	(3)
Distributions to members (Note 8)	(189)	(283)
Debt discount, premium, financing and reacquisition expenses - net	11	(11)
Cash used in financing activities	(4)	(166)
Cash flows - investing activities:
Capital expenditures (Note 10)	(1,004)	(893)
Other - net	47	20
Cash used in investing activities	(957)	(873)
Net change in cash and cash equivalents	(1)	14
Cash and cash equivalents - beginning balance	25	4
Cash and cash equivalents - ending balance	$ 24	$ 18

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Millions		Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents		$ 24	$ 25
Restricted cash - Bondco (Note 11)		0	38
Trade accounts receivable from nonaffiliates - net (Note 11)		450	388
Trade accounts and other receivables from affiliates - net (Note 10)		146	118
Amounts receivable from members related to income taxes (Note 10)		107	136
Materials and supplies inventories - at average cost		91	82
Prepayments and other current assets		97	89
Total current assets		915	876
Investments and other property (Note 11)		102	97
Property, plant and equipment - net (Note 11)		13,617	13,024
Goodwill (Notes 11)		4,064	4,064
Regulatory assets - net (Note 4)		1,114	1,194
Other noncurrent assets		41	32
Total assets		19,853	19,287
Current liabilities:
Short-term borrowings (Note 5)		880	840
Long-term debt due currently (Note 6)	[1]	324
Trade accounts payable (Note 10)		205	150
Amounts payable to members related to income taxes (Note 10)		15	20
Accrued taxes other than amounts related to income		156	181
Accrued interest		69	82
Other current liabilities		139	144
Total current liabilities		1,788	1,458
Long-term debt, less amounts due currently (Note 6)	[1]	5,513	5,646
Liability in lieu of deferred income taxes (Note 10)		2,773	2,612
Employee benefit obligations and other (Note 10 and 11)		2,103	2,063
Total liabilities		12,177	11,779
Commitments and contingencies (Note 7)
Membership interests (Note 8):
Capital account — number of interests outstanding 2016 and 2015 - 635,000,000		7,787	7,621
Accumulated other comprehensive loss		(111)	(113)
Total membership interests		7,676	7,508
Total liabilities and membership interests		$ 19,853	19,287
Bondco [Member]
Current liabilities:
Long-term debt due currently (Note 6)	[2]		$ 41
[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 were nonrecourse to Oncor and were issued to securitize a regulatory asset.

Condensed Consolidated Balance7

Condensed Consolidated Balance Sheets (Parenthetical) - shares	Sep. 30, 2016	Dec. 31, 2015
Condensed Consolidated Balance Sheets [Abstract]
Capital account, interests outstanding	635,000,000	635,000,000

Business and Significant Accoun

Business and Significant Accounting Policies	9 Months Ended
	Sep. 30, 2016
Business And Significant Accounting Policies [Abstract]
BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES	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 Bondco, 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 that sell power in the north-central, eastern and western parts of Texas. The services to REPs included subsidiaries of TCEH through the date of the Reorganized TCEH Spin-Off and subsidiaries of Reorganized TCEH after the date of the Reorganized TCEH Spin- Off . Revenues from TCEH represented 24% and 25% of our total operating revenues for the nine months ended September 30, 2016 and 2015, 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 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. The 2003 Series transition bonds matured and were paid in full in 2015 and the 2004 Series transition bonds matured and were paid in full in May 2016. Final true-up proceedings and refunds of over-collected transition charges for the transition bonds are being conducted by Oncor and the PUCT during 2016 and are expected to have minimal or no net income impact.  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, 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, the Debtors 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  These unaudited condensed financial statements should be read in conjunction with the audited financial statements and related notes included in the 2015 Form 10-K. In the opinion of Oncor management, all adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been made. All intercompany items and transactions have been eliminated in consolidation. 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 U . S . 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. 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 February 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update 2016-2 (ASU 2016-2), Leases . ASU 2016-2 amends previous GAAP to require the balance sheet recognition of lease assets and liabilities for operating leases. Oncor will be required to adopt ASU 2016-2 by January 1, 2019 and does not expect to early adopt. Retrospective application to the 2017 and 2018 comparative periods presented will be required in the year of adoption. We continue to evaluat e the impact of ASU 2016-2 on our financial statements. Since May 2014, the FASB has issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers along with other supplemental guidance (together, Topic 606). Topic 606 introduces new, increased requirements for disclosure of revenue in financial statements and guidance that are intended to eliminate inconsistencies in the recognition of revenue. O n cor will be required to adopt Topic 606 by January 1, 2018 and does not expect to early adopt. We continue to evaluate the impact on our financial statements. At this time, the adoption 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	9 Months Ended
	Sep. 30, 2016
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 at the time, 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 our 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. As of September 30, 2016, we had collected $128 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 ha d not been established as of September 30, 2016. As discussed below, the New Plan of Reorganization (defined below) provided for a spin-off of the TCEH Debtors from EFH Corp. As a result of this s pin- o ff, Reorganized TCEH and its subsidiaries, including Luminant and TXU Energy, ceased to be affiliates of ours as of October 3, 2016.  The EFH Bankruptcy Proceedings continue to be a complex litigation matter and the full extent of potential impacts on us remain unknown. 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 Oncor’s related-party transactions with members of the Texas Holdings Group.  Potential Change in Indirect Ownership of Oncor  As part of the EFH Bankruptcy Proceedings, the bankruptcy court confirmed the Debtors’ Sixth Amended Plan of Reorganization by order dated December 9, 2015. In general, among other things, the Sixth Amended Plan of Reorganization provided for a series of transactions to be effected pursuant to a merger and purchase agreement (Hunt Merger and Purchase Agreement) with an investor group consisting of certain unsecured creditors of TCEH and an affiliate of Hunt Consolidated, Inc. (Hunt), as well as certain other investors designated by Hunt (collectively, the Hunt Investor Group), that would have led to a significant change in the indirect equity ownership of Oncor.  The Debtors and certain creditors entered into a Plan Support Agreement (as amended, Plan Support Agreement) that provided for, among other things, their respective obligations to act and/or support Plans of Reorganization. On May 1, 2016, certain first lien creditors of TCEH delivered a written notice (Plan Support Termination Notice) to the Debtors and the other parties to the Plan Support Agreement notifying such parties of the occurrence of a Plan Support Termination Event (as defined in the Plan Support Agreement). The delivery of the Plan Support Agreement Termination Notice caused the Sixth Amended Plan of Reorganization to become null and void.  On May 1, 2016, following receipt of the Plan Support Termination Notice, EFH Corp. and EFIH delivered a written notice (Merger and Purchase Agreement Termination Notice) to the Hunt Investor Group notifying the Hunt Investor Group that EFH Corp. and EFIH terminated the Hunt Merger and Purchase Agreement. The termination of the Hunt Merger and Purchase Agreement also caused the automatic termination (without the necessity of further action) of (i) certain agreements defining the investment obligations of certain Hunt Investor Group members, and (ii) a letter agreement between Oncor and the Hunt Investor Group.  Following the occurrence of the Plan Support Termination Event as described above, the Debtors filed a new joint Plan of Reorganization (New Plan of Reorganization) pursuant to Chapter 11 of the Bankruptcy Code and a related disclosure statement with the bankruptcy court on May 1, 2016.  In connection with the Sixth Amended Plan of Reorganization, EFH Corp. took the position that, unless the Hunt Investor Group had otherwise acquired, or entered into a definitive agreement with Texas Transmission for the acquisition of the equity interest in Oncor held by Texas Transmission at the consummation of the transactions, certain of EFH Corp.’s rights contained in the Investor Rights Agreement (Investor Rights Agreement), dated November 2008 among Oncor and certain of its direct and indirect equity holders, including EFH Corp. and Texas Transmission, would require Texas Transmission to sell its equity interest in Oncor to the Hunt Investor Group. In this regard, in October 2015, EFH Corp. filed a complaint against Texas Transmission alleging breach of Texas Transmission’s obligations under the Investor Rights Agreement for failing to agree to sell its equity interest in Oncor and, if found to be a valid drag right and a valid IPO Conversion (as defined in the Investor Rights Agreement), to cooperate with an IPO Conversion.  The Hunt Investor Group intervened in the pending litigation. On May 20, 2016, following the Plan Support Termination Notice, the bankruptcy court issued an order dismissing the action and related motions and retaining jurisdiction related to the interpretation and implementation of such order. We cannot predict the ultimate outcome of any subsequent litigation relating to the Investor Rights Agreement and the impact of such litigation, particularly in light of the transactions discussed below.  The New Plan of Reorganization provides that the confirmation and effective date of the New Plan of Reorganization with respect to the TCEH Debtors may occur (and on October 3, 2016, it did occur) separate from, and independent of, the confirmation and effective date of the New Plan of Reorganization with respect to the EFH Debtors. The New Plan of Reorganization, subject to certain conditions and required regulatory approvals, provides for, among other things:  · with respect to the TCEH Debtors, either (a) a tax-free spin-off from EFH Corp., including a transaction that will result in a partial step-up in the tax basis of certain TCEH assets distributed to a newly formed entity wholly owned by TCEH, or (b) a taxable transaction that results in the assets of the TCEH Debtors being distributed to a newly formed entity wholly owned by Reorganized TCEH (TCEH Transactions), and  · with respect to the EFH Debtors, the reorganization of EFH Corp. and EFIH (Reorganized EFH) either pursuant to (a) an equity investment (which may be from existing creditors or third-party investors) or (b) pursuant to a standalone plan of reorganization, in which creditors receive shares of common stock of Reorganized EFH.  Solely as it pertains to the TCEH Debtors, the disclosure statement was approved by the bankruptcy court. The bankruptcy court confirmed the New Plan of Reorganization with respect to the TCEH Debtors on August 26, 2016, and it became effective by its terms, and the Reorganized TCEH Spin-Off occurred effective October 3, 2016.  On July 29, 2016, (i) the EFH Debtors entered into a Plan Support Agreement (NEE Plan Support Agreement) with NextEra Energy, Inc. (NEE) to effect an agreed upon restructuring of the EFH Debtors pursuant to an amendment to the New Plan of Reorganization (Amended New Plan) and (ii) EFH Corp. and EFIH entered into an Agreement and Plan of Merger (NEE Merger Agreement) with NEE and EFH Merger Co., LLC (Merger Sub), a wholly-owned subsidiary of NEE. Pursuant to the NEE Merger Agreement, at the effective time of the Amended New Plan with respect to the EFH Debtors, EFH Corp. will merge with and into Merger Sub (NEE Merger) with Merger Sub surviving as a wholly owned subsidiary of NEE.  In August 2016, the EFH Debtors filed a motion seeking bankruptcy court approval of entry into the NEE Merger Agreement, a related termination fee and the NEE Plan Support Agreement. The NEE Merger Agreement includes various conditions precedent to consummation of the transactions contemplated thereby, including, among others, a condition that certain approvals and rulings be obtained, including from, among others, the PUCT and the IRS and a condition that the TCEH Transactions have occurred. NEE will not be required to consummate the NEE Merger if, among other items, the PUCT approval is obtained but with conditions, commitments or requirements that impose a Burdensome Condition (as defined in the NEE Merger Agreement). NEE’s and Merger Sub’s obligations under the NEE Merger Agreement are not subject to any financing condition. The bankruptcy court approved EFH Corp. and EFIH’s entry into the NEE Merger Agreement, the related termination fee, and the NEE Plan Support Agreement by order dated September 19, 2016.  Following approval of the NEE Merger Agreement by the bankruptcy court and until confirmation of the Amended New Plan by the bankruptcy court, EFH and EFIH may continue or have discussions or negotiations with respect to acquisition proposals for Reorganized EFH (x) with persons that were in active negotiation at the time of approval of the NEE Merger Agreement by the bankruptcy court and (y) with persons that submit an unsolicited acquisition proposal that is, or is reasonably likely to lead to, a Superior Proposal (as defined in the NEE Merger Agreement). The NEE Merger Agreement may be terminated upon certain events, including, among other things: · by either party, if the NEE Merger is not consummated by March 26, 2017, subject to a 90 -day extension under certain conditions; or · by EFH Corp. or EFIH, until the entry of the confirmation order of the Amended New Plan with respect to the EFH Debtors, if their respective board of directors or managers determines after consultation with its independent financial advisors and outside legal counsel, and based on advice of such counsel, that the failure to terminate the NEE Merger Agreement is inconsistent with its fiduciary duties; provided that a material breach of EFH Corp.’s or EFIH’s obligations under certain provisions of the NEE Merger Agreement has not provided the basis for such determination. If the NEE Merger Agreement is terminated for certain reasons set forth therein and an alternative transaction is consummated by EFH or EFIH in which neither NEE nor any of its affiliates obtains direct or indirect ownership of approximately 80% of Oncor, then EFH and EFIH will pay a termination fee of $275,000,000 to NEE.  Following the execution and delivery of the NEE Merger Agreement, EFIH requested, pursuant to the NEE Merger Agreement, that Oncor Holdings and Oncor enter into a letter agreement (NEE Letter Agreement) with NEE and Merger Sub. The NEE Letter Agreement was executed on August 4, 2016 and sets forth certain rights and obligations of the Oncor Ring-Fenced Entities, NEE and Merger Sub to cooperate in the manner set forth therein with respect to initial steps to be taken in connection with the acquisition of Reorganized EFH (EFH Acquisition) and the other transactions described in the NEE Merger Agreement. The NEE Letter Agreement is not intended to give NEE or Merger Sub, directly or indirectly, the right to control or direct the operations of any of the Oncor Ring-Fenced Entit ies prior to the receipt of all approvals required by the bankruptcy court, the PUCT and other governmental entities and the consummation of the EFH Acquisition and related transactions (if and when such transactions are consummated). In addition, Oncor Holdings and Oncor have not endorsed or approved any restructuring involving Oncor Holdings or Oncor or any other transaction proposed by NEE or Merger Sub involving Oncor Holdings or Oncor.  On October 29, 2016, we entered into an Interest Purchase Agreement (OMI Agreement) with T & D Equity Acquisition, LLC, a wholly-owned subsidiary of NEE (T&D Equity Acquisition) and Investment LLC pursuant to which T&D Equity Acquisition would purchase the 1,396,008 limited liability company interests of Oncor that Investment LLC owns in exchange for a purchase price of approximately $27 million. The OMI Agreement contains various conditions precedent to consummation of the transactions contemplated thereby, including the consummation of the transactions contemplated by the NEE Merger Agreement.  On October 30, 2016, an affiliate of NEE entered into an Agreement and Plan of Merger (the TTI Merger Agreement) with Texas Transmission Holdings Corporation (the parent of Texas Transmission) and certain of its affiliates to purchase Texas Transmission's 19.75% equity interest in Oncor for approximately $2.4 billion. The parties have agreed to use their best efforts to have the TTI Merger Agreement close contemporaneously with the NEE Merger. The TTI Merger Agreement also contains various conditions precedent to consummation of the transactions contemplated thereby, including a requirement that EFH Corp., subject to bankruptcy court approval, waive its rights of first refusal under the Investor Rights Agreement to purchase Texas Transmission's 19.75% equity interest in Oncor.  Notwithstanding these pending transactions, we cannot predict the ultimate outcome of the EFH Bankruptcy Proceedings, including whether the transactions contemplated by any Plan of Reorganization, including the EFH Acquisition, will (or when they will) close. In this regard, we cannot predict how any reorganization of EFH Corp. and EFIH ultimately will impact Oncor or what form any change in indirect ownership of Oncor may take. On September 19, 2016, the b ankruptcy c ourt approved the d isclosure s tatement as it relates to the EFH Debtors. The confirmation hearing for the New Plan of Reorganization as it relates to the EFH Debtors is scheduled to commence on December 1, 2016.  Regulatory Matters Related to EFH Bankruptcy Proceedings  In September 2015, Oncor and the Hunt Investor Group filed in PUCT Docket No. 45188 a joint application with the PUCT seeking certain regulatory approvals with respect to the transactions contemplated by the Sixth Amended Plan of Reorganization. On March 24, 2016, the PUCT issued an order conditionally approving the joint application. On April 18, 2016, the Hunt Investor Group and certain interveners in PUCT Docket No. 45188 filed motions for rehearing and on May 19, 2016, the PUCT denied such motions and the order became final. The Hunt Investor Group filed a petition with the Travis County District Court on June 17, 2016 seeking review of the order. We cannot predict the results of the review or the ultimate disposition of PUCT Docket No. 45188, particularly in light of the termination of the Sixth Amended Plan of Reorganization and the other pending transactions discussed above.  In connection with PUCT Docket No. 45188, certain cities that have retained original jurisdiction over electric utility rates passed resolutions directing Oncor to file rate review proceedings. For more information, see Note 3 – “City Rate Reviews”.  The NEE Merger Agreement contemplates that Oncor and NEE file a joint application with the PUCT seeking certain regulatory approvals with respect to the transactions contemplated by the Amended New Plan. On October 31, 2016, Oncor and NEE filed that joint application in PUCT Docket No. 46238.  Settlement Agreement  In connection with the EFH Bankruptcy Proceedings, the EFH Debtors and various creditor parties entered into a settlement agreement (the Settlement Agreement) in August 2015 (as amended in September 2015) to compromise and settle, among other things (a) intercompany claims among the EFH Debtors, (b) claims and causes of actions against holders of first lien claims against TCEH and the agents under the TCEH Senior Secured Facilities, (c) claims and causes of action against holders of interests in EFH Corp. and certain related entities and (d) claims and causes of action against each of the EFH Debtors' current and former directors, the Sponsor Group, managers and officers and other related entities. The Settlement Agreement contemplates a release of such claims upon approval of the Settlement Agreement by the bankruptcy court, which approval was obtained in December 2015.  The Settlement Agreement settles substantially all inter-debtor claims through the effective date of the Settlement Agreement. These settled claims include potentially contentious inter-debtor claims, including various potential avoidance actions and claims arising under numerous debt agreements, tax sharing agreements, and contested property transfers. The release provisions of the Settlement Agreement took effect immediately upon the entry of the bankruptcy court order approving the Settlement Agreement. In this regard, substantially all of the potential affiliate claims, derivative claims and other types of disputes among affiliates (including claims against Oncor) have been resolved by bankruptcy court order. Accordingly, we believe the Settlement Agreement resolves all affiliate claims against Oncor and its assets existing as of the effective date of the Settlement Agreement . 

Regulatory Matters

Regulatory Matters	9 Months Ended
	Sep. 30, 2016
Regulatory Matters [Abstract]
REGULATORY MATTERS	3. REGULATORY MATTERS  Change in Control Review s  In September 2015, Oncor and the Hunt Investor Group filed in PUCT Docket No. 45188 a joint application with the PUCT seeking certain regulatory approvals with respect to the transactions contemplated by the Sixth Amended Plan of Reorganization. On March 24, 2016, the PUCT issued an order conditionally approving the joint application. On April 18, 2016, the Hunt Investor Group and certain interveners in PUCT Docket No. 45188 filed motions for rehearing and on May 19, 2016, the PUCT denied such motions and the order became final. The Hunt Investor Group filed a petition with the Travis County District Court on June 17, 2016 seeking review of the order. We cannot predict the results of the review or the ultimate disposition of PUCT Docket No. 45188, particularly in light of the termination of the Sixth Amended Plan of Reorganization and the other pending transactions discussed in Note 2 to Financial Statements. For additional information regarding the Sixth Amended Plan of Reorganization and application for regulatory approval, see Note 2 to Financial Statements and “City Rate Reviews” below.  The NEE Merger Agreement contemplates that Oncor and NEE file a joint application with the PUCT seeking certain regulatory approvals with respect to the transactions contemplated by the Amended New Plan. On October 31, 2016, Oncor and NEE filed that joint application in PUCT Docket No. 46238. For additional information regarding the Amended New Plan and application for regulatory approval, see Note 2 to Financial Statements.  City Rate Reviews  Oncor has received resolutions passed by approximately 58 cities with original jurisdiction over electric utility rates directing Oncor to file rate review proceedings. The resolutions passed required Oncor to file a rate review with each city by September 1, 2016 based on a January 1, 2015 to December 31, 2015 test year. However, Oncor has subsequently been notified by counsel representing these cities that these rate review proceedings have been abated indefinitely, pending resolution of Oncor ownership issues. The notice provides that if and when the cities desire to proceed with a rate inquiry, cities will notify Oncor in writing and inform Oncor of a precise date of the rate case, which will be at least 120 days from receipt of the communication that lifts the abatement.  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 (PUCT Docket No. 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. The Texas Supreme Court granted the petition for review and heard oral arguments in September 2016. 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 a $135 million loss (after tax) including interest . Interest accrues at the PUCT approved rate for over-collections, which is 0.18% for 2016. 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 2015 Form 10-K for additional information regarding regulatory matters.

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	9 Months Ended
	Sep. 30, 2016
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  September 30, 2016 September 30, 2016 December 31, 2015   Regulatory assets:  Generation-related regulatory assets securitized by transition bonds (a)(d) - $ - $ 31  Employee retirement costs being amortized 3 years 27 38  Unrecovered employee retirement costs incurred since the last rate review period (b) To be determined 318 291  Employee retirement liability (a)(b)(c) To be determined 812 853  Self-insurance reserve (primarily storm recovery costs) being amortized ― net 3 years 72 95  Unrecovered self-insurance reserve incurred since the last rate review period ― net (b) To be determined 374 332  Securities reacquisition costs (pre-industry restructure) 1 year or less 6 14  Securities reacquisition costs (post-industry restructure) ― net Lives of related debt 10 9  Recoverable amounts in lieu of deferred income taxes ― net Life of related asset or liability 3 12  Deferred conventional meter and metering facilities depreciation Largely 4 years 83 100  Under-recovered AMS costs To be determined 194 164  Energy efficiency performance bonus (a) 1 year or less 12 10  Under-recovered wholesale transmission service expense (a) 1 year or less 15 -  Other regulatory assets Various 8 9  Total regulatory assets 1,934 1,958   Regulatory liabilities:  Estimated net removal costs Lives of related assets 782 686  Investment tax credit and protected excess deferred taxes Various 10 14  Over-collection of transition bond charges (a)(d) 1 year or less 6 29  Over-recovered wholesale transmission service expense (a) 1 year or less - 24  Energy efficiency programs (a) Not applicable 22 11  Total regulatory liabilities 820 764  Net regulatory asset $ 1,114 $ 1,194 ____________ (a) Not earning a return in the regulatory rate-setting process. (b) Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review. (c) Represents unfunded liabilities recorded in accor dance with pension and OPEB accounting standards. (d) Bondco net regulatory liabilities at September 30, 2016 were zero ( excludes $6 million of over -collections related to transition bonds assumed by Oncor for final settlement). Bondco net regulatory assets of $10 million at December 31, 2015 consisted of $31 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $21 million (excludes $8 million of over-collections related to transition bonds assumed by Oncor for final settlement).

Borrowings Under Credit Facilit

Borrowings Under Credit Facilities	9 Months Ended
	Sep. 30, 2016
Borrowings Under Credit Facilities [Abstract]
BORROWINGS UNDER CREDIT FACILITIES	5. BORROWINGS UNDER CREDIT FACILITIES  At September 30, 2016, we had a $2.0 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. In October 2016, we exercised the second of two one -year extensions available to us and extended the term of the revolving credit facility to October 2018 . The terms of the revolving credit facility allow us to request an increase in our borrowing capacity of $100 million in the aggregate 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 September 30, 2016, we had outstanding borrowings under the revolving credit facility totaling $880 million with an interest rate of 1.52% and outstanding letters of credit totaling $7 million. At December 31, 2015, we had outstanding borrowings under the revolving credit facility totaling $840 million with an interest rate of 1.48% 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 September 30, 2016, all outstanding borrowings bore interest at LIBOR plus 1.00% . 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 September 30, 2016, letters of credit bore interest at 1.20% , and a commitment fee (at a rate of 0.10% 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 September 30, 2016 and December 31, 2015 was $1.113 billion and $1.153 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 indeb tedness (including borrowings under our revolving credit facility) with the lien of the Deed of Trust. At September 30, 2016 , 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 GAAP). The debt calculation excludes any outstanding transition bonds issued by Bondco, but includes any unamortized fair value discount related to Bondco. Capitalization is calculated as membership interests determined in accordance with GAAP plus indebtedness described above. At September 30, 2016 , we were in compliance with this covenant and with all other covenants . 

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2016
Long-Term Debt [Abstract]
LONG-TERM DEBT	6. LONG-TERM DEBT  At September 30, 2016 and December 31, 2015 , our long-term debt consisted of the following:   September 30, December 31,  2016 2015   Oncor (a):  5.000% Fixed Senior Notes due September 30, 2017 $ 324 $ 324  6.800% Fixed Senior Notes due September 1, 2018 550 550  2.150% Fixed Senior Notes due June 1, 2019 250 250  5.750% Fixed Senior Notes due September 30, 2020 126 126  4.100% Fixed Senior Notes due June 1, 2022 400 400  7.000% Fixed Debentures due September 1, 2022 800 800  2.950% Fixed Senior Notes due April 1, 2025 350 350  7.000% Fixed Senior Notes due May 1, 2032 500 500  7.250% Fixed Senior Notes due January 15, 2033 350 350  7.500% Fixed Senior Notes due September 1, 2038 300 300  5.250% Fixed Senior Notes due September 30, 2040 475 475  4.550% Fixed Senior Notes due December 1, 2041 400 400  5.300% Fixed Senior Notes due June 1, 2042 500 500  3.750% Fixed Senior Notes due April 1, 2045 550 375  Unamortized discount and debt issuance costs (38) (54)  Less amount due currently (324) -  Long-term debt, less amounts due currently — Oncor 5,513 5,646   Bondco (b):  5.290% Fixed Series 2004 Bonds due May 15, 2016 - 41  Total - 41  Less amount due currently - (41)  Long-term debt, less amounts due currently — Bondco - -  Total long-term debt, less amounts due currently $ 5,513 $ 5,646 __________ (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 were nonrecourse to Oncor and were issued to securitize a regulatory asset.  Debt-Related Activity in 201 6  Debt Repayments  Rep ayments of long-term debt in the nine months ended September 30, 2016 totaled $41 million, representing the final transition bond principal payment at the scheduled maturity date.  Issuance of Senior Secured Notes  In August 2016, we completed the sale of $175 million aggregate principal amount of 3.75% senior secured notes maturing in April 2045 (Additional 2045 Notes). The Additional 2045 Notes were an additional issuance of our 3.75% senior secured notes maturing in April 2045, $375 million aggregate principal amount of which were previously issued in March 2015 (2045 Notes). The Additional 2045 Notes were issued as part of the same series as the 2045 Notes. We used the net proceeds of approximately $185 million from the sale of the Additional 2045 Notes to repay borrowings under our revolving credit facility and for general corporate purposes. The Additional 2045 Notes and 2045 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 2045 Notes is payable in cash semiannually in arrears on April 1 and October 1 of each year, beginning on October 1, 2016 . We may at our option redeem the Additional 2045 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 October 1, 2044 , a make-whole premium. The Additional 2045 Notes also contain customary events of default, including failure to pay principal or interest on the notes when due.  The Additional 2045 Notes were issued in a private placement and were not registered under the Securities Act of 1933, as amended. We have agreed, subject to certain exceptions, to register with the SEC notes having substantially identical terms as the Additional 2045 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 Additional 2045 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 Additional 2045 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 Additional 2045 Notes or the exchange offer is not completed within 315 days after the issue date of the Additional 2045 Notes (an exchange default), then the annual interest rate on the Additional 2045 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 Additional 2045 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 September 30, 2016 , the amount of available bond credits was $2.534 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 $1.586 billion.  Fair Value of Long-Term Debt  At September 3 0 , 2016 and December 31, 2015, the estimated fair value of our long-term debt (including current maturities, if any) totaled $7.112 billion and $6.287 billion, respectively, and the carrying amount totaled $5.837 billion and $5.687 billion, respectively. The fair value is estimated using observable market data, representing Level 2 valuations under accounting standards related to the determination of fair value.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2016
Commitments and Contingencies [Abstract]
COMMITMENTS AND CONTINGENCIES	7. COMMITMENTS AND CONTINGENCIES  EFH Bankruptcy Proceedings  On the EFH Petition Date, the EFH Debtors commenced the EFH Bankruptcy Proceedings . 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 2015 Form 10-K for additional information regarding our legal and regulatory proceedings. 

Membership Interests

Membership Interests	9 Months Ended
	Sep. 30, 2016
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 periodically by the PUCT for ratemaking purposes, which is currently set at 60% debt to 40% equity. At September 30, 2016, $69 million was available for distribution to our members as our regulatory capitalization ratio was 59.6% debt to 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. Equity is calculated as membership interests determined in accordance with 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 October 2 6 , 2016, our board of directors declared a cash distribution of $ 41 million, which was paid to our members on October 27, 2016 . During the nine months ended September 30, 2016, our board of directors declared, and we paid, the following cash distributions to our members:    Declaration Date Payment Date Amount  July 27, 2016 August 11, 2016 $ 68  April 27, 2016 May 11, 2016 $ 65  February 24, 2016 February 25, 2016 $ 56  Membership Interests  The following table present s the changes to membership interests during the nine months ended September 30, 2016 and 2015 :    Capital Accounts Accumulated Other Comprehensive Income (Loss) Total Membership Interests   Balance at December 31, 2015 $ 7,621 $ (113) $ 7,508  Net income 355 - 355  Distributions (189) - (189)  Net effects of cash flow hedges (net of tax) - 1 1  Defined benefit pension plans (net of tax) - 1 1  Balance at September 30, 2016 $ 7,787 $ (111) $ 7,676   Balance at December 31, 2014 $ 7,625 $ (107) $ 7,518  Net income 359 - 359  Distributions (283) - (283)  Net effects of cash flow hedges (net of tax) - 1 1  Defined benefit pension plans (net of tax) - 1 1  Balance at September 30, 2015 $ 7,701 $ (105) $ 7,596  Accumulated Other Comprehensive Income (Loss)  The following table present s the changes to accumulated other comprehensive income (loss) for the nine months ended September 30 , 2016 and 2015:   Cash Flow Hedges – Interest Rate Swap Defined Benefit Pension and OPEB Plans Accumulated Other Comprehensive Income (Loss)   Balance at December 31, 2015 $ (22) $ (91) $ (113)  Defined benefit pension plans (net of tax) - 1 1  Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges 1 - 1  Balance at September 30, 2016 $ (21) $ (90) $ (111)   Balance at December 31, 2014 $ (24) $ (83) $ (107)  Defined benefit pension plans (net of tax) - 1 1  Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges 1 - 1  Balance at September 30, 2015 $ (23) $ (82) $ (105) 

Pension and OPEB Plans

Pension and OPEB Plans	9 Months Ended
	Sep. 30, 2016
Pension And Other Postretirement Employee Benefits Plans [Abstract]
PENSION AND OPEB PLANS	9. PENSION AND OPEB PLANS  Pension Plans  We sponsor the Oncor Retirement Plan and also have liabilities under the EFH Retirement Plan, both of which are qualified pension plans under Section 401(a) of the Internal Revenue Code of 1986, as amended, and are subject to the provisions of ERISA. Employees do not contribute to either plan. We also have a supplemental pension plan for certain employees whose retirement benefits cannot be fully earned under the qualified retirement plans. See Note 10 to Financial Statements in our 2015 Form 10-K for additional information regarding pension plans.  Oncor OPEB Plan  The Oncor OPEB Plan covers 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. At September 30, 2016, EFH Corp. retain ed its portion of the liability for retiree benefits related to those retirees. 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. See Note 10 to Financial Statements in our 2015 Form 10-K for additional information.  Pension and OPEB Costs  Our net costs related to pension plans and the Oncor OPEB P lan for the three and nine months ended September 30, 2016 and 2015 were comprised of the following:   Three Months Ended September 30, Nine Months Ended September 30,  2016 2015 2016 2015   Components of net allocated pension costs:  Service cost $ 6 $ 6 $ 18 $ 18  Interest cost 33 33 101 99  Expected return on assets (30) (29) (92) (87)  Amortization of net loss 10 16 30 48  Net pension costs 19 26 57 78  Components of net OPEB costs:  Service cost 2 2 6 6  Interest cost 12 11 36 33  Expected return on assets (2) (3) (6) (9)  Amortization of prior service cost (5) (5) (15) (15)  Amortization of net loss 9 8 26 24  Net OPEB costs 16 13 47 39  Total net pension and OPEB costs 35 39 104 117  Less amounts deferred principally as property or a regulatory asset (25) (28) (75) (84)  Net amounts recognized as expense $ 10 $ 11 $ 29 $ 33  The discount rates reflected in net pension and OPEB costs in 201 6 are 4.28% , 4.57% and 4.60% for the Oncor Retirement Plan, the EFH Retirement Plan and the Oncor OPEB P lan, respectively. The expected return on pension and OPEB p lan assets reflected in the 201 6 cost amounts are 5.53% , 5.64% and 6.30% for the Oncor Retirement Plan, the EFH Retirement Plan and the Oncor OPEB P lan, respectively.  Pension and OPEB Plans Cash Contributions  We made cash contribution s to the pension plans and Oncor OPEB P lan of $3 million and $22 million, respectively, during the nine months ended September 3 0 , 2016 . We expect to make additional cash contributions to the pension plans and Oncor OPEB Plan of $1 million and $ 16 million, respectively, during the remainder of 2016 . Our aggregate pension plans and Oncor OPEB Plan funding is expected to total approximately $479 million and $1 60 million, respectively, in the 2016 to 2020 period based on the latest actuarial projections.

Related-Party Transactions

Related-Party Transactions	9 Months Ended
	Sep. 30, 2016
Related-Party Transactions [Abstract]
RELATED-PARTY TRANSACTIONS	10. RELATED-PARTY TRANSACTIONS  The following represent our significant related-party transactions at September 30, 2016. See Note 2 for additional information regarding related-party contingencies resulting from the EFH Bankruptcy Proceedings and information regarding the Reorganized TCEH Spin-Off. As a result of the Reorganized TCEH Spin-Off, Reorganized TCEH and its subsidiaries, including Luminant and TXU Energy, ceased to be related parties as of October 3, 2016. .  · W e record ed revenue from TCEH, principally for electricity delivery fees, which totaled $265 million and $279 million for the three months ended September 30, 2016 and 2015 , respectively , and $700 million and $739 million for the nine months ended September 30, 2016 and 2015, 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 nine- month periods ended September 30, 2016 and 2015 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 September 30, At December 31,  2016 2015   Trade accounts and other receivables from affiliates $ 149 $ 120  Trade accounts and other payables to affiliates (3) (2)  Trade accounts and other receivables from affiliates – net $ 146 $ 118  · 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, tota led less than $1 m illion and $5 million for the three months ended September 30, 2016 and 2015 , respectively , an d less than $1 million and $14 million for the nine months ended September 30, 2016 and 2015, respectively. We also charge each other for shared facilities at cost. Our payments to EFH Corp. for shared facilities totaled $1 mi llion for each of the three - month periods ended September 30, 2016 and 2015 and $3 million for each of the nine-month periods ended September 30, 2016 and 2015 . Payments we received from EFH Corp. subsidiaries related to shared facilities totaled $1 million and less than $1 m illion for the three - month periods ended September 30, 2016 and 2015, respectively, an d $1 million for each of the nine-month periods ended September 30, 2016 and 2015.  · 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 2015 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. In the unlikely event such amounts are not paid under the tax sharing agreement, it is probable that this regulatory liability will continue to be included in Oncor’s rate setting processes.  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 September 30, 2016 At December 31, 2015  EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total   Federal income taxes receivable $ (84) $ (23) $ (107) $ (109) $ (27) $ (136)  Texas margin taxes payable 15 - 15 20 - 20  Net payable (receivable) $ (69) $ (23) $ (92) $ (89) $ (27) $ (116)  Cash payments made to members related to income taxes consisted of the following:   Nine Months Ended September 30, 2016 Nine Months Ended September 30, 2015  EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total   Federal income taxes $ - $ - $ - $ 39 $ 10 $ 49  Texas margin taxes 20 - 20 24 - 24  Total payments $ 20 $ - $ 20 $ 63 $ 10 $ 73  · Our PUCT-approved tariffs include requirements to assure adequate creditworthiness 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 was required to post collateral support in an amount equal to estimated transition charges over specified time periods. Accordingly, TCEH had posted security in the amount of zero and $6 million for our benefit at September 30, 2016 and December 31, 2015 , respectively.  · At September 30, 2016, Oncor held approximately $6 million of over-collected transition charges, which are being refunded to REPs. An estimated $1 million of the over-collection was refunded to TCEH prior to the Reorganized TCEH Spin-Off, and an estimated $1 million of the over-collection will be refunded to Reorganized TCEH following the Reorganized TCEH Spin-Off.  · 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, prior to the Reorganized TCEH Spin-Off, to TCEH, and after the Reorganized TCEH Spin-Off, to Reorganized TCEH. Delivery fee surcharges totaled $6 million and $5 million for the three-month periods ended September 30 , 2016 and 2015 , respectively, and $15 million and $13 million for the nine-month periods ended September 30, 2016 and 2015, respectively. 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.  · Related parties 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. Also, as of September 30, 2016, 16.6% of the equity in an existing vendor of the company was held by a member of the Sponsor Group. During 2016 and 2015, this vendor performed transmission and distribution system construction and maintenance services for us. Cash payments were made for such services to this vendor totaling $138 million dollars for the nine months ended September 30, 2016 of which approximately $131 million was capitalized and $7 million recor ded as an operation and maintenance expense. At September 30, 2016, we had outstanding trade payables to this vendor of $7 million.  See Note 8 for information regarding distributions to members and Note 9 for information regarding our participation in the EFH Corp. pension plan and transactions with EFH Corp. involving employee benefit matters.

Supplementary Financial Informa

Supplementary Financial Information	9 Months Ended
	Sep. 30, 2016
Supplementary Financial Information [Abstract]
SUPPLEMENTARY FINANCIAL INFORMATION	11. SUPPLEMENTARY FINANCIAL INFORMATION  Major Customers  Revenues from TCEH represente d 25% and 26% of our total operating revenues for the three months ended September 30, 2016 and 2015 , respectively and 24% and 25% for the nine months ended September 30, 2016 and 2015, respectively. Revenues from REP subsidiaries of a nonaffiliated entity collectively represented 19% and 18% of our total operating revenues for the three months ended September 30, 2016 and 2015 , respectively , and 17% of our total operating revenues for each of the nine-month periods ended September 30, 2016 and 2015. No other customer represented 10 % or more of our total operating revenues.  Other Income and ( Deductions )   Three Months Ended September 30, Nine Months Ended September 30,  2016 2015 2016 2015   Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting $ - $ 1 $ 1 $ 5  Professional fees (3) (7) (11) (14)  Non-recoverable pension and OPEB (Note 9) - (2) (1) (6)  Other - (1) - (2)  Total other income and (deductions) - net $ (3) $ (9) $ (11) $ (17)  Interest Expense and Related Charges   Three Months Ended September 30, Nine Months Ended September 30,  2016 2015 2016 2015   Interest expense $ 86 $ 85 $ 256 $ 251  Amortization of debt issuance costs and discounts 1 - 2 2  Allowance for funds used during construction – capitalized interest portion (2) (1) (6) (3)  Total interest expense and related charges $ 85 $ 84 $ 252 $ 250  Restricted Cash  Restricted cash at September 30, 2016 was zero as a result of the maturity and payment in full of the 2004 Series transition bonds in May 2016. Restricted cash reported on our balance sheet at December 31, 2015 related to the transition bonds.  Trade Accounts and Other Receivables  Trade accounts and other receivables reported on our balance sheet consisted of the following:   At September 30, At December 31,  2016 2015   Gross trade accounts and other receivables - net $ 600 $ 509  Trade accounts and other receivables from affiliates - net (146) (118)  Allowance for uncollectible accounts (4) (3)  Trade accounts receivable from nonaffiliates – net $ 450 $ 388  At September 30, 2016 and December 31, 2015 , REP subsidiaries of a nonaffiliated entity, collectively represented approximately 17% and 13% 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 September 30, At December 31,  2016 2015   Assets related to employee benefit plans, including employee savings programs $ 98 $ 94  Land and other investments 4 3  Total investments and other property $ 102 $ 97  Property, Plant and Equipment  Property, plant and equipment reported on our balance sheet consisted of the following:   At September 30, At December 31,  2016 2015   Total assets in service $ 19,719 $ 19,072  Less accumulated depreciation 6,758 6,479  Net of accumulated depreciation 12,961 12,593  Construction work in progress 641 416  Held for future use 15 15  Property, plant and equipment – net $ 13,617 $ 13,024  Intangible Assets  Intangible assets (other than goodwill) reported on our balance sheet consisted of the following:   At September 30, 2016 At December 31, 2015  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 $ 480 $ 94 $ 386 $ 467 $ 91 $ 376  Capitalized software 454 312 142 435 269 166  Total $ 934 $ 406 $ 528 $ 902 $ 360 $ 542  A ggregate amortization expense for intangible assets totaled $14 million and $16 milli on for the three-month periods ended September 30, 2016 and 2015, respectively, and $46 million and $48 milli on for the nine-month periods ended September 30, 2016 and 2015, respectively. The estimated aggregate amortization expense for each of the next five fiscal years is as follows:   Year Amortization Expense  2016 $ 61  2017 54  2018 48  2019 45  2020 44  At both September 30, 2016 and December 31, 2015 , goodwill totaling $ 4.1 billion was reported on our balance sheet. None of this goodwill is being deducted for tax purposes.  Employee Benefit Obligations and Other  Employee benefit obligations and other reported on our balance sheet consisted of the following:   At September 30, At December 31,  2016 2015   Retirement plans and other employee benefits $ 2,021 $ 1,985  Uncertain tax positions (including accrued interest) 3 3  Investment tax credits 13 15  Other 66 60  Total employee benefit obligations and other $ 2,103 $ 2,063  Supplemental Cash Flow Information   Nine Months Ended September 30,  2016 2015   Cash payments (receipts) related to:  Interest $ 266 $ 277  Capitalized interest (6) (3)  Interest (net of amounts capitalized) $ 260 $ 274  Amount in lieu of income taxes (a):  Federal - 49  State 20 24  Total amount in lieu of income taxes $ 20 $ 73  Noncash construction expenditures (b) $ 104 $ 60 _____________ (a) See Note 10 for income tax related detail. (b) Represents end-of-period accruals.

Business and Significant Acco19

Business and Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2016
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 Bondco, 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 that sell power in the north-central, eastern and western parts of Texas. The services to REPs included subsidiaries of TCEH through the date of the Reorganized TCEH Spin-Off and subsidiaries of Reorganized TCEH after the date of the Reorganized TCEH Spin- Off . Revenues from TCEH represented 24% and 25% of our total operating revenues for the nine months ended September 30, 2016 and 2015, 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 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. The 2003 Series transition bonds matured and were paid in full in 2015 and the 2004 Series transition bonds matured and were paid in full in May 2016. Final true-up proceedings and refunds of over-collected transition charges for the transition bonds are being conducted by Oncor and the PUCT during 2016 and are expected to have minimal or no net income impact.  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, 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, the Debtors 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  These unaudited condensed financial statements should be read in conjunction with the audited financial statements and related notes included in the 2015 Form 10-K. In the opinion of Oncor management, all adjustments (consisting of normal recurring accruals) necessary for a fair presentation of the results of operations and financial position have been made. All intercompany items and transactions have been eliminated in consolidation. 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 U . S . dollars unless otherwise indicated.
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.
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.
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. 
Changes In Accounting Standards	Changes in Accounting Standards  In February 2016, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update 2016-2 (ASU 2016-2), Leases . ASU 2016-2 amends previous GAAP to require the balance sheet recognition of lease assets and liabilities for operating leases. Oncor will be required to adopt ASU 2016-2 by January 1, 2019 and does not expect to early adopt. Retrospective application to the 2017 and 2018 comparative periods presented will be required in the year of adoption. We continue to evaluat e the impact of ASU 2016-2 on our financial statements. Since May 2014, the FASB has issued Accounting Standards Update No. 2014-09, Revenue from Contracts with Customers along with other supplemental guidance (together, Topic 606). Topic 606 introduces new, increased requirements for disclosure of revenue in financial statements and guidance that are intended to eliminate inconsistencies in the recognition of revenue. O n cor will be required to adopt Topic 606 by January 1, 2018 and does not expect to early adopt. We continue to evaluate the impact on our financial statements. At this time, the adoption is not expected to have a material effect on our reported results of operations, financial condition or cash flows.

Regulatory Assets and Liabili20

Regulatory Assets and Liabilities (Tables)	9 Months Ended
	Sep. 30, 2016
Regulatory Assets and Liabilities [Abstract]
Components Of Regulatory Assets And Liabilities	  Remaining Rate Recovery/Amortization Period at Carrying Amount At  September 30, 2016 September 30, 2016 December 31, 2015   Regulatory assets:  Generation-related regulatory assets securitized by transition bonds (a)(d) - $ - $ 31  Employee retirement costs being amortized 3 years 27 38  Unrecovered employee retirement costs incurred since the last rate review period (b) To be determined 318 291  Employee retirement liability (a)(b)(c) To be determined 812 853  Self-insurance reserve (primarily storm recovery costs) being amortized ― net 3 years 72 95  Unrecovered self-insurance reserve incurred since the last rate review period ― net (b) To be determined 374 332  Securities reacquisition costs (pre-industry restructure) 1 year or less 6 14  Securities reacquisition costs (post-industry restructure) ― net Lives of related debt 10 9  Recoverable amounts in lieu of deferred income taxes ― net Life of related asset or liability 3 12  Deferred conventional meter and metering facilities depreciation Largely 4 years 83 100  Under-recovered AMS costs To be determined 194 164  Energy efficiency performance bonus (a) 1 year or less 12 10  Under-recovered wholesale transmission service expense (a) 1 year or less 15 -  Other regulatory assets Various 8 9  Total regulatory assets 1,934 1,958   Regulatory liabilities:  Estimated net removal costs Lives of related assets 782 686  Investment tax credit and protected excess deferred taxes Various 10 14  Over-collection of transition bond charges (a)(d) 1 year or less 6 29  Over-recovered wholesale transmission service expense (a) 1 year or less - 24  Energy efficiency programs (a) Not applicable 22 11  Total regulatory liabilities 820 764  Net regulatory asset $ 1,114 $ 1,194 ____________ (a) Not earning a return in the regulatory rate-setting process. (b) Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review. (c) Represents unfunded liabilities recorded in accor dance with pension and OPEB accounting standards. (d) Bondco net regulatory liabilities at September 30, 2016 were zero ( excludes $6 million of over -collections related to transition bonds assumed by Oncor for final settlement). Bondco net regulatory assets of $10 million at December 31, 2015 consisted of $31 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $21 million (excludes $8 million of over-collections related to transition bonds assumed by Oncor for final settlement).

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2016
Long-Term Debt [Abstract]
Schedule Of Long-Term Debt	  September 30, December 31,  2016 2015   Oncor (a):  5.000% Fixed Senior Notes due September 30, 2017 $ 324 $ 324  6.800% Fixed Senior Notes due September 1, 2018 550 550  2.150% Fixed Senior Notes due June 1, 2019 250 250  5.750% Fixed Senior Notes due September 30, 2020 126 126  4.100% Fixed Senior Notes due June 1, 2022 400 400  7.000% Fixed Debentures due September 1, 2022 800 800  2.950% Fixed Senior Notes due April 1, 2025 350 350  7.000% Fixed Senior Notes due May 1, 2032 500 500  7.250% Fixed Senior Notes due January 15, 2033 350 350  7.500% Fixed Senior Notes due September 1, 2038 300 300  5.250% Fixed Senior Notes due September 30, 2040 475 475  4.550% Fixed Senior Notes due December 1, 2041 400 400  5.300% Fixed Senior Notes due June 1, 2042 500 500  3.750% Fixed Senior Notes due April 1, 2045 550 375  Unamortized discount and debt issuance costs (38) (54)  Less amount due currently (324) -  Long-term debt, less amounts due currently — Oncor 5,513 5,646   Bondco (b):  5.290% Fixed Series 2004 Bonds due May 15, 2016 - 41  Total - 41  Less amount due currently - (41)  Long-term debt, less amounts due currently — Bondco - -  Total long-term debt, less amounts due currently $ 5,513 $ 5,646 __________ (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 were nonrecourse to Oncor and were issued to securitize a regulatory asset.

Membership Interests (Tables)

Membership Interests (Tables)	9 Months Ended
	Sep. 30, 2016
Membership Interests [Abstract]
Schedule Of Distributions Paid	  Declaration Date Payment Date Amount  July 27, 2016 August 11, 2016 $ 68  April 27, 2016 May 11, 2016 $ 65  February 24, 2016 February 25, 2016 $ 56 
Schedule Of Changes To Membership Interests	  Capital Accounts Accumulated Other Comprehensive Income (Loss) Total Membership Interests   Balance at December 31, 2015 $ 7,621 $ (113) $ 7,508  Net income 355 - 355  Distributions (189) - (189)  Net effects of cash flow hedges (net of tax) - 1 1  Defined benefit pension plans (net of tax) - 1 1  Balance at September 30, 2016 $ 7,787 $ (111) $ 7,676   Balance at December 31, 2014 $ 7,625 $ (107) $ 7,518  Net income 359 - 359  Distributions (283) - (283)  Net effects of cash flow hedges (net of tax) - 1 1  Defined benefit pension plans (net of tax) - 1 1  Balance at September 30, 2015 $ 7,701 $ (105) $ 7,596 
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, 2015 $ (22) $ (91) $ (113)  Defined benefit pension plans (net of tax) - 1 1  Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges 1 - 1  Balance at September 30, 2016 $ (21) $ (90) $ (111)   Balance at December 31, 2014 $ (24) $ (83) $ (107)  Defined benefit pension plans (net of tax) - 1 1  Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges 1 - 1  Balance at September 30, 2015 $ (23) $ (82) $ (105) 

Pension and OPEB Plans (Tables)

Pension and OPEB Plans (Tables)	9 Months Ended
	Sep. 30, 2016
Pension And Other Postretirement Employee Benefits Plans [Abstract]
Schedule Of Pension And OPEB Plan Costs	  Three Months Ended September 30, Nine Months Ended September 30,  2016 2015 2016 2015   Components of net allocated pension costs:  Service cost $ 6 $ 6 $ 18 $ 18  Interest cost 33 33 101 99  Expected return on assets (30) (29) (92) (87)  Amortization of net loss 10 16 30 48  Net pension costs 19 26 57 78  Components of net OPEB costs:  Service cost 2 2 6 6  Interest cost 12 11 36 33  Expected return on assets (2) (3) (6) (9)  Amortization of prior service cost (5) (5) (15) (15)  Amortization of net loss 9 8 26 24  Net OPEB costs 16 13 47 39  Total net pension and OPEB costs 35 39 104 117  Less amounts deferred principally as property or a regulatory asset (25) (28) (75) (84)  Net amounts recognized as expense $ 10 $ 11 $ 29 $ 33 

Related-Party Transactions (Tab

Related-Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2016
Related-Party Transactions [Abstract]
Schedule Of Trade Accounts And Other Receivables From Related Parties	  At September 30, At December 31,  2016 2015   Trade accounts and other receivables from affiliates $ 149 $ 120  Trade accounts and other payables to affiliates (3) (2)  Trade accounts and other receivables from affiliates – net $ 146 $ 118 
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 September 30, 2016 At December 31, 2015  EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total   Federal income taxes receivable $ (84) $ (23) $ (107) $ (109) $ (27) $ (136)  Texas margin taxes payable 15 - 15 20 - 20  Net payable (receivable) $ (69) $ (23) $ (92) $ (89) $ (27) $ (116)  Cash payments made to members related to income taxes consisted of the following:   Nine Months Ended September 30, 2016 Nine Months Ended September 30, 2015  EFH Corp. Texas Transmission Total EFH Corp. Texas Transmission Total   Federal income taxes $ - $ - $ - $ 39 $ 10 $ 49  Texas margin taxes 20 - 20 24 - 24  Total payments $ 20 $ - $ 20 $ 63 $ 10 $ 73 

Supplementary Financial Infor25

Supplementary Financial Information (Tables)	9 Months Ended
	Sep. 30, 2016
Supplementary Financial Information [Abstract]
Schedule Of Other Income And (Deductions)	  Three Months Ended September 30, Nine Months Ended September 30,  2016 2015 2016 2015   Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting $ - $ 1 $ 1 $ 5  Professional fees (3) (7) (11) (14)  Non-recoverable pension and OPEB (Note 9) - (2) (1) (6)  Other - (1) - (2)  Total other income and (deductions) - net $ (3) $ (9) $ (11) $ (17) 
Schedule Of Interest Expense And Related Charges	  Three Months Ended September 30, Nine Months Ended September 30,  2016 2015 2016 2015   Interest expense $ 86 $ 85 $ 256 $ 251  Amortization of debt issuance costs and discounts 1 - 2 2  Allowance for funds used during construction – capitalized interest portion (2) (1) (6) (3)  Total interest expense and related charges $ 85 $ 84 $ 252 $ 250 
Schedule Of Trade Accounts And Other Receivables	  At September 30, At December 31,  2016 2015   Gross trade accounts and other receivables - net $ 600 $ 509  Trade accounts and other receivables from affiliates - net (146) (118)  Allowance for uncollectible accounts (4) (3)  Trade accounts receivable from nonaffiliates – net $ 450 $ 388 
Summary of Investments And Other Property	  At September 30, At December 31,  2016 2015   Assets related to employee benefit plans, including employee savings programs $ 98 $ 94  Land and other investments 4 3  Total investments and other property $ 102 $ 97 
Schedule Of Property, Plant And Equipment	  At September 30, At December 31,  2016 2015   Total assets in service $ 19,719 $ 19,072  Less accumulated depreciation 6,758 6,479  Net of accumulated depreciation 12,961 12,593  Construction work in progress 641 416  Held for future use 15 15  Property, plant and equipment – net $ 13,617 $ 13,024 
Schedule Of Intangible Assets	  At September 30, 2016 At December 31, 2015  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 $ 480 $ 94 $ 386 $ 467 $ 91 $ 376  Capitalized software 454 312 142 435 269 166  Total $ 934 $ 406 $ 528 $ 902 $ 360 $ 542 
Schedule Of Estimated Aggregate Amortization Expenses	  Year Amortization Expense  2016 $ 61  2017 54  2018 48  2019 45  2020 44 
Schedule Of Employee Benefit Obligations And Other	  At September 30, At December 31,  2016 2015   Retirement plans and other employee benefits $ 2,021 $ 1,985  Uncertain tax positions (including accrued interest) 3 3  Investment tax credits 13 15  Other 66 60  Total employee benefit obligations and other $ 2,103 $ 2,063 
Schedule Of Supplemental Cash Flow Information	  Nine Months Ended September 30,  2016 2015   Cash payments (receipts) related to:  Interest $ 266 $ 277  Capitalized interest (6) (3)  Interest (net of amounts capitalized) $ 260 $ 274  Amount in lieu of income taxes (a):  Federal - 49  State 20 24  Total amount in lieu of income taxes $ 20 $ 73  Noncash construction expenditures (b) $ 104 $ 60 _____________ (a) See Note 10 for income tax related detail. (b) Represents end-of-period accruals.

Business And Significant Acco26

Business And Significant Accounting Policies (Details) $ in Billions	1 Months Ended	3 Months Ended		9 Months Ended
	Nov. 30, 2008	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016entity	Sep. 30, 2015	Dec. 31, 2004USD ($)	Dec. 31, 2003USD ($)
Business And Significant Accounting Polices [Line Items]
Number of entities that would possibly be bankrupt | entity				1
Principal amount of transition bonds issued | $						$ 1.3	$ 1.3
Percentage of equity interest sold in the event of bankruptcy	19.75%
Oncor Holdings [Member]
Business And Significant Accounting Polices [Line Items]
Ownership		80.03%		80.03%
Texas Transmission [Member]
Business And Significant Accounting Polices [Line Items]
Percentage of membership interest owned by non-controlling owners		19.75%		19.75%
Sales [Member] | TCEH [Member]
Business And Significant Accounting Polices [Line Items]
Concentration Risk Percentage		25.00%	26.00%	24.00%	25.00%

EFH Bankruptcy Proceedings (Det

EFH Bankruptcy Proceedings (Details) - USD ($) $ in Millions	Oct. 30, 2016	Sep. 30, 2016	Oct. 29, 2016	Apr. 28, 2014
Bankruptcy [Line Items]
Amount receivable from related party				$ 129
Amount collected from related party		$ 128
Subsequent Event [Member]
Bankruptcy [Line Items]
Purchase price	$ 2,400
OMI Agreement [Member] | Subsequent Event [Member]
Bankruptcy [Line Items]
Limited liability company interests, shares			1,396,008
Limited liability company interests, value			$ 27
EFH Corp [Member] | NEE Merger Agreement [Member]
Bankruptcy [Line Items]
Agreement extension period		90 days
Percent of outstanding equity interests required		80.00%
Termination fee		$ 275
Texas Holdings Group [Member] | TTI Merger Agreement [Member] | Subsequent Event [Member]
Bankruptcy [Line Items]
Percent of outstanding equity interests required	19.75%

Regulatory Matters (Details)

Regulatory Matters (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)item
Number of cities resolutions passed over electric utility rates	58
Number of original jurisdiction cities	204
Number of other parties appealed various portions of rate review final order to state district court	4
Number of issues revised judgment	2
Rate at which interest accrues for over-collections	0.18%
Maximum [Member]
Estimated impact on earnings | $	$ 135
Minimum [Member]
Estimated impact on earnings | $	$ 0

Regulatory Assets And Liabili29

Regulatory Assets And Liabilities (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2016	Dec. 31, 2015
Regulatory Assets And Liabilities [Line Items]
Carrying Amount, Regulatory Assets		$ 1,934	$ 1,958
Carrying Amount, Regulatory Liabilities		820	764
Net regulatory asset		1,114	1,194
Bondco [Member]
Regulatory Assets And Liabilities [Line Items]
Carrying Amount, Regulatory Liabilities		$ 0
Net regulatory asset			10
Estimated Net Removal Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		Lives of related assets
Carrying Amount, Regulatory Liabilities		$ 782	686
Investment Tax Credit and Protected Excess Deferred Taxes [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		Various
Carrying Amount, Regulatory Liabilities		$ 10	14
Over-Collection Of Transition Bond Charges [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[1],[2]	1 year or less
Carrying Amount, Regulatory Liabilities	[1],[2]	$ 6	29
Over-Collection Of Transition Bond Charges [Member] | Bondco [Member]
Regulatory Assets And Liabilities [Line Items]
Carrying Amount, Regulatory Liabilities		$ 6	21
Over-Recovered Wholesale Transmission Service Expense - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[2]	1 year or less
Carrying Amount, Regulatory Liabilities	[2]		24
Energy Efficiency Programs [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[2]	Not applicable
Carrying Amount, Regulatory Liabilities	[2]	$ 22	11
Excluded Over-Collected Series 2003-1 Transition Bond Revenues [Member] | Bondco [Member]
Regulatory Assets And Liabilities [Line Items]
Net regulatory asset			8
Generation Related Regulatory Assets Securitized by Transition Bonds [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[1],[2]	-
Carrying Amount, Regulatory Assets	[1],[2]		31
Generation Related Regulatory Assets Securitized by Transition Bonds [Member] | Bondco [Member]
Regulatory Assets And Liabilities [Line Items]
Carrying Amount, Regulatory Assets			31
Employee Retirement Costs Being Amortized [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		3 years
Carrying Amount, Regulatory Assets		$ 27	38
Unrecovered Employee Retirement Costs Incurred Since The Last Rate Review Period [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[3]	To be determined
Carrying Amount, Regulatory Assets	[3]	$ 318	291
Employee Retirement Liability [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[2],[3],[4]	To be determined
Carrying Amount, Regulatory Assets	[2],[3],[4]	$ 812	853
Self Insurance Reserve (Primarily Storm Recovery Costs) Being Amortized - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		3 years
Carrying Amount, Regulatory Assets		$ 72	95
Unrecovered Self-Insurance Reserve Incurred Since The Last Rate Review Period - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[3]	To be determined
Carrying Amount, Regulatory Assets	[3]	$ 374	332
Securities Reacquisition Costs (Pre-Industry Restructure) [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		1 year or less
Carrying Amount, Regulatory Assets		$ 6	14
Securities Reacquisition Costs (Post-Industry Restructure) - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		Lives of related debt
Carrying Amount, Regulatory Assets		$ 10	9
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
Carrying Amount, Regulatory Assets		$ 3	12
Deferred Conventional Meter And Metering Facilities Depreciation [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		Largely 4 years
Carrying Amount, Regulatory Assets		$ 83	100
Under-recovered AMS Costs [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		To be determined
Carrying Amount, Regulatory Assets		$ 194	164
Energy Efficiency Performance Bonus [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[2]	1 year or less
Carrying Amount, Regulatory Assets	[2]	$ 12	10
Under-Recovered Wholesale Transmission Service Expense - Net [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period	[2]	1 year or less
Carrying Amount, Regulatory Assets	[2]	$ 15
Other Regulatory Assets [Member]
Regulatory Assets And Liabilities [Line Items]
Remaining Rate Recovery/Amortization Period		Various
Carrying Amount, Regulatory Assets		$ 8	$ 9
[1]	Bondco net regulatory liabilities at September 30, 2016 were zero (excludes $6 million of over-collections related to transition bonds assumed by Oncor for final settlement). Bondco net regulatory assets of $10 million at December 31, 2015 consisted of $31 million included in generation-related regulatory assets net of the regulatory liability for over-collection of transition bond revenues of $21 million (excludes $8 million of over-collections related to transition bonds assumed by Oncor for final settlement).
[2]	Not earning a return in the regulatory rate-setting process.
[3]	Recovery is specifically authorized by statute or by the PUCT, subject to reasonableness review.
[4]	Represents unfunded liabilities recorded in accordance with pension and OPEB accounting standards.

Borrowings Under Credit Facil30

Borrowings Under Credit Facilities (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)item	Dec. 31, 2015USD ($)
Line of Credit Facility [Line Items]
Outstanding borrowing under the revolving credit facility	$ 880,000	$ 840
Outstanding borrowing, interest rate	1.52%	1.48%
Letters of credit	$ 7	$ 7
Commitment fee	0.10%
Borrowing capacity available under the credit facility	$ 1,113	$ 1,153
Maximum [Member]
Line of Credit Facility [Line Items]
Commitment rate reduction under the revolving credit facility	0.275%
Debt-to-capitalization ratio	1
Minimum [Member]
Line of Credit Facility [Line Items]
Commitment rate reduction under the revolving credit facility	0.10%
Debt-to-capitalization ratio	0.65
Letter of Credit [Member]
Line of Credit Facility [Line Items]
Outstanding borrowing, interest rate	1.20%
Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 2,000
Number of revolving credit facilities extension options | item	2
Extension period for revolving line of credit	1 year
Expiration of revolving credit facility	Oct. 31, 2018
Additional increase in borrowing capacity amount	$ 100
London Interbank Offered Rate (LIBOR) [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.00%
London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.75%
London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.00%
Federal Funds Effective Rate [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	0.50%
One-Month London Interbank Offered Rate [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	1.00%
One-Month London Interbank Offered Rate [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	0.75%
One-Month London Interbank Offered Rate [Member] | Minimum [Member]
Line of Credit Facility [Line Items]
Spread over variable rate	0.00%

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details) - USD ($)	9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015	Aug. 31, 2016	Mar. 31, 2015
Long-Term Debt [Line Items]
Repayments of long-term debt	$ 41,000,000	$ 594,000,000
Percentage of fair value of cost of property additions certified to the Deed of Trust collateral agent	85.00%
Available bond credits	$ 2,534,000,000
Future debt subject to property additions to the Deed of Trust	1,586,000,000
Estimated fair value of our long-term debt including current maturities	7,112,000,000		$ 6,287,000,000
Carrying amount	$ 5,837,000,000		$ 5,687,000,000
3.750% Fixed Senior Notes due April 1, 2045 [Member]
Long-Term Debt [Line Items]
Interest percentage	3.75%		3.75%
Due date	Apr. 1, 2045		Apr. 1, 2045
Additional 2045 Notes [Member]
Long-Term Debt [Line Items]
Debt issuance of long-term debt				$ 175,000,000	$ 375,000,000
Due date	Oct. 1, 2044
Proceeds from sale of Notes	$ 185,000,000
Date of first payment	Oct. 1, 2016
Percentage of principal amount plus accrued and unpaid interest and make-whole premium	100.00%
Increase in annual interest rate	0.50%
Transition Bond [Member]
Long-Term Debt [Line Items]
Repayments of long-term debt	$ 41,000,000

Long-Term Debt (Schedule Of Lon

Long-Term Debt (Schedule Of Long-Term Debt) (Details) - USD ($) $ in Millions		9 Months Ended	12 Months Ended
		Sep. 30, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Unamortized discount and debt issuance costs	[1]	$ (38)	$ (54)
Less amount due currently	[1]	(324)
Total long-term debt, less amounts due currently	[1]	5,513	5,646
5.000% Fixed Senior Notes Due September 30, 2017 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 324	$ 324
Interest percentage		5.00%	5.00%
Due date		Sep. 30, 2017	Sep. 30, 2017
6.800% Fixed Senior Notes Due September 1, 2018 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 550	$ 550
Interest percentage		6.80%	6.80%
Due date		Sep. 1, 2018	Sep. 1, 2018
2.150% Fixed Senior Notes Due June 1, 2019 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 250	$ 250
Interest percentage		2.15%	2.15%
Due date		Jun. 1, 2019	Jun. 1, 2019
5.750% Fixed Senior Notes Due September 30, 2020 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 126	$ 126
Interest percentage		5.75%	5.75%
Due date		Sep. 30, 2020	Sep. 30, 2020
4.100% Fixed Senior Notes Due June 1, 2022 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 400	$ 400
Interest percentage		4.10%	4.10%
Due date		Jun. 1, 2022	Jun. 1, 2022
7.000% Fixed Debentures Due September 1, 2022 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 800	$ 800
Interest percentage		7.00%	7.00%
Due date		Sep. 1, 2022	Sep. 1, 2022
2.950% Fixed Senior Notes due April 1, 2025 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 350	$ 350
Interest percentage		2.95%	2.95%
Due date		Apr. 1, 2025	Apr. 1, 2025
7.000% Fixed Senior Notes Due May 1, 2032 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 500	$ 500
Interest percentage		7.00%	7.00%
Due date		May 1, 2032	May 1, 2032
7.250% Fixed Senior Notes Due January 15, 2033 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 350	$ 350
Interest percentage		7.25%	7.25%
Due date		Jan. 15, 2033	Jan. 15, 2033
7.500% Fixed Senior Notes Due September 1, 2038 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 300	$ 300
Interest percentage		7.50%	7.50%
Due date		Sep. 1, 2038	Sep. 1, 2038
5.250% Fixed Senior Notes Due September 30, 2040 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 475	$ 475
Interest percentage		5.25%	5.25%
Due date		Sep. 30, 2040	Sep. 30, 2040
4.550% Fixed Senior Notes Due December 1, 2041 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 400	$ 400
Interest percentage		4.55%	4.55%
Due date		Dec. 1, 2041	Dec. 1, 2041
5.300% Fixed Senior Notes Due June 1, 2042 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 500	$ 500
Interest percentage		5.30%	5.30%
Due date		Jun. 1, 2042	Jun. 1, 2042
3.750% Fixed Senior Notes due April 1, 2045 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[1]	$ 550	$ 375
Interest percentage		3.75%	3.75%
Due date		Apr. 1, 2045	Apr. 1, 2045
Bondco [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[2]		$ 41
Less amount due currently	[2]		(41)
Bondco [Member] | 5.290% Fixed Series 2004 Bonds Due May 15, 2016 [Member]
Debt Instrument [Line Items]
Fixed Senior Note	[2]		$ 41
Interest percentage		5.29%	5.29%
Due date		May 15, 2016	May 15, 2016
[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 were nonrecourse to Oncor and were issued to securitize a regulatory asset.

Membership Interests (Narrative

Membership Interests (Narrative) (Details) - USD ($) $ in Millions	Jul. 27, 2016	Sep. 30, 2016	Sep. 30, 2015
Subsequent Event [Line Items]
Cash distribution to members		$ 189	$ 283
Assumed debt to equity ratio, debt		60.00%
Assumed debt to equity ratio, equity		40.00%
Regulatory capitalization ratio, debt		59.60%
Regulatory capitalization ratio, equity		40.40%
Cash available for distribution under the capital structure restriction		$ 69
Subsequent Event [Member]
Subsequent Event [Line Items]
Cash distribution to members	$ 41

Membership Interests (Schedule

Membership Interests (Schedule Of Distributions Paid) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Dividends Payable [Line Items]
Amount	$ 189	$ 283
Payment One FY 2016 [Member]
Dividends Payable [Line Items]
Declaration Date	Jul. 27, 2016
Payment Date	Aug. 11, 2016
Amount	$ 68
Payment Two FY 2016 [Member]
Dividends Payable [Line Items]
Declaration Date	Apr. 27, 2016
Payment Date	May 11, 2016
Amount	$ 65
Payment Three FY 2016 [Member]
Dividends Payable [Line Items]
Declaration Date	Feb. 24, 2016
Payment Date	Feb. 25, 2016
Amount	$ 56

Membership Interests (Schedul35

Membership Interests (Schedule Of Changes To Membership Interests) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Balance			$ 7,508	$ 7,518
Net income	$ 163	$ 163	355	359
Distributions			(189)	(283)
Net effects of cash flow hedges (net of tax)	1	1	1	1
Defined benefit pension plans (net of tax)			1	1
Balance	7,676	7,596	7,676	7,596
Capital Accounts [Member]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Balance			7,621	7,625
Net income			355	359
Distributions			(189)	(283)
Net effects of cash flow hedges (net of tax)
Defined benefit pension plans (net of tax)
Balance	7,787	7,701	7,787	7,701
Accumulated Other Comprehensive Income (Loss) [Member]
Consolidation, Less than Wholly Owned Subsidiary, Parent Ownership Interest, Effects of Changes, Net [Line Items]
Balance			(113)	(107)
Net income
Distributions
Net effects of cash flow hedges (net of tax)			1	1
Defined benefit pension plans (net of tax)			1	1
Balance	$ (111)	$ (105)	$ (111)	$ (105)

Membership Interests (Schedul36

Membership Interests (Schedule Of Changes To Accumulated Other Comprehensive Income (Loss)) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (113)
Balance at end of period	(111)
Cash Flow Hedges - Interest Rate Swap [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(22)	$ (24)
Defined benefit pension plans (net of tax)
Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges	1	1
Balance at end of period	(21)	(23)
Defined Benefit Pension and OPEB Plans [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(91)	(83)
Defined benefit pension plans (net of tax)	1	1
Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges
Balance at end of period	(90)	(82)
Accumulated Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(113)	(107)
Defined benefit pension plans (net of tax)	1	1
Amounts reclassified from accumulated other comprehensive income (loss) and reported in interest expense and related charges	1	1
Balance at end of period	$ (111)	$ (105)

Pension And OPEB Plans (Narrati

Pension And OPEB Plans (Narrative) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)
Oncor Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.28%
Expected return on plan assets	5.53%
EFH Retirement Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.57%
Expected return on plan assets	5.64%
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Cash contributions	$ 3
Additional cash contributions	1
Additional cash contributions, next five years	$ 479
OPEB Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.60%
Expected return on plan assets	6.30%
Cash contributions	$ 22
Additional cash contributions	16
Additional cash contributions, next five years	$ 160

Pension And OPEB Plans (Schedul

Pension And OPEB Plans (Schedule Of Pension And OPEB Plan Costs) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Defined Benefit Plan Disclosure [Line Items]
Net costs	$ 35	$ 39	$ 104	$ 117
Less amounts deferred principally as property or a regulatory asset	(25)	(28)	(75)	(84)
Net amounts recognized as expense	10	11	29	33
Pension Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	6	6	18	18
Interest cost	33	33	101	99
Expected return on assets	(30)	(29)	(92)	(87)
Amortization of net loss	10	16	30	48
Net costs	19	26	57	78
OPEB [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	2	2	6	6
Interest cost	12	11	36	33
Expected return on assets	(2)	(3)	(6)	(9)
Amortization of prior service cost	(5)	(5)	(15)	(15)
Amortization of net loss	9	8	26	24
Net costs	$ 16	$ 13	$ 47	$ 39

Related-Party Transactions (Nar

Related-Party Transactions (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Related Party Transaction [Line Items]
Revenues from electricity delivery fees	$ 265	$ 279	$ 700	$ 739
TCEH [Member]
Related Party Transaction [Line Items]
Revenues from electricity delivery fees	265	279	700	739
Posted security amount	0		0		$ 6
Over-collection of transition charges to be refunded	1		1
Delivery fee surcharges	6	5	15	13
EFH Corp [Member]
Related Party Transaction [Line Items]
Administrative and services costs		5		14
Shared facilities expense	1	1	3	3
Shared facilities payments received	1		1	1
Over-collection of transition charges to be refunded	3		3		$ 2
REPs [Member]
Related Party Transaction [Line Items]
Over-collection of transition charges to be refunded	6		6
Reorganized TCEH [Member]
Related Party Transaction [Line Items]
Over-collection of transition charges to be refunded	$ 1		$ 1
Sponsor Group [Member]
Related Party Transaction [Line Items]
Equity in existing vendor	16.60%		16.60%
Cash payments to vendors			$ 138
Trade payables related parties	$ 7		7
Sponsor Group [Member] | Capitalized [Member]
Related Party Transaction [Line Items]
Cash payments to vendors			131
Sponsor Group [Member] | Operation And Maintenance Expense [Member]
Related Party Transaction [Line Items]
Cash payments to vendors			7
Maximum [Member] | TCEH [Member]
Related Party Transaction [Line Items]
Transformer maintenance revenue	1	1	1	$ 1
Maximum [Member] | EFH Corp [Member]
Related Party Transaction [Line Items]
Administrative and services costs	$ 1		$ 1
Shared facilities payments received		$ 1

Related-Party Transactions (Sch

Related-Party Transactions (Schedule Of Trade Accounts And Other Receivables From Related Parties) (Details) - EFH Corp [Member] - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Trade accounts and other receivables from affiliates	$ 149	$ 120
Trade accounts and other payables to affiliates	(3)	(2)
Trade accounts and other receivables from affiliates - net	$ 146	$ 118

Related-Party Transactions (S41

Related-Party Transactions (Schedule Of Amounts Payable To (Receivable From) Members In Lieu Of Income Taxes) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Related Party Transaction [Line Items]
Federal income taxes receivable	$ (107)	$ (136)
Texas margin taxes payable	15	20
Net payable (receivable)	(92)	(116)
EFH Corp [Member]
Related Party Transaction [Line Items]
Federal income taxes receivable	(84)	(109)
Texas margin taxes payable	15	20
Net payable (receivable)	(69)	(89)
Texas Transmission [Member]
Related Party Transaction [Line Items]
Federal income taxes receivable	(23)	(27)
Net payable (receivable)	$ (23)	$ (27)

Related-Party Transactions (Cas

Related-Party Transactions (Cash Payments Made To (Received From) Members In Lieu Of Income Taxes) (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Related Party Transaction [Line Items]
Federal income taxes		$ 49
Texas margin taxes	$ 20	24
Total payments	20	73
EFH Corp [Member]
Related Party Transaction [Line Items]
Federal income taxes		39
Texas margin taxes	20	24
Total payments	$ 20	63
Texas Transmission [Member]
Related Party Transaction [Line Items]
Federal income taxes		10
Total payments		$ 10

Supplementary Financial Infor43

Supplementary Financial Information (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Supplemental Financial Information [Line Items]
Restricted cash	$ 0		$ 0		$ 38
Aggregate amortization expenses	14	$ 16	46	$ 48
Goodwill	$ 4,064		$ 4,064		$ 4,064
Sales [Member] | TCEH [Member]
Supplemental Financial Information [Line Items]
Concentration Risk Percentage	25.00%	26.00%	24.00%	25.00%
Sales [Member] | Nonaffiliated REP [Member]
Supplemental Financial Information [Line Items]
Concentration Risk Percentage	19.00%	18.00%	17.00%	17.00%
Nonaffiliated Trade Accounts Receivable [Member] | Nonaffiliated REP [Member]
Supplemental Financial Information [Line Items]
Concentration Risk Percentage			17.00%		13.00%

Supplementary Financial Infor44

Supplementary Financial Information (Schedule Of Other Income And (Deductions)) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Supplementary Financial Information [Abstract]
Accretion of fair value adjustment (discount) to regulatory assets due to purchase accounting		$ 1	$ 1	$ 5
Professional fees	(3)	(7)	(11)	(14)
Non-recoverable pension and OPEB (Note 9)		(2)	(1)	(6)
Other		(1)		(2)
Total other income and (deductions) - net	$ (3)	$ (9)	$ (11)	$ (17)

Supplementary Financial Infor45

Supplementary Financial Information (Schedule Of Interest Expense And Related Charges) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Supplementary Financial Information [Abstract]
Interest expense	$ 86	$ 85	$ 256	$ 251
Amortization of debt issuance costs and discounts	1		2	2
Allowance for funds used during construction — capitalized interest portion	(2)	(1)	(6)	(3)
Total interest expense and related charges	$ 85	$ 84	$ 252	$ 250

Supplementary Financial Infor46

Supplementary Financial Information (Schedule Of Trade Accounts And Other Receivables) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Gross trade accounts and other receivables - net	$ 600	$ 509
Trade accounts and other receivables from affiliates - net	(146)	(118)
Allowance for uncollectible accounts	(4)	(3)
Trade accounts receivable from nonaffiliates - net	$ 450	$ 388

Supplementary Financial Infor47

Supplementary Financial Information (Summary of Investments And Other Property) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Assets related to employee benefit plans, including employee savings programs	$ 98	$ 94
Land and other investments	4	3
Total investments and other property	$ 102	$ 97

Supplementary Financial Infor48

Supplementary Financial Information (Schedule Of Property, Plant And Equipment) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Total assets in service	$ 19,719	$ 19,072
Less accumulated depreciation	6,758	6,479
Net of accumulated depreciation	12,961	12,593
Construction work in progress	641	416
Held for future use	15	15
Property, plant and equipment - net	$ 13,617	$ 13,024

Supplementary Financial Infor49

Supplementary Financial Information (Schedule Of Intangible Assets) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 934	$ 902
Accumulated Amortization	406	360
Net	528	542
Land Easements [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	480	467
Accumulated Amortization	94	91
Net	386	376
Capitalized Software [Member]
Finite-Lived Intangible Assets [Line Items]
Gross Carrying Amount	454	435
Accumulated Amortization	312	269
Net	$ 142	$ 166

Supplementary Financial Infor50

Supplementary Financial Information (Schedule Of Estimated Aggregate Amortization Expenses) (Details) $ in Millions	Sep. 30, 2016USD ($)
Supplementary Financial Information [Abstract]
2,016	$ 61
2,017	54
2,018	48
2,019	45
2,020	$ 44

Supplementary Financial Infor51

Supplementary Financial Information (Schedule Of Employee Benefit Obligations And Other) (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Supplementary Financial Information [Abstract]
Retirement plans and other employee benefits	$ 2,021	$ 1,985
Uncertain tax positions (including accrued interest)	3	3
Investment tax credits	13	15
Other	66	60
Total employee benefit obligations and other	$ 2,103	$ 2,063

Supplementary Financial Infor52

Supplementary Financial Information (Schedule Of Supplemental Cash Flow Information) (Details) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015
Supplementary Financial Information [Abstract]
Interest		$ 266	$ 277
Capitalized interest		(6)	(3)
Interest (net of amounts capitalized)		260	274
Federal			49
State	[1]	20	24
Total amount in lieu of income taxes	[1]	20	73
Noncash construction expenditures	[2]	$ 104	$ 60
[1]	See Note 10 for income tax related detail.
[2]	Represents end-of-period accruals.