Oncor Electric Delivery 424B3 Prospectus supplement

Filed Pursuant to Rule 424(b)(3)

Registration No. 333-239566

PROSPECTUS

ONCOR ELECTRIC DELIVERY COMPANY LLC

Offers to Exchange

$400,000,000 aggregate principal amount of its 2.75% Senior Secured Notes due 2030 and $400,000,000 aggregate principal amount of its 3.70% Senior Secured Notes due 2050, (collectively, the exchange notes), each of which have been registered under the Securities Act of 1933, as amended (the Securities Act), for any and all of its outstanding 2.75% Senior Secured Notes due 2030 and 3.70% Senior Secured Notes due 2050, respectively (collectively, the outstanding notes and such transactions, the exchange offers)

We are conducting the exchange offers in order to provide you with an opportunity to exchange your unregistered outstanding notes for the exchange notes that have been registered under the Securities Act.

The Exchange Offers

• We will exchange all unregistered outstanding notes that are validly tendered and not validly withdrawn for an equal principal amount of exchange notes that are registered under the Securities Act.

• You may withdraw tenders of outstanding notes at any time prior to the expiration of the exchange offers.

• The exchange offers expire at 5:00 p.m., New York City time, on August 11, 2020, unless extended. We do not currently intend to extend the expiration date.

• The exchange of outstanding notes for exchange notes in the exchange offers will not be a taxable event for U.S. federal income tax purposes.

• The terms of the exchange notes to be issued in the exchange offers are substantially identical to the outstanding notes of the respective series, except that the exchange notes will be registered under the Securities Act, do not have any transfer restrictions and do not have registration rights or additional interest provisions.

Results of the Exchange Offers

• Except as prohibited by applicable law, the exchange notes may be sold in the over-the-counter market, in negotiated transactions or through a combination of such methods. There is no existing market for the exchange notes to be issued, and we do not plan to list the exchange notes on a national securities exchange or market.

• We will not receive any proceeds from the exchange offers.

All untendered outstanding notes will remain outstanding and continue to be subject to the restrictions on transfer set forth in the outstanding notes and in the indenture governing the outstanding notes. In general, the outstanding notes may not be offered or sold, unless registered under the Securities Act, except pursuant to an exemption from, or in a transaction not subject to, the Securities Act and applicable state securities laws. Other than in connection with the exchange offers, we do not currently anticipate that we will register the outstanding notes under the Securities Act.

Each broker-dealer that receives exchange notes for its own account in the exchange offers must acknowledge that it will deliver a prospectus in connection with any resale of those exchange notes. The letter of transmittal states that by so acknowledging and delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act.

This prospectus, as it may be amended or supplemented from time to time, may be used by a broker-dealer in connection with resales of exchange notes received in exchange for outstanding notes where the broker-dealer acquired such outstanding notes as a result of market-making or other trading activities.

We have agreed to keep effective the registration statement of which this prospectus is a part until the earlier of 90 days after the completion of the exchange offers or such time as broker-dealers no longer own any notes. See “Plan of Distribution.”

See “Risk Factors” beginning on page 12 for a discussion of certain risks that you should consider before participating in the exchange offers.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of the exchange notes to be distributed in the exchange offers or passed upon the adequacy or accuracy of this prospectus. Any representation to the contrary is a criminal offense.

The date of this prospectus is July 14, 2020.

You should rely only on the information included in this prospectus. We have not authorized anyone to provide you with additional or different information. The prospectus may be used only for the purposes for which it has been published, and no person has been authorized to give any information not contained herein. If you receive any other information, you should not rely on it. You should assume that the information contained in this prospectus is accurate only as of the date on the front cover of this prospectus. Our business profile, financial condition, results of operations or prospects may have changed since that date. The representations and warranties contained in any agreement that we have filed as an exhibit to the registration statement of which this prospectus is a part or that we may publicly file in the future may contain representations and warranties made by and to the parties thereto as of specific dates. While we are responsible for considering whether additional specific disclosures of material information regarding material contractual provisions are required to make the statements in the registration statement of which this prospectus is a part not misleading, those representations and warranties may be subject to exceptions and qualifications contained in separate disclosure schedules; may represent the parties’ risk allocation in the particular transaction; or may be qualified by materiality standards that differ from what may be viewed as material for securities law purposes. No offer of these securities is being made in any jurisdiction where such offer is prohibited.

TABLE OF CONTENTS

PROSPECTUS SUMMARY		2
RISK FACTORS		12
FORWARD-LOOKING STATEMENTS	��	23
INDUSTRY AND MARKET INFORMATION		25
USE OF PROCEEDS		25
CONSOLIDATED CAPITALIZATION AND SHORT-TERM DEBT OF ONCOR AND SUBSIDIARIES		26
SELECTED FINANCIAL DATA		27
OUR BUSINESS AND PROPERTIES		29
LEGAL PROCEEDINGS		36
MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		37
CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE		56
QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK		56
DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE		58
EXECUTIVE COMPENSATION		68
DIRECTOR COMPENSATION		109
SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED EQUITY HOLDER MATTERS		112
THE EXCHANGE OFFERS		120
DESCRIPTION OF THE NOTES		129
SUMMARY OF MATERIAL UNITED STATES FEDERAL INCOME TAX CONSEQUENCES		143
SUMMARY OF MATERIAL ERISA CONSIDERATIONS		143
PLAN OF DISTRIBUTION		144
LEGAL MATTERS		145
EXPERTS		145
AVAILABLE INFORMATION		145
SEC POSITION ON INDEMNIFICATION FOR SECURITIES ACT LIABILITIES		145
GLOSSARY		146
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS		F-1

PROSPECTUS SUMMARY

This summary highlights selected information appearing elsewhere in this prospectus. This summary is not complete and does not contain all of the information that you should consider before participating in the exchange offers. You should carefully read the entire prospectus, including the section entitled “Risk Factors.” See the section entitled “Available Information”. Unless the context otherwise requires or as otherwise indicated, references in this prospectus to “Oncor,” “we,” “our” and “us” refer to Oncor Electric Delivery Company LLC, and/or its subsidiaries, which include Oncor Electric Delivery Transition Bond Company LLC through the date of its dissolution on December 29, 2016, and Oncor Electric Delivery NTU LLC, a regulated utility that Oncor indirectly acquired on May 16, 2019 in the InfraREIT Acquisition. References to “Sempra” refer to our indirect majority owner, Sempra Energy, and/or its subsidiaries, depending on context. On May 16, 2019, we completed the acquisition of InfraREIT and its subsidiary, InfraREIT Partners, which is sometimes referred to in this prospectus as the InfraREIT Acquisition. For your convenience, we have also provided a Glossary, beginning on page 146, of selected terms and abbreviations.

Our Business

We are a regulated electricity transmission and distribution company that provides the essential service of delivering electricity safely, reliably and economically to end-use consumers through our electrical systems, as well as providing transmission grid connections to merchant generation facilities and interconnections to other transmission grids in Texas. We are a direct, majority-owned subsidiary of Oncor Holdings, which is indirectly and wholly owned by Sempra. Oncor Holdings owns 80.25% of our outstanding membership interests and Texas Transmission owns 19.75% of our outstanding membership interests. We are a limited liability company organized under the laws of the State of Delaware, formed in 2007 as the successor entity to Oncor Electric Delivery Company, a corporation formed under the laws of the State of Texas in 2001.

We operate the largest transmission and distribution system in Texas, delivering electricity to more than 3.6 million homes and businesses and operating more than 139,000 miles of transmission and distribution lines at December 31, 2019. We provide:

• transmission services to our electricity distribution business as well as electricity distribution companies, cooperatives and municipalities, and

• distribution services to REPs that sell electricity to retail customers.

Our transmission and distribution rates are regulated by the PUCT and certain cities, and in certain instances, by the FERC. We are not a seller of electricity, nor do we purchase electricity for resale. The company is managed as an integrated business; consequently, there is only one reportable segment.

Our transmission and distribution assets are located principally in the north-central, eastern, western and panhandle regions of Texas. This territory has an estimated population in excess of ten million and comprises over 120 counties and more than 400 incorporated municipalities, including Dallas/Fort Worth and surrounding suburbs, as well as Waco, Wichita Falls, Odessa, Midland, Tyler and Killeen.

Most of our power lines have been constructed over lands of others pursuant to easements or along public highways, streets and rights-of-way as permitted by law. At March 31, 2020, we had approximately 4,185 full-time employees, including approximately 755 employees under collective bargaining agreements.

Our transmission and distribution rates are regulated by the PUCT, certain cities and, in certain instances, FERC, and are subject to cost-of-service regulation and annual earnings oversight.

Ring-Fencing Measures

Various ring-fencing measures have been taken to enhance our credit quality and the separateness between the Oncor Ring-Fenced Entities, Sempra and its affiliates (other than the Oncor Ring-Fenced Entities), and any other entities with a direct or indirect ownership interest in Oncor or Oncor Holdings. These measures serve to mitigate the Oncor Ring-Fenced Entities’ credit exposure to Sempra and its affiliates and any other direct or indirect owners of Oncor and Oncor Holdings, and to reduce the risk that the assets and liabilities of Oncor Ring-Fenced Entities would be substantively consolidated with the assets and liabilities of any Sempra entity or any other direct or indirect owners of Oncor and Oncor Holdings in connection with a bankruptcy of any such entities. Such measures include, among other things: the 19.75% equity interest held by Texas Transmission; maintenance of separate books and records for the Oncor Ring-Fenced Entities; and our board of directors being comprised of a majority of directors who meet certain disinterested director standards. As a result, none of

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the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or obligations of any Sempra entity or any other direct or indirect owner of Oncor or Oncor Holdings. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of any Sempra entities and any other direct or indirect owner of Oncor or Oncor Holdings. We do not bear any liability for debt or contractual obligations of Sempra and its affiliates or any other direct or indirect owner of Oncor or Oncor Holdings, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from Sempra and its affiliates and any other direct or indirect owner of Oncor or Oncor Holdings. For more information on the ring-fencing measures, see “Our Business and Properties – Ring-Fencing Measures.”

Electricity Transmission

Our electricity transmission business is responsible for the safe and reliable operations of our transmission network and substations. These responsibilities consist of the construction and maintenance of transmission facilities and substations and the monitoring, controlling and dispatching of high-voltage electricity over our transmission facilities in coordination with ERCOT, the independent system operator and the regional coordinator of the various electricity systems within Texas.

We are a member of ERCOT, and our transmission business actively assists the operations of ERCOT and market participants. Through our transmission business, we participate with ERCOT and other member utilities to plan, design, construct and operate new transmission lines, with regulatory approval, necessary to maintain reliability, interconnect to merchant generation facilities, increase bulk power transfer capability and minimize limitations and constraints on the ERCOT transmission grid.

Transmission revenues are provided under tariffs approved by either the PUCT or, to a small degree related to limited interconnections to other markets, the FERC. Network transmission revenues compensate us for delivery of electricity over transmission facilities operating at 60kV and above. Other services we offer through our transmission business include system impact studies, facilities studies, transformation service and maintenance of transformer equipment, substations and transmission lines owned by other parties. PURA allows us to update our transmission rates periodically to reflect changes in invested capital. This “capital tracker” provision encourages investment in the transmission system to help ensure reliability and efficiency by allowing for timely recovery of and return on new transmission investments.

At December 31, 2019, our transmission system included 7,163 circuit miles of 345kV transmission lines and 10,636 circuit miles of 138kV and 69kV transmission lines. One hundred generation facilities totaling 40,687 MW were directly connected to our transmission system at December 31, 2019, and 349 transmission stations and 775 distribution substations were served from our transmission system.

Electricity Distribution

Our electricity distribution business is responsible for the overall safe and efficient operation of distribution facilities, including electricity delivery, power quality and system reliability. These responsibilities consist of the ownership, management, construction, maintenance and operation of the distribution system within our certificated service area. Our distribution system receives electricity from the transmission system through substations and distributes electricity to end-users and wholesale customers through 3,594 distribution feeders at December 31, 2019.

Our distribution system included 121,747 miles of distribution lines and 3.685 million points of delivery at December 31, 2019. We added approximately 64,000 points of delivery in 2019. From 2014 to 2019, the number of distribution system points of delivery we serve, excluding lighting sites, grew an average of 2.09% per year.

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We provide distribution services to approximately 90 REPs and certain electric cooperatives in our certificated service area. The consumers of the electricity we deliver are free to choose their electricity supplier from REPs who compete for their business. Requests to recover distribution-related investments are generally included in our rate reviews. However, provisions in existing legislation also allow us to file DCRF applications, under certain circumstances, once per year in order to recover distribution-related investments on an interim basis. On April 3, 2020, we filed with the PUCT in Docket No. 50734, as well as with cities with original jurisdiction over our rates, an application for approval of an updated DCRF. On June 24, 2020, we filed an unopposed stipulation and settlement agreement that included a $70 million increase in annual distribution revenues and, on June 29, 2020, interim rates based on the settlement agreement were authorized to begin effective September 1, 2020. The settlement agreement and rates are subject to final PUCT approval.

InfraREIT Acquisition

InfraREIT Mergers

On May 16, 2019, we completed the InfraREIT Acquisition. Total purchase price (including cash consideration and transaction costs incurred by InfraREIT and paid by Oncor) paid by us in connection with the acquisition totaled approximately $1,324 million (including approximately $1,275 million representing the cash consideration, a $40 million management termination fee InfraREIT agreed to pay Hunt Consolidated, Inc. at closing and certain other transaction costs incurred by InfraREIT and its subsidiaries and paid by us on their behalf), and we funded such amounts with $1,330 million in capital contributions received from Sempra and certain indirect equityholders of Texas Transmission and proceeds received through the issuance of commercial paper.

In connection with the InfraREIT Acquisition, we also extinguished all of InfraREIT’s outstanding debt (which was owed by certain of InfraREIT’s subsidiaries) totaling an aggregate principal amount of approximately $953 million as of May 16, 2019. We repaid $602 million principal amount of InfraREIT’s outstanding debt using proceeds from borrowings under a short-term unsecured term loan credit agreement that was subsequently repaid, and the issuance of commercial paper. We also exchanged $351 million of InfraREIT’s outstanding debt for senior secured notes issued by us. As a result of these repayments and exchanges, all debt owed by InfraREIT’s subsidiaries was extinguished in connection with the closing of the InfraREIT Acquisition.

The InfraREIT Acquisition expanded Oncor’s existing footprint in Texas by adding various electricity transmission and distribution assets and projects in the north, central, west and panhandle regions of Texas. The assets we acquired through the acquisition of InfraREIT’s subsidiaries included approximately 1,575 miles of transmission lines, including approximately 1,235 circuit miles of 345kV transmission lines and approximately 340 circuit miles of 138kV transmission lines. The central, north and west Texas transmission system we acquired in the transaction is directly connected to approximately 20 operational generation facilities totaling approximately 3,900 MW and serves over 50 transmission stations and substations. The projects acquired include a joint project with LP&L, with costs to ultimately be split by Oncor and LP&L that involves the build out of transmission lines and associated station work to join the City of Lubbock to the ERCOT market. For more information on this project, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Business — Significant Activities and Events — Joint Project with LP&L.”

Asset Exchange

On May 16, 2019, immediately prior to the InfraREIT Acquisition, the SDTS-SU Asset Exchange was completed. Additionally, immediately prior to the closing of the SDTS-SU Asset Exchange, the equity interests and related economic interests in SDTS held by SU were cancelled. SDTS became our wholly owned, indirect subsidiary in connection with the SDTS-SU Asset Exchange and the InfraREIT Acquisition and was renamed “Oncor Electric Delivery Company NTU LLC”.

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In connection with the SDTS-SU Asset Exchange, pursuant to the joint survivor merger of SU and SDTS, (i) SDTS assumed certain real property and other assets owned by SU and used in the electric transmission and distribution business in the central, north and west and panhandle regions of Texas, as well as equity interests in GS Project Entity, L.L.C., a Texas limited liability company, that was merged with and into SDTS and (ii) SU assumed certain real property and other assets owned by SDTS and used in the electric transmission and distribution business in the vicinity of the Texas-Mexico border, including certain real property and other assets that SDTS owned and leased to SU.

The SDTS-SU Asset Exchange was structured to qualify, in part, as a simultaneous tax deferred like kind exchange of assets to the extent that the assets exchanged are of “like kind” (within the meaning of Section 1031 of the Internal Revenue Code of 1986). SDTS paid approximately $13.18 million to SU at closing to settle the difference between the sums of the estimated net book value of the assets and liabilities exchanged and the estimated net working capital amounts associated with the SDTS-SU Asset Exchange. In August 2019, SU paid $8 million to NTU pursuant to the SDTS-SU Asset Exchange agreement as a post-closing true-up to settle the difference between the final net book value of the assets and liabilities exchanged and the final net working capital amounts associated with the SDTS-SU Asset Exchange.

In addition, as a condition to the closing of the SDTS-SU Asset Exchange, the Sempra-Sharyland Transaction was completed. As a result of the Sempra-Sharyland Transaction, Sharyland is now our affiliate for purposes of PUCT rules. Pursuant to the agreement governing the SDTS-SU Asset Exchange and the PUCT order in Docket No. 48929 approving the InfraREIT Acquisition, upon closing of the InfraREIT Acquisition we entered into an operation agreement pursuant to which we will provide certain operations services to Sharyland at cost with no markup or profit.

March 2020 Term Loan Agreement

On March 23, 2020, we entered into an unsecured term loan credit agreement (as amended, the March 2020 Term Loan Agreement) with Wells Fargo Bank, National Association (Wells Fargo), the administrative agent and a lender under the agreement with a commitment equal to an aggregate principal amount of $350 million. As amended, the March 2020 Term Loan Agreement has a maturity date of June 30, 2021. We may borrow up to $350 million in up to four borrowings which may be made, at our option, at any time in the period beginning on April 1, 2020 and ending on the earliest to occur of (i) the date on which the term loans are funded in full and no commitments remain unused, (ii) the fourth funding date and (iii) 5:00 p.m. Eastern time on August 7, 2020. As amended, the March 2020 Term Loan Agreement provides for loans to bear interest at per annum rates equal to, at our option, (x) LIBOR plus 0.950%, or (y) an alternate base rate (the highest of (1) the prime rate of Wells Fargo, (2) the federal funds effective rate plus 0.50%, and (3) daily one-month LIBOR plus 1%). No amounts were outstanding under the March 2020 Term Loan Agreement as of March 31, 2020. On June 30, 2020, we made our first borrowing under the March 2020 Term Loan Agreement, in the amount of $15 million.

Notice of Corporate Separateness

We and our equity owners have implemented certain structural and operational “ring-fencing” measures that are intended to further separate us from our direct and indirect owners, including our majority indirect equity owner, Sempra. See this “Prospectus Summary” section for more information regarding these “ring-fencing” measures. By your receipt of this prospectus, you acknowledge the receipt of the notice of corporate separateness given hereby.

We are a limited liability company organized under the laws of the State of Delaware, formed in 2007 as the successor entity to Oncor Electric Delivery Company, formerly known as TXU Electric Delivery Company, a corporation formed under the laws of the State of Texas in 2001. Our principal executive offices are located at 1616 Woodall Rodgers Freeway, Dallas, TX 75202. The telephone number of our principal executive offices is (214) 486-2000. Our Internet address is http://www.oncor.com. Information on our website or available by hyperlink from our website does not constitute part of this prospectus.

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The Exchange Offers

On March 20, 2020, we issued $400,000,000 aggregate principal amount of 2.75% Senior Secured Notes due 2030 (outstanding 2030 notes) and $400,000,000 aggregate principal amount of 3.70% Senior Secured Notes due 2050 (outstanding 2050 notes, collectively with the outstanding 2030 notes, the outstanding notes) in a private offering. The term “2030 exchange notes” refers to the 2.75% Senior Secured Notes due 2030 and the term “2050 exchange notes” refers to the 3.70% Senior Secured Notes due 2050, each as registered under the Securities Act that are subject to the exchange offers, and all of which collectively are referred to as the “exchange notes.” The term “notes” collectively refers to the outstanding notes and the exchange notes.

General In connection with the private offerings of the outstanding notes, we entered into a registration rights agreement with the initial purchasers in such offerings pursuant to which we agreed, among other things, to deliver this prospectus to you and to use commercially reasonable efforts to complete the exchange offers within 315 days after the date of original issuance of the outstanding notes. You are entitled to exchange in the exchange offers your outstanding notes for the exchange notes that are identical in all material respects to the outstanding notes except:

• the exchange notes have been registered under the Securities Act;

• the exchange notes are not entitled to any registration rights which are applicable to the outstanding notes under the registration rights agreement; and

• the additional interest provision of the registration rights agreement is not applicable.

The Exchange Offers We are offering to exchange:

• $400,000,000 aggregate principal amount of 2.75% Senior Secured Notes due 2030 that have been registered under the Securities Act for any and all of our existing restricted 2.75% Senior Secured Notes due 2030; and

• $400,000,000 aggregate principal amount of 3.70% Senior Secured Notes due 2050 that have been registered under the Securities Act for any and all of our existing restricted 3.70% Senior Secured Notes due 2050.

You may only exchange outstanding notes in minimum denominations of $2,000 and integral multiples of $1,000 in excess of $2,000.

Resale Based on an interpretation by the staff of the SEC set forth in no-action letters issued to third parties, we believe that the exchange notes issued pursuant to the exchange offers in exchange for the outstanding notes may be offered for resale, resold and otherwise transferred by you (unless you are our “affiliate” within the meaning of Rule 405 under the Securities Act) without compliance with the registration and prospectus delivery provisions of the Securities Act, provided that:

• you are acquiring the exchange notes in the ordinary course of your business; and

• you have not engaged in, do not intend to engage in, and have no arrangement or understanding with any person to participate in, a distribution of the exchange notes.

If you are a broker-dealer and receive exchange notes for your own account in exchange for outstanding notes that you acquired as a result of market-making activities or other trading activities, you must acknowledge that you will deliver this prospectus in connection with any resale of the exchange notes and that you are not our affiliate and did not purchase your outstanding notes from us or any of our affiliates. See “Plan of Distribution.”

Any holder of outstanding notes who:

• is our affiliate;

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• does not acquire exchange notes in the ordinary course of its business; or

• tenders its outstanding notes in the exchange offers with the intention to participate, or for the purpose of participating, in a distribution of exchange notes

cannot rely on the position of the staff of the SEC enunciated in Morgan Stanley & Co. Incorporated (available June 5, 1991) and Exxon Capital Holdings Corporation (available May 13, 1988), as interpreted in Shearman & Sterling (available July 2, 1993), or similar no-action letters and, in the absence of an exemption therefrom, must comply with the registration and prospectus delivery requirements of the Securities Act in connection with any resale of the exchange notes.

Our belief that the exchange notes may be offered for resale without compliance with the registration or prospectus delivery provisions of the Securities Act is based on interpretations of the SEC for other exchange offers that the SEC expressed in some of its no-action letters to other issuers in exchange offers like ours. We cannot guarantee that the SEC would make a similar decision about our exchange offers. If our belief is wrong, or if you cannot truthfully make the representations mentioned above, and you transfer any exchange note issued to you in the exchange offers without meeting the registration and prospectus delivery requirements of the Securities Act, or without an exemption from such requirements, you could incur liability under the Securities Act. We are not indemnifying you for any such liability.

Expiration Date The exchange offers will expire at 5:00 p.m., New York City time, on August 11, 2020, unless extended by us. We do not currently intend to extend the expiration date.

Withdrawal You may withdraw the tender of your outstanding notes at any time prior to the expiration of the exchange offers. We will return to you any of your outstanding notes that are not accepted for any reason for exchange, without expense to you, promptly after the expiration or termination of the exchange offers.

Conditions to the Exchange Offers Each exchange offer is subject to customary conditions. We reserve the right to waive any defects, irregularities or conditions to exchange as to particular outstanding notes. See “The Exchange Offers—Conditions to the Exchange Offers.”

Procedures for Tendering Outstanding Notes If you wish to participate in either of the exchange offers, you must either:

• complete, sign and date the applicable accompanying letter of transmittal, or a facsimile of the letter of transmittal, in accordance with the instructions contained in this prospectus and the letter of transmittal, and mail or deliver such letter of transmittal or facsimile thereof to the exchange agent at the address set forth on the cover page of the letter of transmittal; or

• if you hold outstanding notes through The Depository Trust Company (DTC), comply with DTC’s Automated Tender Offer Program procedures described in this prospectus, by which you will agree to be bound by the letter of transmittal.

By signing, or agreeing to be bound by, the letter of transmittal, you will represent to us that, among other things:

• you are not our “affiliate” within the meaning of Rule 405 under the Securities Act;

• you have no arrangement or understanding with any person to participate in the distribution of the exchange notes;

• you are not engaged in, and do not intend to engage in, a distribution of the exchange notes;

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• you are acquiring the exchange notes in the ordinary course of your business;

• if you are a broker-dealer, you did not purchase your outstanding notes from us or any of our affiliates; and

• if you are a broker-dealer that will receive exchange notes for your own account in exchange for outstanding notes that were acquired as a result of market-making activities, you will deliver a prospectus, as required by law, in connection with any resale of such exchange notes.

Special Procedures for Beneficial Owners If you are a beneficial owner of outstanding notes that are registered in the name of a broker, dealer, commercial bank, trust company or other nominee, and you wish to tender those outstanding notes in either of the exchange offers, you should contact the registered holder promptly and instruct the registered holder to tender those outstanding notes on your behalf. If you wish to tender on your own behalf, you must, prior to completing and executing the letter of transmittal and delivering your outstanding notes, either make appropriate arrangements to register ownership of the outstanding notes in your name or obtain a properly completed bond power from the registered holder. The transfer of registered ownership may take considerable time and may not be able to be completed prior to the expiration date.

Guaranteed Delivery Procedures If you wish to tender your outstanding notes and your outstanding notes are not immediately available, or you cannot deliver your outstanding notes, the letter of transmittal or any other required documents, or you cannot comply with the procedures under DTC’s Automated Tender Offer Program for transfer of book-entry interests prior to the expiration date, you must tender your outstanding notes according to the guaranteed delivery procedures set forth in this prospectus under “The Exchange Offers—Guaranteed Delivery Procedures.”

Effect on Holders of Outstanding Notes As a result of the making of, and upon acceptance for exchange of all validly tendered outstanding notes pursuant to the terms of, the exchange offers, we will have fulfilled a covenant under the registration rights agreement. Accordingly, there will be no increase in the applicable interest rate on the outstanding notes under the circumstances described in the registration rights agreement. If you do not tender your outstanding notes in either of the exchange offers, you will continue to be entitled to all the rights and limitations applicable to the outstanding notes as set forth in the Indenture (as defined below), except we will not have any further obligation to you to provide for the exchange and registration of untendered outstanding notes under the registration rights agreement. To the extent that outstanding notes are tendered and accepted in the exchange offers, the trading market for outstanding notes that are not so tendered and accepted could be adversely affected.

Consequences of Failure to Exchange All untendered outstanding notes will remain outstanding and continue to be subject to the restrictions on transfer set forth in the outstanding notes and in the Indenture. In general, the outstanding notes may not be offered or sold unless registered under the Securities Act, except pursuant to an exemption from, or in a transaction not subject to, the Securities Act and applicable state securities laws. Other than in connection with the exchange offers, we do not currently anticipate that we will register the outstanding notes under the Securities Act.

United States Federal Income Tax Consequences The exchange of outstanding notes for exchange notes in the exchange offers will not be a taxable event for U.S. federal income tax purposes. See “Summary of Material United States Federal Income Tax Consequences.”

Use of Proceeds We will not receive any proceeds from the issuance of the exchange notes in the exchange offers. See “Use of Proceeds.”

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Exchange Agent The Bank of New York Mellon Trust Company, N.A. is the exchange agent for the exchange offers. Any questions and requests for assistance, requests for additional copies of this prospectus or of the applicable letter of transmittal and requests for the notice of guaranteed delivery should be directed to the exchange agent. The address and telephone number of the exchange agent are set forth in the section captioned “The Exchange Offers—Exchange Agent.”

The Exchange Notes

The summary below describes the principal terms of the exchange notes. Certain of the terms and conditions described below are subject to important limitations and exceptions. The “Description of the Notes” section of this prospectus contains more detailed descriptions of the terms and conditions of the outstanding notes and exchange notes. The exchange notes will have terms identical in all material respects to the respective series of outstanding notes, except that the exchange notes will not contain terms with respect to transfer restrictions, registration rights and additional interest for failure to observe certain obligations in the registration rights agreement.

Securities Offered $800,000,000 aggregate principal amount of exchange notes consisting of:

• $400,000,000 principal amount of 2030 exchange notes; and

• $400,000,000 principal amount of 2050 exchange notes.

Maturity Date The exchange notes will mature on each of the following dates:

• May 15, 2030 for the 2030 exchange notes; and

• May 15, 2050 for the 2050 exchange notes.

Indenture We will issue the exchange notes under the Indenture, dated as of August 1, 2002, as amended and supplemented (the Indenture), between us and The Bank of New York Mellon Trust Company, N.A. (as successor to The Bank of New York Mellon, formerly The Bank of New York), as trustee (the Trustee).

Interest Rate The 2030 exchange notes and the 2050 exchange notes will bear interest at an annual rate equal to 2.75% and 3.70%, respectively. Interest will be calculated on the basis of a 360-day year consisting of twelve 30-day months, and with respect to any period less than a full month, on the basis of the actual number of days elapsed during the period.

Interest Payment Dates Interest on the exchange notes will accrue from and including the date of original issuance. Oncor will pay interest in U.S. dollars on the exchange notes semi-annually on May 15 and November 15 of each year, beginning on November 15, 2020.

Ranking The exchange notes will be senior secured obligations of Oncor and will rank pari passu with our other secured indebtedness. The exchange notes will be senior in right of payment to all subordinated indebtedness. At March 31, 2020, we had $9.019 billion principal amount of senior secured debt outstanding, which is secured by the Collateral (as defined below).

Collateral Our obligations under the exchange notes will be secured by a lien on certain of our transmission and distribution assets, mortgaged under our deed of trust (as amended, Deed of Trust), dated as of May 15, 2008, from us to The Bank of New York Mellon Trust Company, N.A. (as successor to The Bank of New York Mellon, formerly The Bank of New York), as collateral agent, as described in the Deed of Trust (Collateral). See “Description of the Notes — Security.”

Optional Redemption We may at our option redeem all or part of the exchange notes at the respective “make-whole” redemption prices discussed in this prospectus under “Description of the Notes — Optional Redemption,” plus accrued and unpaid interest to but excluding the date fixed for redemption.

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Limitation of Secured Debt If any of the exchange notes are outstanding under the Indenture, we will not issue, incur or assume any debt secured by a lien upon any of our property (other than Excepted Property, as defined in the Indenture), except for certain permitted secured debt, unless the exchange notes are also secured by that lien, without the consent of the holders of a majority in principal amount of all outstanding securities issued under the Indenture, including the exchange notes. See “Description of the Notes — Limitation on Secured Debt.”

Risk Factors You should consider carefully all of the information set forth in this prospectus prior to exchanging your outstanding notes. In particular, we urge you to consider carefully the factors set forth under the heading “Risk Factors.”

No Prior Market The exchange notes have no established trading market. We have not listed and do not intend to list any of the exchange notes on any securities exchange. Certain financial institutions have informed us that they intend to make a market in the exchange notes. However, these financial institutions may cease their market-making efforts at any time. If no active trading market exists, you may not be able to resell the exchange notes at their fair market value or at all.

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Summary Consolidated Financial Data of Oncor and Subsidiaries

The following table sets forth our summary historical consolidated financial data as of and for the periods indicated. The summary financial data as of March 31, 2020 and for the three months ended March 31, 2020 have been derived from our Interim Financial Statements. The summary financial data as of December 31, 2019 and 2018 and for each of the three fiscal years ended December 31, 2019, 2018 and 2017, have been derived from our Annual Financial Statements. The summary financial data as of December 31, 2017, 2016 and 2015 and for the years ended December 31, 2016 and 2015 have been derived from our historical consolidated financial statements that are not included in this prospectus.

The summary consolidated financial data should be read in conjunction with “Selected Financial Data” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this prospectus.

	At March 31,			At December 31,
	2020			2019			2018			2017			2016			2015
	(millions of dollars, except ratios)
Total assets	$	27,754		$	27,036		$	22,752		$	22,120		$	20,811		$	19,287
Property, plant & equipment — net		19,816			19,370			16,090			14,879			13,829			13,024
Goodwill		4,740			4,740			4,064			4,064			4,064			4,064
Capitalization:
Long-term debt, less amounts due currently (a)	$	9,256		$	8,017		$	5,835		$	5,567		$	5,515		$	5,646
Membership interests		10,904			10,799			8,460			7,903			7,711			7,508
Total	$	20,160		$	18,816		$	14,295		$	13,470		$	13,226		$	13,154
Capitalization ratios (b):
Long-term debt, less amounts due currently		45.9	%		42.6	%		40.8	%		41.3	%		41.7	%		42.9	%
Membership interests		54.1			57.4			59.2			58.7			58.3			57.1
Total		100.0	%		100.0	%		100.0	%		100.0	%		100.0	%		100.0	%

(a) As of March 31, 2020, the amount is reduced by $65 million of unamortized discount and debt issuance costs related to our outstanding long-term debt securities, as of that date.

(b) For purposes of reporting to the PUCT, the regulatory capitalization ratio at March 31, 2020 and December 31, 2019 was 56.5% debt to 43.5% equity and 54.8% debt to 45.2% equity, respectively. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Short-Term Debt Activity,” Note 7 to Interim Financial Statements and Note 9 to Annual Financial Statements for additional information regarding regulatory capitalization ratios.

	Three Months Ended March 31,			Year Ended December 31,
	2020			2019			2018			2017			2016			2015
	(millions of dollars, except ratios)
Operating revenues	$	1,072		$	4,347		$	4,101		$	3,958		$	3,920		$	3,878
Net income	$	131		$	651		$	545		$	419		$	431		$	432
Capital expenditures	$	628		$	2,097		$	1,767		$	1,631		$	1,352		$	1,154
Embedded interest cost on long-term debt — end of period (a)		4.6	%		4.8	%		5.1	%		5.5	%		5.6	%		5.8	%

(a) Represents the annual interest and amortization of any discounts, premiums, issuance costs (including the effects of interest rate hedges) and any deferred gains/losses on reacquisitions divided by the carrying value of the debt plus or minus the unamortized balance of any discounts, premiums, issuance costs (including the effects of interest rate hedges) and gains/losses on reacquisitions at the end of the year.

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RISK FACTORS

You should carefully consider the risk factors set forth below as well as the other information contained in this prospectus before deciding to participate in the exchange offers. Any of these risks could materially and adversely affect our business, financial condition, operating results or cash flow; however, these risks are not our only risks. Additional risks and uncertainties not currently known to us or those we currently view to be immaterial also may materially and adversely affect our business, financial condition, results of operations or cash flow. In such a case, the trading price of the exchange notes could decline or we may not be able to make payments of interest and principal on the exchange notes, and you may lose all or part of your original investment.

Risks Related to Our Business

Our business is subject to ongoing complex governmental regulations and legislation that have impacted, and will continue in the future to impact, our business and/or results of operations.

Our business operates in a changing market environment influenced by various state and federal legislative and regulatory initiatives regarding the restructuring of the energy industry. We will need to continually adapt to these changes.

Our business is subject to changes in state and federal laws (including PURA, the Federal Power Act, the Public Utility Regulatory Policies Act of 1978 and the Energy Policy Act of 2005), changing governmental policy, and regulatory actions by the PUCT, and other governmental authorities (including the NERC, the Texas RE, the TCEQ, the FERC and the EPA), and the rules, guidelines and protocols of ERCOT with respect to matters including, but not limited to, market structure and design, construction and operation of transmission and distribution facilities, acquisition, disposal, depreciation and amortization of regulated assets and facilities, recovery of costs and investments, return on invested capital and environmental matters. Changes in, revisions to, or reinterpretations of existing laws and regulations and other regulatory actions may have an adverse effect on our business and/or results of operations and we could be exposed to increased costs to comply with the more stringent requirements or new interpretations and to potential liability for customer refunds, penalties or other amounts.

In addition, if it is determined that we did not comply with applicable statutes, regulations, rules, tariffs or orders and we are ordered to pay a material amount in customer refunds, penalties or other amounts, our financial condition, results of operations and cash flows would be materially adversely affected. For example, under the Energy Policy Act of 2005, the FERC can impose penalties (up to $1 million per day per violation) for failure to comply with mandatory electric reliability standards, including standards to protect the power system against potential disruptions from cyber and physical security breaches. In addition, the PUCT may impose penalties on us if it finds that we violated any law, regulation, PUCT order or other rule or requirement. The PUCT has the authority to impose penalties of up to $25,000 per day per violation.

The Texas Legislature meets every two years. The Texas Legislature was in session from January 8, 2019 to May 27, 2019. During the 2019 regular legislative session, no legislation passed that is expected to have a material impact on our financial position, results of operations or cash flows. However, at any time, the governor may convene a special session of the Texas Legislature. During any regular or special session, bills may be introduced that if adopted could materially and adversely affect our business and our business prospects.

The rates of our electricity delivery business are subject to regulatory review and may be reduced below current levels, which could adversely impact our financial condition and results of operations.

The rates we charge are regulated by the PUCT and certain cities and are subject to cost-of-service regulation and annual earnings oversight. This regulatory treatment does not provide any assurance as to achievement of earnings levels. Our rates are regulated based on an analysis of our costs and capital structure, as reviewed and approved in a regulatory proceeding. While rate regulation is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital, there can be no assurance that the PUCT will judge all of our costs to have been prudently incurred, that the PUCT will not reduce the amount of invested capital included in the capital structure that our rates are based upon, or that the regulatory process in which rates are determined will always result in rates that will produce full recovery of our costs, including regulatory assets reported in the balance sheet, and the return on invested capital allowed by the PUCT.

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Our business could be adversely affected by health epidemics and pandemics, including the current COVID-19 pandemic.

We face risks related to health epidemics and pandemics, including the COVID-19 pandemic, which could lead to the disruption of our business operations by impacting the global economy and our employees, REPs, end-users, wholesale customers, network transmission customers, service providers, vendors and suppliers. These effects could also have a variety of adverse impacts on us, including reduced demand for energy, particularly from commercial and industrial customers, delayed or delinquent customer payments to us, slowing growth in our service territory, reduced availability or productivity of our workforce, constraints on our supply chain, impairment of goodwill or long-lived assets, increased pension funding requirements due to a decline in pension asset values, impairment of our ability to develop, construct and/or operate electricity delivery facilities, and impairment of our ability to access funds from financial institutions and capital markets. COVID-19 has been declared a pandemic by the World Health Organization and has spread globally, including throughout the United States and Texas. The COVID-19 pandemic is currently impacting the global economy, communities, and supply chains around the world. COVID-19 has also adversely affected conditions in the capital and credit markets and may adversely affect our cost of and access to debt financing. To date, COVID-19 has not had a material adverse impact on our operations, supply chain, liquidity, financial condition, or results of operations. We have taken several precautionary and preemptive actions in response to COVID-19 to protect our workforce and critical operations pursuant to our pandemic response plan, including requiring employees to work remotely when possible and restricting non-essential employee travel. We are also actively managing our supply chain and communicating regularly with key vendors and suppliers.

We will continue to monitor the COVID-19 pandemic and its impacts and may take further actions that alter our business operations as may be required by federal, state or local authorities, or that we determine are in the best interests of our employees, customers and suppliers. The extent to which COVID-19 does impact our results will ultimately depend on future developments, which are highly uncertain, and will include emerging information concerning the severity of COVID-19, the duration of the pandemic, and the actions taken by governments and private businesses to attempt to contain COVID-19. Therefore, we cannot predict whether, or to what extent, the COVID-19 pandemic will have a material adverse impact on our operations, supply chain, liquidity, financial condition, or results of operations.

Attacks on our infrastructure or other events that disrupt or breach our cyber/data or physical security measures, as well as attacks on our third-party vendors, could have an adverse impact on our reputation, disrupt business operations and expose us to significant liabilities including penalties for failure to comply with federal, state or local statutes and regulations, which could have a material effect on our results of operations, liquidity and financial condition.

A breach of cyber/data security measures that impairs our information technology infrastructure or other loss of key technology platforms could disrupt normal business operations and affect our ability to control our transmission and distribution assets, access customer information and limit communication with third parties. In the ordinary course of business, we collect and retain sensitive information, including customer information and personal information about employees. We face various cyber and data risks, including malware, computer viruses, unauthorized access attempts, cyber or phishing attacks. While we have controls in place designed to protect our information technology infrastructure and are not aware of any significant breaches to date, any loss of confidential or proprietary data through a breach, including a breach involving one of our third-party vendors, could adversely affect our reputation, expose us to material legal and regulatory claims and fines, require compliance with notification and monitoring regulations, impair our ability to execute on business strategies and/or materially affect our results of operations, liquidity and financial condition.

A physical attack on our transmission and distribution infrastructure could also interfere with normal business operations and affect our ability to control our transmission and distribution assets. While we have security measures in place designed to protect our transmission and distribution system and have not had any significant security breaches, a physical security breach could adversely affect our reputation, expose us to material regulatory penalties and/or materially affect our results of operations, liquidity and financial condition.

We rely on third parties for various services. If these third parties experience cyber attacks, the services they provide us could be disrupted. This disruption could interfere with our ability to perform our obligations to others, which could negatively affect our financial condition and reputation. In addition, the theft, damage, or improper disclosure of sensitive data held by these third parties may subject us to further harm.

Under the Energy Policy Act of 2005, the FERC can impose penalties (up to $1 million per day per violation) for failure to comply with mandatory electric reliability standards, including standards to protect the power system against potential disruptions from cyber and physical security breaches.

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We participate in industry groups and discussions with regulators to remain current on emerging threats and mitigating techniques. These groups include, but are not limited to: the U.S. Cyber Emergency Response Team, the National Electric Sector Cyber Security Organization, the Department of Homeland Security, the U.S. Nuclear Regulatory Commission and NERC. We also apply the knowledge gained by continuing to invest in technology, processes, security measures and services to detect, mitigate and protect our assets, both physical and cyber. These investments include upgrades to network architecture and physical security measures, regular intrusion detection monitoring and compliance with emerging industry regulation.

Our capital deployment program may not be executed as planned, which could adversely impact our financial condition and results of operations.

There can be no guarantee that the execution of our capital deployment program for our electricity delivery facilities will be successful, and there can be no assurance that the capital investments we intend to make in connection with our electricity delivery business will produce the desired improvements to service and reliability or cost management. Furthermore, there can be no guarantee that our capital investments will ultimately be recoverable through rates or, if recovered, that they will be recovered on a timely basis. For more information regarding the limitation on recovering the value of investments using rates, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Key Risks and Challenges” and “– Regulation and Rates.”

Market volatility may impact our business and financial condition in ways that we currently cannot predict.

Because our operations are capital intensive, we expect to rely over the long term on access to financial markets, as a significant source of liquidity for capital requirements not satisfied by cash-on-hand, operating cash flows or our Credit Facility and CP Program. It is likely we will incur additional debt in connection with our large capital expenditure plan, which calls for construction projects to service our growing customer base and ERCOT needs, maintenance projects, and investments in information technology. Our ability to access the capital or credit markets may be severely restricted at a time when we would like, or need, to access those markets, which could have an impact on our flexibility to react to changing economic and business conditions. In addition, the cost of debt financing may be materially and adversely impacted by these market conditions. Even if we are able to obtain debt financing, we may be unable to recover in rates some or all of the costs of such debt financing if they exceed our PUCT-approved cost of debt determined in our most recent rate review or subsequent rate reviews. Accordingly, there can be no assurance that the capital and credit markets will continue to be a reliable or acceptable source of short-term or long-term financing for us. Additionally, disruptions in the capital and credit markets could have a broader impact on the economy in general in ways that could lead to reduced electricity usage, which could have a negative impact on our revenues, or have an impact on our customers, counterparties and/or lenders, causing them to fail to meet their obligations to us.

The phase out of LIBOR could affect interest rates under our variable rate debt and the overall interest rate environment.

In July 2017, the United Kingdom Financial Conduct Authority, which regulates LIBOR, announced that it intends to stop compelling banks to submit rates for the calculation of LIBOR after 2021. In addition, other regulators across the globe have suggested reforming or replacing other benchmark rates. Our Credit Facility and our term loan credit agreements use LIBOR as a benchmark for establishing interest rates. Our Credit Facility and our term loan credit agreements include mechanisms for amending each of them to reflect the establishment of an alternative rate of interest upon the occurrence of certain events related to the phase out of LIBOR. However, we have not yet pursued any technical amendments or other contractual alternatives to address this matter and are currently evaluating the impact of the potential replacement of the LIBOR interest rate. Our term loan credit agreements currently contain maturity dates that are prior to the anticipated date that any LIBOR phase out will occur. Any amendment or alternative provisions may not adequately address the actual changes to LIBOR or successor benchmark rates. A successor benchmark rate could be higher or more volatile than LIBOR prior to its discontinuance, which could negatively impact the cost of our variable rate debt, impact our ability to refinance some or all of our existing variable rate debt, influence the valuation of any derivative contracts or otherwise have a material adverse impact on our business, financial condition and results of operations. Additionally, the discontinuation, reform or replacement of LIBOR or any other benchmark rates may have an unpredictable impact on contractual mechanics in the credit markets or cause disruption to the broader financial markets. Uncertainty as to the nature of such potential discontinuation, reform or replacement could have a significant impact on the overall interest rate environment.

Adverse actions with respect to our credit ratings could negatively affect our ability to access capital.

Our access to capital markets and our cost of debt could be directly affected by our credit ratings. Any adverse action with respect to our credit ratings could generally cause borrowing costs to increase and the potential pool of investors and

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funding sources to decrease. Our credit ratings are currently higher than those of Sempra, our majority indirect equity owner. If credit rating agencies were to change their views of our independence from Sempra and its affiliates (other than the Oncor Ring-Fenced Entities), our credit ratings could decline. Despite our ring-fencing measures, rating agencies have in the past taken, and could in the future take, an adverse action with respect to our credit ratings in response to activities involving financing and liability management activities by our indirect majority equity owner. In the event any such adverse action takes place and causes our borrowing costs to increase, we may not be able to recover such increased costs if they exceed our PUCT-approved cost of debt determined in our most recent rate review or subsequent rate reviews.

Most of our large suppliers and counterparties require an expected level of creditworthiness in order for them to enter into transactions with us. If our credit ratings decline, the costs to operate our business could increase because counterparties could require the posting of collateral in the form of cash-related instruments, or counterparties could decline to do business with us.

We are subject to mandatory service quality and reliability standards. Efforts to comply with those standards could subject us to higher operating costs and/or increased capital expenditures, and non-compliance with applicable standards could subject us to penalties that could have a material effect on our business.

The PUCT has jurisdiction with respect to ensuring the service quality and reliability of the delivery of electricity to retail customers by electric utilities and has established reliability standards that apply to each utility. The FERC has jurisdiction with respect to ensuring the reliability of electric transmission service, including transmission facilities owned by utilities within ERCOT. The FERC has designated the NERC to establish and enforce reliability standards, under FERC oversight, for all owners, operators and users of the bulk power system. The FERC has approved the delegation by NERC of compliance and enforcement authority for reliability in the ERCOT region to the Texas RE.

To maintain compliance with the mandatory reliability standards, we may be subjected to higher operating costs and/or increased capital expenditures. While we expect to recover costs and expenditures from customers through regulated rates, there can be no assurance that the PUCT will approve full recovery of such costs or the timing of any such recovery. In addition, if we were found to be in noncompliance with applicable reliability standards, we could be subject to sanctions, including monetary penalties. Penalties imposed by the PUCT and NERC would not be recoverable from customers through regulated rates.

The PUCT is authorized to impose a penalty of up to $25,000 per violation per day if a utility fails to meet reliability standards. Oncor must report to the PUCT concerning its performance with respect to the applicable reliability standards on an annual basis. We cannot predict the outcome of any such reports or related potential enforcement actions.

Under the Energy Policy Act of 2005, FERC can impose penalties (up to $1 million per day per violation) for failure to comply with reliability standards, which would not be recoverable from customers through regulated rates. We have four registrations with NERC – as a transmission planner, a transmission owner, a transmission operator and a distribution provider. As a registered entity, we are subject to periodic audits by the Texas RE of our compliance with reliability standards. These audits will occur as designated by the Texas RE at a minimum of every three years. We cannot predict the outcome of any such audits.

Our revenues are concentrated in a small number of customers and any delay or default in payment could adversely affect our cash flows, financial condition and results of operations.

Our revenues from the distribution of electricity are collected from approximately 90 REPs and certain electric cooperatives in our certificated service area, that sell the electricity we distribute to consumers. REP subsidiaries of our two largest counterparties represented 25% and 18% of our total operating revenues for the three months ended March 31, 2020, respectively, and 23% and 18% for the year ended 2019. In addition, we collect network transmission revenues from distribution companies and cooperatives and municipalities. Currently, the majority of this network transmission customer revenue comes from customers who are investment grade and, as a result, generally considered low credit risk. PUCT rules allow for the recovery of uncollectible amounts due from REPs (but not network transmission customers) through rates. Adverse economic conditions, structural problems in the market served by ERCOT or the financial difficulties of one or more customers could adversely impact the credit rating of our customers, impair the ability of these customers to pay for our services or could cause them to delay such payments. We depend on these customers to timely remit these revenues to us. Delays or defaults in payment from customers could adversely affect our cash flows, financial condition and results of operations.

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In the future, we could have liquidity needs that could be difficult to satisfy under some circumstances, especially in uncertain financial market conditions.

Our operations are capital intensive. We rely on access to financial markets and our Credit Facility as a significant source of liquidity for capital requirements, including maturities of long-term debt, not satisfied by cash-on-hand or operating cash flows. The inability to raise capital on favorable terms or access liquidity facilities, particularly during times of uncertainty similar to those experienced in the financial markets in 2008 and 2009, could adversely impact our ability to sustain and grow our business and would likely increase capital costs that may not be recoverable through rates. Our access to the financial markets and our Credit Facility, and the pricing and terms we receive in the financial markets, could be adversely impacted by various factors, such as:

• changes in financial markets that reduce available credit or the ability to obtain or renew liquidity facilities on acceptable terms;

• economic weakness in the ERCOT market;

• changes in interest rates;

• a deterioration of our credit or a reduction in our credit ratings;

• a deterioration of the credit or insolvency or financial distress of one or more lenders under our Credit Facility that affects the ability of the lender(s) to make loans to us;

• a deterioration of the credit of Sempra or its affiliates (other than the Oncor Ring-Fenced Entities) or a reduction in the credit ratings of Sempra or such affiliates that is perceived to potentially have an adverse impact on us despite the ring-fencing of the Oncor Ring-Fenced Entities from Sempra and such affiliates;

• a material breakdown in our risk management procedures; and

• changes that restrict our ability to access our Credit Facility.

Our primary source of liquidity, aside from operating cash flows, has been our ability to borrow under our Credit Facility, which also supports our CP Program. Because our CP Program is supported by our Credit Facility, CP Notes outstanding is a reduction to the available borrowing capacity. The Credit Facility, our term loan credit agreements and the Note Purchase Agreements each contain a debt-to-capital ratio covenant that effectively limits our ability to incur indebtedness in the future. At March 31, 2020, we were in compliance with these covenants. See Note 4 to Interim Financial Statements and Note 6 to Annual Financial Statements for further information regarding this covenant and our Credit Facility, as well as our CP Program.

We are required to maintain a regulatory capital structure at or below the assumed debt-to-equity ratio established periodically by the PUCT for ratemaking purposes. That debt-to-equity ratio is 57.5% debt to 42.5% equity. At March 31, 2020, our regulatory capitalization ratio was 56.5% debt to 43.5% equity. Our ability to incur additional long-term debt will be limited by our regulatory capital structure and we are able to issue future long-term debt only to the extent that we will be in compliance therewith.

The costs of providing pension benefits and OPEB and related funding requirements may have a material adverse effect on our financial condition, results of operations and cash flows.

We offer certain pension and health care and life insurance benefits to eligible employees and their eligible dependents upon the retirement of such employees through pension and OPEB plans.

We also have contractual liabilities related to the Vistra Retirement Plan, a defined benefit pension plan. Until October 2016, we were a member of the same controlled group (within the meaning of ERISA) as Vistra. We also maintain an OPEB plan to cover eligible retirees of Oncor and EFH Corp./Vistra whose employment service were assigned to both Oncor (or a predecessor regulated utility bushiness) and the non-regulated business of EFH Corp./Vistra.

Our costs or share of the costs of providing pension and OPEB benefits and related funding requirements are dependent upon numerous factors, assumptions and estimates and are subject to changes in these factors, assumptions and estimates, including the market value of the assets funding the pension and OPEB plans. Benefits costs and related funding requirements are also subject to changing employee demographics (including but not limited to age, compensation levels and years of accredited service), the level of contributions made to retiree plans, expected and actual earnings on plan assets and the discount rates used in determining the projected benefit obligation. Changes made to the provisions of the plans may also impact current and future benefit costs. Fluctuations in actual market returns as well as changes in general interest rates may result in increased or decreased benefit costs in future periods.

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See Note 8 to Interim Financial Statements, Note 10 to Annual Financial Statements, “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Application of Critical Accounting Policies – Defined Benefit Pension Plans and OPEB Plans” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Financial Condition – Liquidity and Capital Resources – Pension and OPEB Plan Funding” for further information regarding pension and OPEB funding.

Our ring-fencing measures may not work as planned and a bankruptcy court may nevertheless subject Oncor to the claims of its affiliates’ creditors.

Various ring-fencing measures have been taken to enhance our credit quality and the separateness between the Oncor Ring-Fenced Entities, Sempra and its affiliates (other than the Oncor Ring-Fenced Entities), and any other direct or indirect owners of Oncor or Oncor Holdings. These enhancements are intended to minimize the risk that a court would order any of the Oncor Ring-Fenced Entities’ assets and liabilities to be substantively consolidated with those of Sempra or any of its affiliates or any other direct or indirect owners of Oncor or Oncor Holdings or their affiliates in connection with a bankruptcy of any such entities. Substantive consolidation is an equitable remedy in bankruptcy that results in the pooling of the assets and liabilities of the debtor and one or more of its affiliates solely for purposes of the bankruptcy case, including for purposes of distributions to creditors and voting on and treatment under a reorganization plan. Bankruptcy courts have broad equitable powers, and as a result, outcomes in bankruptcy proceedings are inherently difficult to predict. To the extent a bankruptcy court were to determine that substantive consolidation is appropriate under the facts and circumstances, then the assets and liabilities of any Oncor Ring-Fenced Entity that is subject to the substantive consolidation order would be available to help satisfy the debt or contractual obligations of the affiliated entity that is a debtor in bankruptcy and subject to the same substantive consolidation order. If any Oncor Ring-Fenced Entity were included in such a substantive consolidation order, the secured creditors of Oncor would retain their liens and priority with respect to Oncor’s assets.

See Note 1 to Annual Financial Statements and “Our Business and Properties – Ring-Fencing Measures” for additional information on our ring-fencing measures.

Goodwill that we have recorded is subject to at least annual impairment evaluations, and as a result, we could be required to write off some or all of this goodwill, which may adversely impact our financial condition and results of operations.

In accordance with accounting standards, recorded goodwill is not amortized but is reviewed annually or more frequently for impairment, if certain conditions exist, and may be impaired. Any reduction in or impairment of the value of goodwill will result in a charge against earnings, which may adversely impact our reported results of operations and financial condition. See Note 1 to Annual Financial Statements for more information about our goodwill impairment assessment and testing.

Our results of operations and financial condition could be negatively impacted by any development or event beyond our control that causes economic weakness in the ERCOT market, including the current COVID-19 pandemic.

We derive substantially all of our revenues from operations in the ERCOT market, which covers approximately 75% of the geographical area in the State of Texas. As a result, regardless of the state of the economy in areas outside the ERCOT market, economic weakness in the ERCOT market (including due to the current COVID-19 pandemic) could lead to reduced demand for electricity in the ERCOT market. Such a reduction could lead to slowing growth in our service territory and have a material adverse impact on our results of operations and financial condition. In addition, reduced demand for electricity in high growth areas of our service territory, such as west Texas, could lead to a material decrease in our construction projects and five-year capital expenditure projections. The majority of our west Texas growth is related to connecting oil and gas producers to the ERCOT grid. While we currently do not expect the impacts of the COVID-19 pandemic or the recent global reductions in oil and gas prices to have a material adverse impact on our capital expenditure plans, particularly with respect to 2020 projects (the majority of which do not require further ERCOT or PUCT construction approval), we continue to actively monitor the situation. If the situation deteriorates, however, it could adversely impact our future capital expenditure plans.

Disruptions at power generation facilities owned by third parties could interrupt our sales of transmission and distribution services.

The electricity we transmit and distribute to customers of REPs is obtained by the REPs from electricity generation facilities. We do not own or operate any generation facilities. If generation is disrupted or if generation capacity is inadequate, our sales of transmission and distribution services may be diminished or interrupted, and our results of operations, financial condition and cash flows may be adversely affected.

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The operation and maintenance of electricity delivery facilities involves significant risks that could adversely affect our results of operations and financial condition.

The operation and maintenance of delivery facilities involves many risks, including equipment breakdown or failure of facilities, lack of sufficient capital to maintain the facilities, impact of unusual or adverse weather conditions or other natural events, as well as the risk of performance below expected levels of efficiency or reliability, the occurrence of any of which could result in lost revenues and/or increased expenses that may not be recoverable through rates. A significant number of our facilities were constructed many years ago. In particular, older transmission and distribution equipment, even if maintained in accordance with good engineering practices, may require significant capital expenditures to keep operating at peak efficiency or reliability. A risk of increased maintenance and capital expenditures arises from damage to facilities due to storms, natural disasters, wars, terrorist acts and other catastrophic events. Further, our ability to successfully and timely complete capital improvements to existing facilities or other capital projects is contingent upon many variables and subject to substantial risks. Should any such efforts be unsuccessful, we could be subject to additional costs that may not be recoverable through rates and/or the write-off of our investment in the project or improvement.

Insurance, warranties or performance guarantees may not cover all or any of the lost revenues or increased expenses that could result from the risks discussed above. Likewise, our ability to obtain insurance, and the cost of and coverage provided by such insurance, could be affected by events outside our control.

Changes in technology or increased conservation efforts may reduce the value of our electricity delivery facilities and may significantly impact our business in other ways as well.

Research and development activities are ongoing to improve existing and alternative technologies to produce and store electricity, including gas turbines, fuel cells, microturbines, photovoltaic (solar) cells and concentrated solar thermal devices and batteries. It is possible that advances in these or other technologies will reduce the costs of electricity production from these technologies to a level that will enable these technologies to compete effectively with traditional generation plants. Changes in technology could also alter the channels through which retail customers buy electricity. To the extent self-generation or storage facilities become a more cost-effective option for certain customers, our revenues could be materially reduced.

Also, electricity demand could be reduced by increased conservation efforts and advances in technology, which could likewise significantly reduce the value of our electricity delivery facilities. Certain regulatory and legislative bodies have introduced or are considering requirements and/or incentives to reduce energy consumption by a fixed date. Effective energy conservation by our customers could result in reduced energy demand, or significantly slow the growth in demand. Such reduction in demand could materially reduce our revenues.

We are dependent upon a limited number of suppliers and service providers for certain of our operations. If any of these suppliers or service providers failed or became unable to perform on their agreements with us, it could disrupt our business and have an adverse effect on our cash flows, financial condition and results of operations.

We rely on suppliers and service providers to provide us with certain specialized materials and services, including materials and services for power line construction, maintenance and repair, information technology and customer operations. The financial condition of our suppliers and service providers may be adversely affected by general economic conditions, such as credit risk and turbulent macroeconomic events. Because many of the tasks of these suppliers and service providers require specialized electric industry knowledge and equipment, if any of these parties fail to perform, go out of business or otherwise become unable to perform, we may not be able to transition to substitute suppliers or service providers in a timely manner. This could delay our construction and improvement projects, increase our costs and disrupt our operations, which could negatively impact our business and reputation. In addition, we could be subject to fines or penalties in the event a delay resulted in a violation of a PUCT or other regulatory order.

Our revenues and results of operations are seasonal.

A significant portion of our revenues is derived from rates that we collect from REPs based on the amount of electricity we distribute on behalf of such REPs. Sales of electricity to residential and commercial customers are influenced by temperature fluctuations. Thus, our revenues and results of operations are subject to seasonality, weather conditions and other electricity usage drivers, with revenues being highest in the summer.

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The litigation environment in which we operate poses a significant risk to our business.

We are involved in the ordinary course of business in a number of lawsuits involving employment, commercial and environmental issues and other claims for injuries and damages, among other matters. Judges and juries in the State of Texas have demonstrated a willingness to grant large verdicts, including punitive damages, to plaintiffs in personal injury, property damage and business tort cases. We use appropriate means to contest litigation threatened or filed against us, but the litigation environment in the State of Texas poses a significant business risk.

The loss of the services of our key management and personnel could adversely affect our ability to operate our business.

Our future success will depend on our ability to continue to attract and retain highly qualified personnel. We compete for such personnel with many other companies, in and outside our industry, government entities and other organizations. We may not be successful in retaining our current personnel or in hiring or retaining qualified personnel in the future. Our failure to attract new personnel or retain our existing personnel could have a material adverse effect on our business.

We regularly evaluate opportunities to make selective strategic acquisitions involving regulated assets, such as the InfraREIT Acquisition that we completed in May 2019. Acquisitions involve various risks, and we may not be able to realize the anticipated benefits of any such acquisitions.

We regularly evaluate opportunities to make selective strategic acquisitions involving regulated assets. Additional equity or debt capital may be required to complete any acquisition. In addition, any acquisition may be structured in such a manner that could result in the assumption of secured or unsecured debt and other liabilities. Any such transaction may require PUCT and other regulatory approvals. An acquisition may involve risks relating to the combination of assets and facilities, the diversion of management’s attention and the impact on our credit ratings.

The InfraREIT Acquisition involved the acquisition of a business that owned primarily regulated electric transmission and distribution assets and was previously operated as an independent company. Any potential cost savings, synergies or other benefits from the transaction may not be fully realized or may take longer to realize than expected. In addition, some of the assets that we acquired have yet to undergo prudence review by the PUCT. There can be no assurance that the PUCT will judge all of the costs related to those assets to have been prudently incurred.

Risks Related to the Exchange Offers

There may be adverse consequences if you do not exchange your outstanding notes.

If you do not exchange your outstanding notes for exchange notes in the exchange offers, you will continue to be subject to restrictions on transfer of your outstanding notes as set forth in the offering memorandum distributed in connection with the March 2020 private offering of the outstanding notes. In general, the outstanding notes may not be offered or sold unless they are registered or exempt from registration under the Securities Act and applicable state securities laws. Except as required by the registration rights agreement, we do not intend to register resales of the outstanding notes under the Securities Act. You should refer to “Prospectus Summary—The Exchange Offers” and “The Exchange Offers” for information about how to tender your outstanding notes.

The tender of outstanding notes under the exchange offers will reduce the outstanding amount of the outstanding notes, which may have an adverse effect upon, and increase the volatility of, the market prices of the outstanding notes due to a reduction in liquidity.

Your ability to transfer the exchange notes may be limited if there is no active trading market, and there is no assurance that any active trading market will develop for the exchange notes.

We are offering the exchange notes to the holders of the outstanding notes. We do not intend to list the notes on any securities exchange. There is currently no established market for the exchange notes, and we cannot assure you as to the liquidity of markets that may develop for the exchange notes, your ability to sell the exchange notes or the price at which you would be able to sell the exchange notes. If such markets were to exist, the exchange notes could trade at prices that may be lower than their principal amount or purchase price depending on many factors, including prevailing interest rates, the market for similar notes, our financial and operating performance and other factors. Certain financial institutions have informed us that they intend to make a market in the notes after the exchange offers are completed. However, these financial institutions may cease their market-making efforts at any time without notice. We cannot assure you that an active market for the exchange notes will develop or, if developed, that it will continue. If no active trading market develops, you may not be able to resell the notes at their fair market value or at all.

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Certain persons who participate in the exchange offers must deliver a prospectus in connection with resales of the exchange notes.

We have not requested, and do not intend to request, an interpretation by the staff of the SEC as to whether the exchange notes issued pursuant to our exchange offers in exchange for the outstanding notes may be offered for resale, resold or otherwise transferred by any holder without compliance with the registration and prospectus delivery provisions of the Securities Act. Instead, based on interpretations of the staff of the SEC contained in Exxon Capital Holdings Corp., SEC no-action letter (April 13, 1988), Morgan Stanley & Co. Inc., SEC no-action letter (June 5, 1991) and Shearman & Sterling, SEC no-action letter (July 2, 1983), we believe that you may offer for resale, resell or otherwise transfer the exchange notes without compliance with the registration and prospectus delivery requirements of the Securities Act. We cannot guarantee that the SEC would make a similar decision about our exchange offers. If our belief is wrong, or if you cannot truthfully make the representations mentioned above, and you transfer any exchange note issued to you in the exchange offers without meeting the registration and prospectus delivery requirements of the Securities Act, or without an exemption from such requirements, you could incur liability under the Securities Act. Additionally, in some instances described in this prospectus under “Plan of Distribution,” certain holders of exchange notes will remain obligated to comply with the registration and prospectus delivery requirements of the Securities Act to transfer the exchange notes. If such a holder transfers any exchange notes without delivering a prospectus meeting the requirements of the Securities Act or without an applicable exemption from registration under the Securities Act, such a holder may incur liability under the Securities Act. We do not and will not assume, or indemnify such a holder against, this liability.

Risks Related to the Notes

The following risks apply to the outstanding notes and will apply equally to the exchange notes.

The market price of the notes will fluctuate.

Any material differences between our actual results and the historical results contained in our annual, quarterly and current reports filed with the SEC could have a significant adverse impact on the market price of the notes, assuming a market for the notes develops. In addition, any downgrade of our credit ratings could have an adverse impact on the market price of the notes.

The terms of the notes contain limited covenants and other protections.

The Indenture governing the notes contains covenants restricting our ability to take certain actions. However, each of these covenants contains specified exceptions. In addition, these covenants are limited and do not protect holders of the notes from all events that could have a negative effect on the creditworthiness of the notes and the market price of the notes, assuming a market for the notes develops.

The Indenture and the Deed of Trust permit us to incur significant additional debt. Accordingly, the Indenture will not afford the holders of the notes protection in the event we incur significant additional debt.

The notes and the Indenture under which the notes are issued do not place any limitation on the amount of unsecured debt that may be incurred by us. The Indenture and the Deed of Trust also permit us to incur a significant amount of additional secured debt, including debt secured equally and ratably by the Collateral, subject to certain limitations, as described further under “Description of the Notes —Securing Additional Obligations” and “—Limitation on Secured Debt.” Our incurrence of additional debt may have important consequences for holders of the notes, including making it more difficult for us to satisfy our obligations with respect to the notes, a loss in the trading value of the notes, if any, and a risk that the credit rating of the notes is lowered or withdrawn. The covenants contained in the Indenture and the Deed of Trust will not afford holders of notes protection in the event we incur significant additional debt.

It may be difficult to realize the value of the Collateral securing the notes.

Each of the assets and facilities that will be included in the Collateral is subject to the same kinds of risks as are described under “—Risks Related to Our Business.” We cannot provide any assurance that any of the necessary permits, certificates or other entitlements to operate those assets and facilities would be transferable to the Trustee or any purchaser from the Trustee in the event of a foreclosure upon that asset or facility. The Trustee’s ability to foreclose on the Collateral on behalf of the holders of the notes may be subject to perfection, the consent of third parties and, with respect to those assets that are subject to the jurisdiction of the PUCT and the FERC, the prior approval by the PUCT and the FERC. The Trustee’s ability to foreclose may also be subject to priority issues and practical problems associated with the realization of the Trustee’s security interest in the Collateral. We cannot assure holders of the notes that the consents of any third parties and approvals by governmental entities will be given when required to implement a foreclosure on such assets, especially if we are not in

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compliance with the underlying permits at the time. Accordingly, the Trustee may not have the ability to foreclose upon those assets or assume or transfer the right to operate those assets or facilities, and a temporary shutdown of operations may result and the value of the Collateral may significantly decrease. Even if the Trustee assumes the right to operate the assets and facilities, there may also be practical problems associated with the Trustee’s ability to identify a qualified operator to operate and maintain the assets and facilities. In addition, future regulatory developments or other inabilities to obtain or comply with required permits may adversely affect the value of the Collateral.

No appraisals of any Collateral have been prepared in connection with the exchange offers. The value of the Collateral at any time will depend on market and other economic conditions, including the availability of suitable buyers for the Collateral. By their nature some or all of the pledged assets may be illiquid and may have no readily ascertainable market value. We cannot assure holders of the notes that the fair market value of the Collateral as of the date of this prospectus exceeds the principal amount of the debt secured thereby. The value of the assets pledged as Collateral for the notes could be impaired in the future as a result of changing economic conditions, our failure to implement our business strategy, competition and other future trends.

Bankruptcy laws may limit your ability to realize value from the Collateral.

The right of the Trustee to repossess and dispose of the Collateral upon the occurrence of an event of default under the Indenture is likely to be significantly impaired by applicable bankruptcy law if a bankruptcy case were to be commenced by or against us prior to the Trustee having repossessed and disposed of, or otherwise exercised remedies in respect of, the Collateral. Under the U.S. Bankruptcy Code, a secured creditor is prohibited from repossessing its security from a debtor in a bankruptcy case, or from disposing of a security repossessed from such debtor, without bankruptcy court approval. Moreover, the U.S. Bankruptcy Code permits the debtor to continue to retain and to use collateral even though the debtor is in default under the applicable debt instrument, provided that the secured creditor is given “adequate protection.” The meaning of the term “adequate protection” may vary according to circumstances, but it is intended in general to protect the value of the secured creditor’s interest in the collateral and may include cash payments or the granting of additional security, if and at such times as the court in its discretion determines that the value of the secured creditor’s interest in the collateral is declining during the pendency of the bankruptcy case. In view of the lack of a precise definition of the term “adequate protection” and the broad discretionary powers of a bankruptcy court, it is impossible to predict (1) how long payments under the notes could be delayed following the commencement of a bankruptcy case, (2) whether or when the Trustee could repossess or dispose of the Collateral and (3) whether or to what extent holders of the notes would be compensated for any delay in payment or loss of value of the Collateral through the requirement of “adequate protection.”

In the event a bankruptcy court determines the value of the Collateral is not sufficient to repay all amounts due on the notes and any other obligations secured by the Collateral then the holders of the notes and such other obligations would hold secured claims to the extent of the value of the Collateral securing such claims, and would hold unsecured claims with respect to any shortfall. Applicable federal bankruptcy laws may not permit the payment and/or accrual of post-petition interest (including make-whole premiums), costs and attorneys’ fees during a debtor’s bankruptcy case. In addition, if we were to become the subject of a bankruptcy case, the bankruptcy trustee or debtor may seek to avoid certain pre-petition transfers made by us, including transfers held to be preferences or fraudulent conveyances. While transfers to secured creditors are generally not preferential, transfers to undersecured creditors may be subject to avoidance.

Any future pledges of Collateral may be avoidable.

Any further pledge of Collateral in favor of the Trustee may be avoidable by the pledgor (as debtor in possession) or by its trustee in bankruptcy or other third parties if certain events or circumstances exist or occur, such that the pledge or granting of the security interest is deemed a fraudulent conveyance or preference.

The Trustee’s ability to exercise remedies with respect to Collateral is limited.

The Deed of Trust provides the Trustee on behalf of the holders of obligations secured by the Deed of Trust with significant remedies, including foreclosures and sale of all or parts of the Collateral. However, the rights of the Trustee to exercise significant remedies (such as foreclosure) are, subject to certain exceptions, generally limited to a payment default, bankruptcy of us or the acceleration of the indebtedness.

Proceeds from any sale of the Collateral upon foreclosure may be insufficient to repay the notes in full.

We cannot assure you that the net proceeds from a sale of the Collateral securing the notes would be sufficient to repay all of the notes following a foreclosure upon the Collateral or a liquidation of our assets.

The value of the Collateral and the amount to be received upon a sale of the Collateral will depend upon many factors including, among others, the condition of the Collateral, the ability to sell the Collateral in an orderly sale, the condition of

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the national and local economies, the availability of buyers and similar factors. The book value of the Collateral should not be relied on as a measure of realizable value for these assets. By their nature, portions of the Collateral may be illiquid and may have no readily ascertainable market value. In addition, a significant portion of the Collateral includes assets that may only be usable, and thus retain value, as part of our existing business operations. Accordingly, any sale of the Collateral separate from the sale of our business operations may not be feasible or of significant value.

Additionally, applicable law requires that every aspect of any foreclosure or other disposition of Collateral be “commercially reasonable.” If a court were to determine that any aspect of the Trustee’s exercise of remedies was not commercially reasonable, the ability of the Trustee and the holders of the notes to recover the difference between the amount realized through such exercise of remedies and the amount owed on the notes may be adversely affected and, in the worst case, the holders of the notes could lose all claims for such deficiency amount.

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FORWARD-LOOKING STATEMENTS

This prospectus, including the attached consolidated financial statements, and other presentations made by us contain “forward-looking statements” within the meaning of Section 21E of the Exchange Act and Section 27A of the Securities Act. All statements, other than statements of historical facts, that are included in this prospectus, including the incorporated documents, as well as statements made in presentations, in response to questions or otherwise, that address activities, events or developments that we expect or anticipate to occur in the future, including such matters as projections, capital allocation, future capital expenditures, business strategy, competitive strengths, goals, future acquisitions or dispositions, development or operation of facilities, market and industry developments and the growth of our business and operations (often, but not always, through the use of words or phrases such as “intends,” “plans,” “will likely result,” “are expected to,” “will continue,” “is anticipated,” “estimated,” “should,” “projection,” “target,” “goal,” “objective” and “outlook”), are forward-looking statements. Although we believe that in making any such forward-looking statement our expectations are based on reasonable assumptions, any such forward-looking statement involves uncertainties and is qualified in its entirety by reference to the discussion of risk factors under “Risk Factors” in this prospectus and the discussions under “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this prospectus and the following important factors, among others, that could cause our actual results to differ materially from those projected in such forward-looking statements:

• prevailing governmental policies and regulatory actions, including those of the U.S. Congress, the President of the U.S., the Texas Legislature, the Governor of Texas, the FERC, the PUCT, the NERC, the Texas RE, the U.S. Department of Energy, the EPA, and the TCEQ, with respect to:

• allowed rate of return;

• permitted capital structure;

• industry, market and rate structure;

• recovery of investments;

• acquisition and disposal of assets and facilities;

• operation and construction of assets and facilities;

• changes in tax laws and policies, including the impact of the TCJA and the Coronavirus Aid, Relief, and Economic Security Act; and

• changes in and compliance with environmental, sourcing, reliability and safety laws and policies;

• legal and administrative proceedings and settlements, including the exercise of equitable powers by courts;

• weather conditions and other natural phenomena;

• health epidemics and pandemics, including the evolving COVID-19 pandemic and its impact on Oncor’s business and the economy in general;

• acts of sabotage, wars or terrorist or cyber security threats or activities;

• economic conditions, including the impact of a recessionary environment;

• unanticipated population growth or decline, or changes in market demand and demographic patterns, particularly in the ERCOT region;

• changes in business strategy, development plans or vendor relationships;

• unanticipated changes in interest rates or rates of inflation;

• unanticipated changes in operating expenses, liquidity needs and capital expenditures;

• inability of various counterparties to meet their financial obligations to us, including failure of counterparties to perform under agreements;

• general industry trends;

• hazards customary to the industry and the possibility that we may not have adequate insurance to cover losses resulting from such hazards;

• changes in technology used by and services offered to us;

• significant changes in our relationship with our employees, including the availability of qualified personnel, and the potential adverse effects if labor disputes or grievances were to occur;

• changes in assumptions used to estimate costs of providing employee benefits, including pension and OPEB, and future funding requirements related thereto;

• significant changes in critical accounting policies material to us;

• commercial bank and financial market conditions, access to capital, the cost of such capital, and the results of financing and refinancing efforts, including availability of funds in the capital markets and the potential impact of disruptions in U.S. credit markets;

• circumstances which may contribute to future impairment of goodwill, intangible or other long-lived assets;

• financial restrictions under our Credit Facility, term loan credit agreements, Note Purchase Agreements, and indentures governing our debt instruments;

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• our ability to generate sufficient cash flow to make interest payments on our debt instruments;

• actions by credit rating agencies;

• our ability to effectively execute our operational strategy; and

• the risk that any potential cost savings and any other potential synergies from the InfraREIT Acquisition may not be fully realized or may take longer to realize than expected.

Any forward-looking statement speaks only at the date on which it is made, and, except as may be required by law, we undertake no obligation to update any forward-looking statement to reflect events or circumstances after the date on which it is made or to reflect the occurrence of unanticipated events. New factors emerge from time to time, and it is not possible for us to predict all of them; nor can we assess the impact of each such factor or the extent to which any factor, or combination of factors, may cause results to differ materially from those contained in any forward-looking statement. As such, you should not unduly rely on such forward-looking statements.

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INDUSTRY AND MARKET INFORMATION

The industry and market data and other statistical information used throughout this prospectus are based on independent industry publications, government publications, reports by market research firms or other published independent sources, including certain data published by ERCOT, the independent system operator and the regional coordinator of the various electricity systems within Texas. We did not commission any of these publications or reports. Some data is also based on our good faith estimates, which are derived from our review of internal surveys, as well as the independent sources listed above. Independent industry publications and surveys generally state that they have obtained information from sources believed to be reliable, but do not guarantee the accuracy and completeness of such information. While we believe that each of these studies and publications is reliable, we have not independently verified such data and we make no representation as to the accuracy of such information. Forecasts are particularly likely to be inaccurate, especially over long periods of time, and we do not know what assumptions regarding general economic growth are used in preparing the forecasts included in this prospectus. Similarly, while we believe that our internal and external research is reliable, it has not been verified by any independent sources and we make no assurances that the predictions contained therein are accurate.

USE OF PROCEEDS

We will not receive any cash proceeds from the issuance of the exchange notes pursuant to the exchange offers. In consideration for issuing the exchange notes as contemplated in this prospectus, we will receive in exchange a like principal amount of outstanding notes, the terms of which are identical in all material respects to the exchange notes, except that the exchange notes will not contain terms with respect to transfer restrictions, registration rights and additional interest for failure to observe certain obligations in the registration rights agreement. The outstanding notes surrendered in exchange for the exchange notes will be retired and cancelled and cannot be reissued. Accordingly, the issuance of the exchange notes will not result in any change in our capitalization.

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CONSOLIDATED CAPITALIZATION AND SHORT-TERM DEBT OF ONCOR AND SUBSIDIARIES

The following table summarizes our consolidated capitalization and short-term debt as of March 31, 2020. This table should be read in conjunction with the information included under the headings “Use of Proceeds,” “Selected Financial Data,” “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and the financial statements and related notes included herein.

	At March 31, 2020
	Amount		Percent
	(millions of dollars, except percentages)
Capitalization:
Long-term debt, less amounts due currently (a)	$	9,256		45.9	%
Membership interests		10,904		54.1	%
Total capitalization	$	20,160		100.0	%
Short-term debt:
Short-term debt (b)	$	—
Long-term debt due currently		148
Total short-term debt	$	148

(a) As of March 31, 2020, the amount is reduced by $65 million of unamortized discount and debt issuance costs related to our outstanding long-term debt securities, as of that date.

(b) Excludes $9 million in outstanding letters of credit issued under the Credit Facility.

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SELECTED FINANCIAL DATA

The selected financial data should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations,” our unaudited interim consolidated financial statements and related notes and our audited consolidated financial statements and related notes appearing elsewhere in this prospectus.

	At March 31,			At December 31,
	2020			2019			2018			2017			2016			2015
	(millions of dollars, except ratios)
Total assets	$	27,754		$	27,036		$	22,752		$	22,120		$	20,811		$	19,287
Property, plant & equipment — net		19,816			19,370			16,090			14,879			13,829			13,024
Goodwill		4,740			4,740			4,064			4,064			4,064			4,064
Capitalization:
Long-term debt, less amounts due currently	$	9,256		$	8,017		$	5,835		$	5,567		$	5,515		$	5,646
Membership interests		10,904			10,799			8,460			7,903			7,711			7,508
Total	$	20,160		$	18,816		$	14,295		$	13,470		$	13,226		$	13,154
Capitalization ratios (a):
Long-term debt, less amounts due currently		45.9	%		42.6	%		40.8	%		41.3	%		41.7	%		42.9	%
Membership interests		54.1			57.4			59.2			58.7			58.3			57.1
Total		100.0	%		100.0	%		100.0	%		100.0	%		100.0	%		100.0	%

(a) As of March 31, 2020, the amount is reduced by $65 million of unamortized discount and debt issuance costs related to our outstanding long-term debt securities, as of that date.

(b) For purposes of reporting to the PUCT, the regulatory capitalization ratio at March 31, 2020 and December 31, 2019 was 56.5% debt to 43.5% equity and 54.8% debt to 45.2% equity, respectively. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Short-Term Debt Activity,” Note 7 to Interim Financial Statements and Note 9 to Annual Financial Statements for additional information regarding regulatory capitalization ratios.

	Three Months Ended March 31,			Year Ended December 31,
	2020			2019			2018			2017			2016			2015
	(millions of dollars, except ratios)
Operating revenues	$	1,072		$	4,347		$	4,101		$	3,958		$	3,920		$	3,878
Net income	$	131		$	651		$	545		$	419		$	431		$	432
Capital expenditures	$	628		$	2,097		$	1,767		$	1,631		$	1,352		$	1,154
Embedded interest cost on long-term debt — end of period (a)		4.6	%		4.8	%		5.1	%		5.5	%		5.6	%		5.8	%

(a) Represents the annual interest and amortization of any discounts, premiums, issuance costs (including the effects of interest rate hedges) and any deferred gains/losses on reacquisitions divided by the carrying value of the debt plus or minus the unamortized balance of any discounts, premiums, issuance costs (including the effects of interest rate hedges) and gains/losses on reacquisitions at the end of the year.

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Quarterly Information (unaudited)

Results of operations for the first quarter of 2020 and by quarter for each of the years ended December 31, 2019 and 2018 are summarized below. In our opinion, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of such amounts have been made. Quarterly results are not necessarily indicative of a full year’s operations because of seasonal and other factors. Dollar amounts below are in millions.

2020	First Quarter
Operating revenues	$	1,072
Operating income		242
Net income		131
2019	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Operating revenues	$	1,016	$	1,041	$	1,211	$	1,079
Operating income		216		253		369		236
Net income		116		139		263		133
2018	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Operating revenues	$	990	$	1,021	$	1,095	$	995
Operating income		202		244		293		206
Net income		89		143		194		119

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OUR BUSINESS AND PROPERTIES

Overview of Oncor

We are a regulated electricity transmission and distribution company that provides the essential service of delivering electricity safely, reliably and economically to end-use consumers through our electrical systems, as well as providing transmission grid connections to merchant generation facilities and interconnections to other transmission grids in Texas. We are a direct, majority-owned subsidiary of Oncor Holdings, which is indirectly and wholly owned by Sempra. Oncor Holdings owns 80.25% of our outstanding membership interests and Texas Transmission owns 19.75% of our outstanding membership interests. We are a limited liability company organized under the laws of the State of Delaware, formed in 2007 as the successor entity to Oncor Electric Delivery Company, a corporation formed under the laws of the State of Texas in 2001.

We operate the largest transmission and distribution system in Texas, delivering electricity to more than 3.6 million homes and businesses and operating more than 139,000 miles of transmission and distribution lines at December 31, 2019. We provide:

• transmission services to our electricity distribution business as well as electricity distribution companies, cooperatives and municipalities, and

• distribution services to REPs that sell electricity to retail customers.

Our transmission and distribution rates are regulated by the PUCT and certain cities, and in certain instances, by the FERC. We are not a seller of electricity, nor do we purchase electricity for resale. The company is managed as an integrated business; consequently, there is only one reportable segment.

Our transmission and distribution assets are located principally in the north-central, eastern, western and panhandle regions of Texas. This territory has an estimated population in excess of ten million and comprises over 120 counties and more than 400 incorporated municipalities, including Dallas/Fort Worth and surrounding suburbs, as well as Waco, Wichita Falls, Odessa, Midland, Tyler and Killeen. Most of our power lines have been constructed over lands of others pursuant to easements or along public highways, streets and rights-of-way as permitted by law. At March 31, 2020, we had approximately 4,185 full-time employees, including approximately 755 employees under collective bargaining agreements.

Ring-Fencing Measures

Since 2007, various ring-fencing measures have been taken to enhance our credit quality and the separateness between the Oncor Ring-Fenced Entities and entities with ownership interests in Oncor or Oncor Holdings. These ring-fencing measures serve to mitigate the Oncor Ring-Fenced Entities’ credit exposure to owners of Oncor and Oncor Holdings, and to reduce the risk that the assets and liabilities of Oncor Ring-Fenced Entities would be substantively consolidated with the assets and liabilities of any direct or indirect owners of Oncor and Oncor Holdings in connection with a bankruptcy of any such entities. These measures include the November 2008 sale of 19.75% of Oncor’s equity interests to Texas Transmission.

In March 2018, Sempra indirectly acquired Oncor Holdings pursuant to the Sempra Acquisition. The Sempra Order issued by the PUCT approving the Sempra Acquisition outlines certain ring-fencing measures, governance mechanisms and restrictions that apply after the Sempra Acquisition. As a result of these ring-fencing measures, Sempra does not control Oncor, and the ring-fencing measures limit Sempra’s ability to direct the management, policies and operations of Oncor, including the deployment or disposition of Oncor’s assets, declarations of dividends, strategic planning and other important corporate issues and actions.

None of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or obligations of any Sempra entity or any other direct or indirect owner of Oncor or Oncor Holdings. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of any Sempra entities and any other direct or indirect owner of Oncor or Oncor Holdings. We do not bear any liability for debt or contractual obligations of Sempra and its affiliates or any other direct or indirect owner of Oncor or Oncor Holdings, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from Sempra and its affiliates and any other direct or indirect owner of Oncor or Oncor Holdings.

Oncor is a limited liability company governed by a board of directors, not its members. The Sempra Order and our Limited Liability Company Agreement require that the board of directors of Oncor consist of thirteen members, constituted as follows:

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• seven Disinterested Directors, who (i) shall be independent directors in all material respects under the rules of the New York Stock Exchange in relation to Sempra or its subsidiaries and affiliated entities and any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, and (ii) shall have no material relationship with Sempra or its subsidiaries or affiliated entities or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, currently or within the previous ten years;

• two members designated by Sempra (through Oncor Holdings);

• two members designated by Texas Transmission; and

• two current or former officers of Oncor (the Oncor Officer Directors), currently Robert S. Shapard and E. Allen Nye, Jr., who are our Chairman of the Board and Chief Executive, respectively.

Until March 9, 2028, in order for a current or former officer of Oncor to be eligible to serve as an Oncor Officer Director, the officer cannot have worked for Sempra or any of its affiliates (excluding Oncor Holdings and Oncor) or any other entity with a direct or indirect ownership interest in Oncor or Oncor Holdings in the ten-year period prior to the officer being employed by Oncor. Oncor Holdings, at the direction of STIH, has the right to nominate and/or seek the removal of the Oncor Officer Directors, subject to approval by a majority of the Oncor board of directors. STIH is a wholly owned, indirect subsidiary of, and controlled by, Sempra following the Sempra Acquisition.

In addition, the Sempra Order provides that Oncor’s board cannot be overruled by the board of Sempra or any of its subsidiaries on dividend policy, the issuance of dividends or other distributions (except for contractual tax payments), debt issuance, capital expenditures, operation and maintenance expenditures, management and service fees, and appointment or removal of board members, provided that certain actions may also require the additional approval of the Oncor Holdings board of directors. The Sempra Order also provides that any changes to the size, composition, structure or rights of the board must first be approved by the PUCT. In addition, if Sempra acquires Texas Transmission’s interest in Oncor, the two board positions on Oncor’s board of directors that Texas Transmission is entitled to appoint will be eliminated and the size of Oncor’s board of directors will be reduced by two.

Additional regulatory commitments, governance mechanisms and restrictions provided in the Sempra Order and our Limited Liability Company Agreement to ring-fence Oncor from its owners include, among others:

• A majority of the Disinterested Directors of Oncor must approve any annual or multi-year budget if the aggregate amount of capital expenditures or operating and maintenance expenditures in such budget is more than a 10% increase or decrease from the corresponding amounts of such expenditures in the budget for the preceding fiscal year or multi-year period, as applicable;

• Oncor may not pay any dividends or make any other distributions (except for contractual tax payments) if a majority of its Disinterested Directors determines that it is in the best interests of Oncor to retain such amounts to meet expected future requirements;

• At all times, Oncor will remain in compliance with the debt-to-equity ratio established by the PUCT from time to time for ratemaking purposes, and Oncor will not pay dividends or other distributions (except for contractual tax payments), if that payment would cause its debt-to-equity ratio to exceed the debt-to-equity ratio approved by the PUCT;

• If the credit rating on Oncor’s senior secured debt by any of the three major rating agencies falls below BBB (or the equivalent), Oncor will suspend dividends and other distributions (except for contractual tax payments), unless otherwise allowed by the PUCT;

• Without the prior approval of the PUCT, neither Sempra nor any of its affiliates (excluding Oncor) will incur, guaranty or pledge assets in respect of any indebtedness that is dependent on the revenues of Oncor in more than a proportionate degree than the other revenues of Sempra or on the stock of Oncor, and there will be no debt at STH or STIH at any time following the closing of the Sempra Acquisition;

• Neither Oncor nor Oncor Holdings will lend money to, borrow money from or share credit facilities with Sempra or any of its affiliates (other than Oncor subsidiaries), or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings;

• There must be maintained certain “separateness measures” that reinforce the financial separation of Oncor from its owners, including a requirement that dealings between Oncor, Oncor Holdings and their subsidiaries with Sempra,

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any of Sempra’s other affiliates or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, must be on an arm’s-length basis, limitations on affiliate transactions, separate recordkeeping requirements and a prohibition on Sempra or its affiliates or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings pledging Oncor assets or stock for any entity other than Oncor; and

• Sempra will continue to hold indirectly at least 51% of the ownership interests in Oncor and Oncor Holdings for at least five years following the closing of the Sempra Acquisition, unless otherwise specifically authorized by the PUCT.

Oncor’s Market (ERCOT statistics below were derived from information published by ERCOT)

We operate within the ERCOT market. This market represents approximately 90% of the electricity consumption in Texas. ERCOT is the regional reliability coordinating organization for member electricity systems in Texas and the Independent System Operator (ISO) of the interconnected transmission grid for those systems. ERCOT is responsible for ensuring reliability, adequacy and security of the electric systems, as well as nondiscriminatory access to transmission service by all wholesale market participants in the ERCOT region. ERCOT’s membership consists of corporate and associate members, including electric cooperatives, municipal power agencies, independent generators, independent power marketers, transmission service providers, distribution services providers, independent REPs and consumers.

In 2019, ERCOT’s hourly demand peaked at 74,820 MW as compared to the peak hourly demand of 73,473 MW in 2018. The ERCOT market has limited interconnections to other markets in the U.S. and Mexico, which currently limits potential imports into and exports out of the ERCOT market to 1,106 MW of generation capacity (or approximately 1.5% of peak demand). In addition, wholesale transactions within the ERCOT market are generally not subject to regulation by the FERC.

The ERCOT market operates under reliability standards set by NERC. The PUCT has primary jurisdiction over the ERCOT market to ensure the adequacy and reliability of power supply across Texas’ main interconnected transmission grid. We, along with other owners of transmission and distribution facilities in Texas, assist the ERCOT ISO in its operations. We have planning, design, construction, operation and maintenance responsibility for the portion of the transmission grid and for the load-serving substations we own, primarily within our certificated distribution service area. We participate with the ERCOT ISO and other ERCOT utilities in obtaining regulatory approvals and planning, designing, constructing and upgrading transmission lines in order to remove existing constraints and interconnect generation on the ERCOT transmission grid. The transmission line projects are necessary to meet reliability needs, support energy production and increase bulk power transfer capability.

Oncor’s Strategies

We focus on delivering electricity in a safe and reliable manner, minimizing service interruptions and investing in our transmission and distribution infrastructure to maintain our system, serve our growing customer base with a modernized grid and support energy production.

We believe that building and leveraging upon opportunities to scale our operating advantage and technology programs enables us to create value by eliminating duplicative costs, efficiently managing supply costs, and building and standardizing distinctive process expertise over a larger grid. Scale also allows us to take part in large capital investments in our transmission and distribution system, with a smaller fraction of overall capital at risk and with an enhanced ability to streamline costs. Our organic growth strategies are to invest in technology upgrades and to construct transmission and distribution facilities to meet the needs of our customers, the state of Texas, and the ERCOT market. We regularly evaluate opportunities to make selective strategic acquisitions involving regulated assets. We and other transmission and distribution businesses in ERCOT benefit from regulatory capital recovery mechanisms known as “capital trackers” that we believe enable adequate and more timely recovery of transmission and distribution investments through our regulated rates.

Oncor’s Operations

Performance Indicators — We achieved or exceeded market performance protocols in 12 out of 14 PUCT market metrics in 2019. These metrics measure the success of transmission and distribution companies in facilitating customer transactions in the competitive Texas electricity market.

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Investing in Infrastructure and Technology — In 2019, we invested approximately $2.1 billion in our network to upgrade the transmission system and associated facilities, to extend the distribution infrastructure and to pursue certain initiatives in infrastructure maintenance and information technology.

Electricity Transmission — Our electricity transmission business is responsible for the safe and reliable operations of our transmission network and substations. These responsibilities consist of the construction and maintenance of transmission facilities and substations and the monitoring, controlling and dispatching of high-voltage electricity over our transmission facilities in coordination with ERCOT.

We are a member of ERCOT, and our transmission business actively assists the operations of ERCOT and market participants. Through our transmission business, we participate with ERCOT and other member utilities to plan, design, construct and operate new transmission lines, with regulatory approval, necessary to maintain reliability, interconnect to merchant generation facilities, increase bulk power transfer capability and minimize limitations and constraints on the ERCOT transmission grid.

Transmission revenues are provided under tariffs approved by either the PUCT or, to a small degree related to limited interconnections to other markets, the FERC. Network transmission revenues compensate us for delivery of electricity over transmission facilities operating at 60kV and above. Other services we offer through our transmission business include system impact studies, facilities studies, transformation service and maintenance of transformer equipment, substations and transmission lines owned by other parties.

PURA allows us to update our transmission rates periodically on an interim basis to reflect changes in invested capital. This “capital tracker” provision encourages investment in the transmission system to help ensure reliability and efficiency by allowing for timely recovery of and return on new transmission investments.

At December 31, 2019, our transmission system included:

• 17,799 miles of transmission lines:

• 7,163 circuit miles of 345kV transmission lines,

• 10,636 circuit miles of 138kV and 69kV transmission lines,

• service to 100 generation facilities totaling 40,687 MW directly connected to our transmission system; and

• service to 349 transmission stations and 775 distribution substations from our transmission system.

At December 31, 2019, our transmission facilities had the following connections to other transmission grids in Texas:

	Number of Interconnected Lines
Grid Connections	345kV		138kV		69kV
Brazos Electric Power Cooperative, Inc.		8		117		30
Rayburn Country Electric Cooperative, Inc.		1		41		6
Lower Colorado River Authority		9		29		2
Texas New Mexico Power		4		16		13
Tex-La Electric Cooperative of Texas, Inc.		—		13		1
American Electric Power Company, Inc. (a)		4		8		12
Texas Municipal Power Agency		7		6		—
Lone Star Transmission		12		—		—
CenterPoint Energy Inc.		8		—		—
Other small systems operating wholly within Texas		8		16		3

(a) One of the 345kV lines is an asynchronous high-voltage direct current connection with the Southwest Power Pool.

Electricity Distribution — Our electricity distribution business is responsible for the overall safe and efficient operation of distribution facilities, including electricity delivery, power quality and system reliability. These responsibilities consist of the ownership, management, construction, maintenance and operation of the distribution system within our certificated service area. Our distribution system receives electricity from the transmission system through substations and distributes electricity to end-users and wholesale customers through 3,594 distribution feeders.

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At December 31, 2019, our distribution system included:

• 121,747 miles of distribution lines:

• 94,805 miles of overhead lines, and

• 26,942 miles of underground lines,

• 3.685 million points of delivery at December 31, 2019,

• 64,000 approximate number of points of delivery added in 2019, and

• 2.09% average growth per year over the past five years in the number of distribution system points of delivery we serve, excluding lighting sites.

Electricity points of delivery at March 31, 2020 totaled 3.7 million based on the number of active meters.

Distribution revenues from residential and small business users are based on actual monthly consumption (kWh), and, depending on size and annual load factor, revenues from large commercial and industrial users are based either on actual monthly demand (kilowatts) or the greater of actual monthly demand (kilowatts) or 80% of peak monthly demand during the prior eleven months.

The PUCT allows utilities to file DCRF applications, under certain circumstances, once per year to recover distribution-related investments on an interim basis.

Customers — Our transmission customers consist of municipalities, electric cooperatives and other distribution companies. Our distribution customers consist of approximately 90 REPs and certain electric cooperatives in our certificated service area. Revenues from REP subsidiaries of Vistra and NRG Energy, Inc. collectively represented 23% and 18% of our total operating revenues in 2019, respectively, and 25% and 18% of our total operating revenues for the three months ended March 31, 2020, respectively. No other customer represented more than 10% of our total operating revenues. The consumers of the electricity we deliver are free to choose their electricity supplier from REPs who compete for their business.

Competition — Oncor operates in certificated areas designated by the PUCT. The majority of Oncor’s service territory is single certificated, with Oncor as the only certificated transmission and distribution provider. However, in multi-certificated areas of Texas, Oncor competes with certain utilities and rural electric cooperatives for the right to serve end-use customers.

Seasonality — Our revenues and results of operations are subject to seasonality, weather conditions and other electricity usage drivers, with revenues being highest in the summer.

Regulation and Rates — As our operations are wholly within Texas, we believe we are not a public utility as defined in the Federal Power Act and, as a result, we are not subject to general regulation under this act. However, we are subject to reliability standards adopted and enforced by the Texas RE and the NERC (including critical infrastructure protection) under the Federal Power Act. See “Risk Factors – We are subject to mandatory service quality and reliability standards. Efforts to comply with those standards could subject us to higher operating costs and/or increased capital expenditures, and non-compliance with applicable standards could subject us to penalties that could have a material effect on our business.”

The PUCT has original jurisdiction over transmission and distribution rates and services in unincorporated areas and in those municipalities that have ceded original jurisdiction to the PUCT and has exclusive appellate jurisdiction to review the rate and service orders and ordinances of municipalities. Generally, PURA prohibits the collection of any rates or charges by a public utility (as defined by PURA) that does not have the prior approval of the appropriate regulatory authority (i.e., the PUCT or the municipality with original jurisdiction).

At the state level, PURA requires owners or operators of transmission facilities to provide open-access wholesale transmission services to third parties at rates and terms that are nondiscriminatory and comparable to the rates and terms of the utility’s own use of its system. The PUCT has adopted rules implementing the state open-access requirements for all utilities that are subject to the PUCT’s jurisdiction over transmission services, including us.

Environmental Regulations and Related Considerations — The TCEQ and the EPA have jurisdiction over water discharges (including storm water) from facilities in Texas. We believe our facilities are presently in material compliance with applicable state and federal requirements relating to discharge of pollutants into the water. We believe we hold all required waste water discharge permits from the TCEQ for facilities in operation and have applied for or obtained necessary permits for facilities under construction. We also believe we can satisfy the requirements necessary to obtain any required permits or renewals. There are also federal rules pertaining to Spill Prevention, Control and Countermeasure (SPCC) plans

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for oil-filled electrical equipment and bulk storage facilities for oil that affect certain of our facilities. We have implemented SPCC plans as required for those substations, work centers and distribution systems, and believe we are currently in material compliance with these rules.

Treatment, storage and disposal of solid waste and hazardous waste are regulated at the state level under the Texas Solid Waste Disposal Act and at the federal level under the Resource Conservation and Recovery Act of 1976, as amended, and the Toxic Substances Control Act. The EPA has issued regulations under the Resource Conservation and Recovery Act of 1976 and the Toxic Substances Control Act, and the TCEQ has issued regulations under the Texas Solid Waste Disposal Act applicable to our facilities. We are in material compliance with applicable solid and hazardous waste regulations.

Our capital expenditures for environmental matters totaled $37 million in 2019 and are expected to total approximately $51 million in 2020.

2017 Rate Review — We filed a rate review in PUCT Docket No. 46957 in March 2017, and the PUCT issued an order in that docket that took effect on November 27, 2017. Incorporating the new corporate federal income tax rate in our approved rate settlement agreement reduced our annual revenues and our tax expense by approximately $125 million. Other significant findings include a change in our authorized return on equity to 9.8% and a change in our authorized regulatory capital structure to 57.5% debt to 42.5% equity. Our previous authorized return on equity was 10.25% with an authorized regulatory capital structure of 60% debt to 40% equity. See Note 3 to Annual Financial Statements for more information on the PUCT order.

Sharyland 2017 Asset Exchange — In July 2017, we entered into the Sharyland 2017 Agreement with the Sharyland Entities. Pursuant to that agreement, on November 9, 2017, we exchanged approximately $383 million of our transmission assets, consisting of 517 circuit miles of 345kV transmission lines, and approximately $25 million in cash for approximately $408 million of the Sharyland Entities’ distribution assets (constituting substantially all of their electricity distribution business) and certain of their transmission assets. The transaction expanded our customer base in west Texas and provides some potential growth opportunities for the distribution network. The exchange of assets between Oncor and the Sharyland Entities was structured to qualify, in part, as a simultaneous tax deferred like kind exchange of assets to the extent that the assets exchanged are of “like kind” (within the meaning of Section 1031 of the Code). The Sharyland 2017 Asset Exchange did not have a material effect on our results of operations, financial position or cash flows. See further discussion of the transaction in Note 2 to Annual Financial Statements.

InfraREIT Acquisition

InfraREIT Mergers

On May 16, 2019, we completed our acquisition of InfraREIT and InfraREIT Partners pursuant to the InfraREIT Merger Agreement. Pursuant to the InfraREIT Merger Agreement, (i) InfraREIT merged with and into a wholly owned subsidiary of Oncor, with the Oncor subsidiary continuing as the surviving company, and (ii) a wholly owned subsidiary of Oncor merged with and into InfraREIT Partners (renamed Oncor NTU Partnership LP), with InfraREIT Partners continuing as the surviving entity (together, the Mergers).

In connection with the Mergers, (i) each share of common stock, par value $0.01 per share, of InfraREIT issued and outstanding was converted into the right to receive $21.00 per share in cash from us and (ii) each limited partnership unit of InfraREIT Partners issued and outstanding was converted into the right to receive $21.00 per unit in cash from us (except units held, directly or indirectly, by Oncor or its subsidiaries, which remain outstanding).

In connection with our entrance into the InfraREIT Merger Agreement, we received an equity commitment letter from Sempra and certain indirect equity holders of Texas Transmission (the Equity Commitment Parties). Pursuant to the equity commitment letter, the Equity Commitment Parties provided their pro rata share of capital contributions to us in an aggregate principal amount of $1,330 million to fund the cash consideration payable in the Mergers and the payment of related fees and expenses. Total purchase price (including cash consideration and transaction costs incurred by InfraREIT and paid by Oncor) paid by us in connection with the Mergers totaled approximately $1,324 million (including approximately $1,275 million representing the cash consideration, a $40 million management termination fee InfraREIT agreed to pay Hunt Consolidated, Inc. at closing and certain other transaction costs incurred by InfraREIT and its subsidiaries and paid by us on their behalf), and we funded such amounts with the capital contributions received from the Equity Commitment Parties and proceeds received through the issuance of CP Notes.

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In connection with the Mergers, we also extinguished all of InfraREIT’s outstanding debt (which was owed by certain of InfraREIT’s subsidiaries) totaling an aggregate principal amount of approximately $953 million as of May 16, 2019. We repaid $602 million principal amount of InfraREIT’s outstanding debt using proceeds from borrowings under a short-term unsecured term loan credit agreement that we entered into on May 9, 2019 (Bridge Loan), which Bridge Loan was subsequently repaid, and the issuance of CP Notes. We also exchanged $351 million of InfraREIT’s outstanding debt for senior secured notes issued by us. As a result of these repayments and exchanges, all debt owed by InfraREIT’s subsidiaries was extinguished in connection with the closing of the Mergers.

The assets we acquired through the acquisition of InfraREIT’s subsidiaries included approximately 1,575 miles of transmission lines, including approximately 1,235 circuit miles of 345kV transmission lines and approximately 340 circuit miles of 138kV transmission lines. The central, north and west Texas transmission system we acquired in the transaction is directly connected to approximately 20 operational generation facilities totaling approximately 3,900 MW and serves over 50 transmission stations and substations.

The InfraREIT Acquisition expanded Oncor’s existing footprint in Texas by adding various electricity transmission and distribution assets and projects in the north, central, west and panhandle regions of Texas. Oncor is currently involved in an estimated $400 million joint project with LP&L, with costs to ultimately be split by Oncor and LP&L that involves the build out of transmission lines and associated station work to join the City of Lubbock to the ERCOT market. Oncor’s expenditures as of March 31, 2020 with respect to the project (minus amounts subject to reimbursement by LP&L) totaled $17 million. To support its funding of reimbursements to Oncor, LP&L is required to maintain an escrow account with minimum monthly balances. The balance of the escrow account at March 31, 2020 was $10 million. Each of Oncor and LP&L is expected to make total expenditures of approximately $143 million and $111 million, respectively, in 2020, with the remainder of the estimated $400 million in costs to be incurred in 2021. This joint project consists of approximately 175 miles of transmission lines in the Lubbock and surrounding Texas panhandle areas.

Asset Exchange

On May 16, 2019, immediately prior to the Mergers, the SDTS-SU Asset Exchange was completed. Additionally, immediately prior to the closing of the SDTS-SU Asset Exchange, the equity interests and related economic interests in SDTS held by SU were cancelled. SDTS became our wholly owned, indirect subsidiary in connection with the SDTS-SU Asset Exchange and the Mergers and was renamed “Oncor Electric Delivery Company NTU LLC”.

In connection with the SDTS-SU Asset Exchange, pursuant to the joint survivor merger of SU and SDTS, (i) SDTS assumed certain real property and other assets owned by SU and used in the electric transmission and distribution business in the central, north and west and panhandle regions of Texas, as well as equity interests in GS Project Entity, L.L.C., a Texas limited liability company, that was merged with and into SDTS and (ii) SU assumed certain real property and other assets owned by SDTS and used in the electric transmission and distribution business in the vicinity of the Texas-Mexico border, including certain real property and other assets that SDTS owned and leased to SU.

The SDTS-SU Asset Exchange was structured to qualify, in part, as a simultaneous tax deferred like kind exchange of assets to the extent that the assets exchanged are of “like kind” (within the meaning of Section 1031 of the Code). SDTS paid approximately $13.18 million to SU at closing to settle the difference between the sums of the estimated net book value of the assets and liabilities exchanged and the estimated net working capital amounts associated with the SDTS-SU Asset Exchange. In August 2019, SU paid $8 million to NTU pursuant to the SDTS-SU Asset Exchange agreement as a post-closing true-up to settle the difference between the final net book value of the assets and liabilities exchanged and the final net working capital amounts associated with the SDTS-SU Asset Exchange.

In addition, as a condition to the closing of the SDTS-SU Asset Exchange, the Sempra-Sharyland Transaction was completed. As a result of the Sempra-Sharyland Transaction, Sharyland is now our affiliate for purposes of PUCT rules. Pursuant to the agreement governing the SDTS-SU Asset Exchange and the PUCT order in Docket No. 48929 approving the InfraREIT Acquisition, upon closing of the InfraREIT Acquisition we entered into an operation agreement pursuant to which we will provide certain operations services to Sharyland at cost with no markup or profit. We provided approximately $300,000 in services to Sharyland in 2019 pursuant to this agreement.

EFH Bankruptcy Proceedings and Sempra Acquisition

In April 2014, EFH Corp. (at the time the indirect owner of 80.03% of Oncor’s outstanding equity) and the substantial majority of its direct and indirect subsidiaries at the time commenced proceedings under Chapter 11 of the U.S. Bankruptcy

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Code. The Oncor Ring-Fenced Entities were not parties to the EFH Bankruptcy Proceedings. On March 9, 2018, pursuant to the Sempra Acquisition, EFH Corp. merged with an indirect subsidiary of Sempra, with EFH Corp. (renamed STH) continuing as the surviving company and an indirect, wholly owned subsidiary of Sempra. Sempra paid cash consideration of approximately $9.45 billion to acquire the indirect 80.03% outstanding membership interest in Oncor held by Oncor Holdings and other EFH Corp. assets and liabilities unrelated to Oncor. In addition, in a separate transaction, Oncor Holdings acquired 0.22% of the outstanding membership interests in Oncor from Investment LLC for $26 million in cash, which represents approximately $18.60 per membership interest. As a result, after the Sempra Acquisition, Oncor Holdings owns 80.25% of our outstanding membership interests and Texas Transmission owns 19.75% of our outstanding membership interests. In February 2020, Sempra acquired (through STIH) an indirect 1% ownership interest in Texas Transmission.

The Sempra Acquisition was consummated after obtaining the approval of the bankruptcy court in the EFH Bankruptcy Proceedings, the Federal Communications Commission and the PUCT. The Sempra Order issued by the PUCT and our Limited Liability Company Agreement outline certain ring-fencing measures, governance mechanisms and restrictions that apply after the Sempra Acquisition. As a result of these ring-fencing measures, Sempra does not control Oncor, and the ring-fencing measures limit Sempra’s ability to direct the management, policies and operations of Oncor, including the deployment or disposition of Oncor’s assets, declarations of dividends, strategic planning and other important corporate issues and actions. These limitations include limited representation on the board of directors of Oncor. For more information on the ring-fencing measures applicable after the Sempra Acquisition, see “– Ring-Fencing Measures” above.

The Sempra Order also contains certain operational and financial commitments, including that Oncor will make minimum capital expenditures equal to at least $7.5 billion over the period from January 1, 2018 until December 31, 2022 (subject to certain adjustments). Our capital expenditures totaled $2.1 billion and $1.8 billion in 2019 and 2018, respectively. For a discussion of our projected capital expenditures for the five year period 2020 through 2024, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Financial Condition – Liquidity and Capital Resources – Available Liquidity/CP Program/Credit Facility/Short-Term Borrowings – Liquidity Needs, Including Capital Expenditures.”

LEGAL 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 on our financial position, results of operations or cash flows. See Notes 2 and 6 to Interim Financial Statements and Notes 3 and 8 to Annual Financial Statements for additional information concerning our legal and regulatory proceedings.

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF

FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following discussion and analysis of our financial condition and results of operations for the three months ended March 31, 2020 and 2019 and the fiscal years ended December 31, 2019 and 2018 should be read in conjunction with Selected Financial Data and the Annual Financial Statements and Interim Financial Statements.

Our Annual Report on Form 10-K for the year ended December 31, 2018 includes a discussion and analysis of our financial condition and results of operations for the year ended December 31, 2017 in Item 7 of Part II, “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

All dollar amounts in the tables in the following discussion and analysis are stated in millions of U.S. dollars unless otherwise indicated.

BUSINESS

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, western and panhandle regions of Texas. We are a direct, majority-owned subsidiary of Oncor Holdings, which is indirectly and wholly owned by Sempra. Oncor Holdings owns 80.25% of our outstanding membership interests and Texas Transmission owns 19.75% of our outstanding membership interests. We are managed as an integrated business; consequently, there is only one reportable segment.

Our condensed consolidated financial statements for the three months ended March 31, 2020, include the results of our wholly owned indirect subsidiary, NTU, which is a regulated utility that provides electricity transmission delivery service in the north-central, western and panhandle regions of Texas. We acquired NTU as part of the InfraREIT Acquisition that closed on May 16, 2019.

Ring-Fencing Measures

Various ring-fencing measures have been taken to enhance our credit quality and the separateness between the Oncor Ring-Fenced Entities, Sempra and its affiliates (other than the Oncor Ring-Fenced Entities), and any other entities with a direct or indirect ownership interest in Oncor or Oncor Holdings. These measures serve to mitigate the Oncor Ring-Fenced Entities’ credit exposure to Sempra and its affiliates and any other direct or indirect owners of Oncor and Oncor Holdings, and to reduce the risk that the assets and liabilities of Oncor Ring-Fenced Entities would be substantively consolidated with the assets and liabilities of any Sempra entity or any other direct or indirect owners of Oncor and Oncor Holdings in connection with a bankruptcy of any such entities. Such measures include, among other things: the 19.75% equity interest held by Texas Transmission; maintenance of separate books and records for the Oncor Ring-Fenced Entities; and our board of directors being comprised of a majority of Disinterested Directors. As a result, none of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or obligations of any Sempra entity or any other direct or indirect owner of Oncor or Oncor Holdings. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of any Sempra entities and any other direct or indirect owner of Oncor or Oncor Holdings. We do not bear any liability for debt or contractual obligations of Sempra and its affiliates or any other direct or indirect owner of Oncor or Oncor Holdings, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from Sempra and its affiliates and any other direct or indirect owner of Oncor or Oncor Holdings. For more information on the ring-fencing measures, see “Ring-Fencing Measures” and Note 1 to Interim Financial Statements.

Significant Activities and Events

COVID-19 Pandemic — As a result of the COVID-19 pandemic, beginning in March 2020, various orders were issued at the state and local levels in our service territory declaring a state of disaster relating to the pandemic and requiring individuals to stay at their place of residence except as needed for certain essential matters, including matters related to critical infrastructure. As a critical infrastructure provider of electricity transmission and distribution services, our operations have continued throughout the pandemic. We have implemented our pandemic response plan and taken various precautionary and preemptive actions under that plan to protect our workforce and critical operations.

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To date, the COVID-19 pandemic has not had a material adverse impact on our business, financial condition, or results of operations. However, we do face risks and uncertainties related to COVID-19 and cannot predict whether, or to what extent, the pandemic will have a material adverse impact on our business, financial condition, or results of operations in the future. For a discussion of risks and uncertainties related to COVID-19, including the potential impacts on our business, financial condition and results of operations, see “Risk Factors.” In light of the global economic uncertainty relating to the COVID-19 pandemic, we also took various steps in March 2020 to increase our liquidity, as discussed below in “— Debt-Related Activities” and “Financial Condition — Liquidity and Capital Resources — Available Liquidity and Liquidity Needs, Including Capital Expenditures.”

On March 26, 2020, the PUCT issued an order in PUCT Project No. 50664 Issues Related to the State of Disaster for the Coronavirus Disease 2019 creating the COVID-19 Electricity Relief Program (COVID-19 ERP) to aid certain residential customers unable to pay their electricity bills as a result of the impact of COVID-19. To fund that program, the PUCT order also provided for a surcharge to be collected by transmission and distribution utilities through rates and directed ERCOT to provide an aggregate amount of $15 million in interest-free loans to those transmission and distribution utilities for the initial funding of the COVID-19 ERP. As a result, we filed a tariff rider on April 1, 2020 implementing the surcharge and received an unsecured loan from ERCOT on April 9, 2020 in the amount of $7 million. Pursuant to an order issued April 17, 2020, the COVID-19 ERP will expire July 17, 2020 unless extended by the PUCT. The PUCT also authorized the transmission and distribution utilities to create regulatory assets with respect to the COVID-19 ERP and other costs resulting from the effects of COVID-19. Therefore, we are recording incremental costs incurred by us resulting from the effects of COVID-19, including costs relating to the implementation of our pandemic response plan, as a regulatory asset. There can be no assurance, however, that the rate surcharge and ERCOT loan will provide sufficient funds to cover all of our costs relating to the COVID-19 ERP, or that all amounts in the regulatory assets we have established with respect to COVID-19 costs will be judged reasonable and necessary by the PUCT in our next rate review, which is required to be filed on or before October 1, 2021. For more information on PUCT Project No. 50664 and COVID-19-related regulatory matters, see Note 2 to Interim Financial Statements.

Debt-Related Activities — In March 2020, we completed a sale of $400 million aggregate principal amount of the outstanding 2030 notes and $400 million aggregate principal amount of the outstanding 2050 notes. In the three months ended March 31, 2020, we also entered into two term loan credit agreements consisting of the $450 million term loan credit agreement entered into on January 28, 2020 (January 2020 Term Loan Agreement) and the $350 million March 2020 Term Loan Agreement. As of March 31, 2020, $450 million of principal amount was outstanding under the January 2020 Term Loan Agreement and no principal amount was outstanding under the March 2020 Term Loan Agreement. Repayments of long-term debt in the three months ended March 31, 2020 included repayment of $460 million principal amount borrowed under a term loan agreement entered into in 2019 that was to mature in October 2020 (2019 Term Loan Agreement) and $2 million principal amount of the quarterly amortizing debt for senior secured notes issued under one of our Note Purchase Agreements. The $460 million repaid under the 2019 Term Loan Agreement constituted all amounts outstanding under that agreement, and as a result of that repayment the 2019 Term Loan Agreement is no longer in effect.

Joint Project with LP&L — Oncor is currently involved in an estimated $400 million joint project with LP&L, with costs to ultimately be split by Oncor and LP&L that involves the build out of transmission lines and associated station work to join the City of Lubbock to the ERCOT market. Oncor’s expenditures as of March 31, 2020 with respect to the project (minus amounts subject to reimbursement by LP&L) totaled $17 million. To support its funding of reimbursements to Oncor, LP&L is required to maintain an escrow account with minimum monthly balances. The balance of the escrow account at March 31, 2020 was $10 million. Each of Oncor and LP&L is expected to make total expenditures of approximately $143 million and $111 million, respectively, in 2020, with the remainder of the estimated $400 million in costs to be incurred in 2021. This joint project consists of approximately 175 miles of transmission lines in the Lubbock and surrounding Texas panhandle areas.

InfraREIT Acquisition — On May 16, 2019, we completed the InfraREIT Acquisition, pursuant to which we acquired all of the equity interests of InfraREIT and its subsidiary, InfraREIT Partners. The cash consideration paid to stockholders of InfraREIT and limited partners of InfraREIT Partners totaled $1,275 million. In addition, we paid certain transaction costs incurred by InfraREIT (including a management agreement termination fee of $40 million that InfraREIT paid an affiliate of Hunt Consolidated, Inc. at closing), with the aggregate cash consideration and payment of certain InfraREIT expenses totaling $1,324 million. In connection with and immediately after the closing of the InfraREIT Acquisition, on May 16, 2019, we also extinguished all $953 million aggregate principal amount of the outstanding debt of InfraREIT and its subsidiaries through repayment of $602 million of InfraREIT subsidiary debt and the exchange of $351 million of InfraREIT subsidiary debt for newly issued Oncor senior secured notes. See Notes 2, 6 and 7 to Annual Financial Statements for more information on the exchange of notes and repayment of debt of InfraREIT and its subsidiaries. The InfraREIT Acquisition expanded Oncor’s existing footprint in Texas by adding various electricity transmission and distribution assets and projects in the north, central, west and panhandle regions of Texas, including the joint project with LP&L.

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Matters with the PUCT — See discussion under “Regulation and Rates - Matters with the PUCT.”

KEY RISKS AND CHALLENGES

Following is a discussion of key risks and challenges facing management and the initiatives currently underway to manage such challenges. For additional information concerning risk factors related to our business, see “Risk Factors” in this prospectus.

Rates and Cost Recovery

Our rates are regulated by the PUCT and certain cities and are subject to regulatory rate-setting processes and annual earnings oversight. This regulatory treatment does not provide any assurance as to achievement of earnings levels. Our rates are regulated based on an analysis of our costs and capital structure, as reviewed and approved in a regulatory proceeding. Rate regulation is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital. However, there is no assurance that the PUCT will judge all of our costs to have been prudently incurred, that the PUCT will not reduce the amount of invested capital included in the capital structure that our rates are based upon, that the regulatory process in which rates are determined will always result in rates that produce full recovery of our costs or that our authorized return on equity will not be reduced. See “Regulation and Rates” below for further information.

Capital Availability and Cost

Our access to capital markets and cost of debt could be directly affected by our credit ratings. Any adverse action with respect to our credit ratings could generally cause borrowing costs to increase and the potential pool of investors and funding sources to decrease. Our credit ratings are currently higher than those of Sempra. If credit rating agencies were to change their views of our independence from Sempra and its affiliates (other than the Oncor Ring-Fenced Entities), our credit ratings could decline. We believe this risk is substantially mitigated by the ring-fencing measures as described in Notes 1 and 2 to Annual Financial Statements. See “Risk Factors—Adverse actions with respect to our credit ratings could negatively affect our ability to access capital,” and “In the future, we could have liquidity needs that could be difficult to satisfy under some circumstances, especially in uncertain financial market conditions.”

Technology Risks

Technology risks include the risk of interrupted and/or degraded business operations due to the loss of key technology platforms. Risks to our key technology platforms include nonperformance by equipment and service providers, failure of the technology to meet performance expectations and inadequate cost recovery allowances by regulatory authorities. We continue to implement measures to mitigate these risks, including business continuity and disaster recovery plans, but there can be no assurance that these measures will achieve the operational and financial objectives.

Cyber Security and Infrastructure Protection Risk

A breach of our cyber/data or physical security measures that impairs our information technology infrastructure or transmission and distribution infrastructure could disrupt normal business operations, affect our ability to control our transmission and distribution system, expose us to material regulatory claims and limit communication with third parties. Any loss of confidential or proprietary data through a cyber/data breach, including a breach involving one of our third-party vendors, could also materially affect our reputation, expose the company to legal claims and fines or impair our ability to execute on business strategies. If third parties in our supply chain experience cyber attacks, the services they provide us could be disrupted. This disruption could interfere with our ability to perform our obligations to others, which could negatively affect our financial condition and reputation. In addition, the theft, damage, or improper disclosure of sensitive data held by these third parties may subject us to further harm. We participate in industry groups and with regulators to remain current on emerging threats and mitigating techniques. While we have not experienced any security breach with a significant operational, reputational or financial impact, we recognize the growing threat within our industry and are proactively taking steps to continuously improve our technology, security measures, processes and services to detect, mitigate and protect our assets, both physical and cyber.

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APPLICATION OF CRITICAL ACCOUNTING POLICIES

Our significant accounting policies are discussed in Note 1 to Annual Financial Statements. We prepare our financial statements in accordance with GAAP governing rate-regulated operations. Application of these accounting policies in the preparation of our consolidated 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 revenues and expenses during the periods covered. The following is a summary of certain critical accounting policies that are impacted by judgments and uncertainties and under which different amounts might be reported using different assumptions or estimation methodologies.

Accounting for the Effects of Income Taxes

Our tax sharing agreement with Oncor Holdings, STH (as successor to EFH Corp.) and Texas Transmission provides for the calculation of amounts related to income taxes for each of Oncor Holdings and Oncor substantially as if these entities were taxed as corporations and requires payments to the members determined on that basis (without duplication for any income taxes paid by a subsidiary of Oncor Holdings).

We are a partnership for U.S. federal income tax purposes. Accordingly, while partnerships are not subject to income taxes, in consideration of the presentation of our financial statements as an entity subject to cost-based regulatory rate-setting processes with such costs historically including income taxes and the tax sharing agreement, the financial statements present amounts determined under the tax sharing agreement as “provision in lieu of income taxes” and “liability in lieu of deferred income taxes”. Such amounts are determined in accordance with the provisions of the accounting guidance for income taxes and accounting standards that provide interpretive guidance for accounting for uncertain tax positions and thus differences between the book and tax bases of assets and liabilities are accounted for as if we were a stand-alone corporation. In the 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.

Our expense amounts related to income taxes and related balance sheet amounts are recorded pursuant to our tax sharing agreement, as discussed above. Recording of such amounts involves significant management estimates and judgments, including judgments and estimates of the timing and probability of recognition of income and deductions by taxing authorities. In assessing the likelihood of realization of assets related to income taxes, management considers estimates of the amount and character of future taxable income. Actual amounts related to income taxes could vary from estimated amounts due to the future impacts of various items, including changes in income tax laws, our forecasted financial condition and results of operations in future periods, as well as final review of filed tax returns by taxing authorities. Our and STH’s income tax returns are regularly subject to examination by applicable tax authorities. In management’s opinion, any liability recorded pursuant to income tax accounting guidance related to uncertain tax positions reflects future amounts that may be owed as a result of any examination.

Amounts payable to and receivable from members related to income taxes on our balance sheet reflect our tax provision net of quarterly estimated tax payments required by the tax sharing agreement that are trued up the following year when the annual tax return is filed.

See Notes 1 and 5 to Annual Financial Statements for additional information.

Regulatory Assets and Liabilities

We are subject to rate regulation and our financial statements reflect regulatory assets and liabilities in accordance with GAAP related to the effect of certain types of regulation. Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process based on PURA and/or the PUCT’s orders, precedents or substantive rules. Rate regulation is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital subject to PUCT review for reasonableness and prudence and possible disallowance. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital and the timing and amount of assets to be recovered by rates. See Note 2 to Interim Financial Statements and Note 3 to Annual Financial Statements for more information regarding regulatory assets and liabilities.

Impairment of Long-Lived Assets and Goodwill

We evaluate long-lived assets (including intangible assets with finite lives) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

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We also evaluate goodwill for impairment annually on October 1 and whenever events or changes in circumstances indicate that an impairment may exist. The determination of the existence of these and other indications of impairment involves judgments that are subjective in nature and may require the use of estimates in forecasting future results and cash flows.

If at the assessment date our carrying value exceeds our estimated fair value (enterprise value), then the estimated enterprise value is compared to the estimated fair values of our operating assets (including identifiable intangible assets) and liabilities at the assessment date. The resultant implied goodwill amount is compared to the recorded goodwill amount. Any excess of the recorded goodwill amount over the implied goodwill amount is written off as an impairment charge.

In each of 2019, 2018 and 2017, we concluded, based on a qualitative assessment, that our estimated enterprise fair value was more likely than not greater than our carrying value. As a result, no additional testing for impairment was required and no impairments were recognized.

Defined Benefit Pension Plans and OPEB Plans

We offer certain pension, health care and life insurance benefits to eligible employees (and certain eligible former employees of EFH Corp. and Vistra whose service was partially assigned to Oncor in connection with the deregulation and disaggregation of EFH Corp.’s electric utility business in 2002) and their eligible dependents upon the retirement of such employees as we discuss in Note 10 to Annual Financial Statements. We are authorized to establish a regulatory asset or liability for the difference between the amounts of pension and OPEB costs reflected in our PUCT-approved billing rates and the actual amounts that would otherwise have been recorded as charges or credits to earnings related to recoverable service. Accordingly, we recognize (principally as a regulatory asset or property) additional pension and OPEB costs consistent with PURA. Amounts deferred are ultimately subject to regulatory approval.

Benefit costs are impacted by actual and actuarial estimates of employee demographics (including but not limited to age, compensation levels and years of accredited service), future health care costs, the level of contributions made to retiree plans, expected and actual earnings on plan assets and the discount rates used in determining the projected benefit obligation. Actuarial assumptions are reviewed and updated annually based on current economic conditions and trends. Changes made to the provisions of the plans may also impact current and future benefit costs. Fluctuations in actual equity market returns as well as changes in general interest rates may result in increased or decreased benefit costs in future periods.

In accordance with accounting rules, changes in benefit obligations associated with factors discussed above may be immediately recognized as a regulatory asset if related to recoverable service or in other comprehensive income and reclassified as a current cost in future years. As such, significant portions of benefit costs recorded in any period may not reflect the actual level of cash benefits provided to plan participants.

See Note 10 to Annual Financial Statements regarding other disclosures related to pension and OPEB plans obligations.

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RESULTS OF OPERATIONS

Operating Data

	Three Months Ended March 31,				Year Ended December 31,
	2020		2019		2019		2018		2017
Operating statistics:
Electric energy volumes (gigawatt-hours):
Residential		9,417		10,319		45,340		46,007		41,483
Commercial, industrial, small business and other		21,003		19,793		88,038		84,049		76,117
Total electric energy volumes		30,420		30,112		133,378		130,056		117,600
Reliability statistics: (a)(b)
System Average Interruption Duration Index (SAIDI) (nonstorm)		84.0		82.0		84.1		90.2		89.7
System Average Interruption Frequency Index (SAIFI) (nonstorm)		1.3		1.2		1.3		1.3		1.4
Customer Average Interruption Duration Index (CAIDI) (nonstorm)		67.0		68.2		67.2		69.2		62.1
Electricity points of delivery (end of period and in thousands):
Electricity distribution points of delivery (based on number of active meters)		3,703		3,639		3,685		3,621		3,551
Operating revenues:
Revenues contributing to earnings:
Distribution base revenues (c)	$	496	$	499	$	2,143	$	2,139	$	1,877
Transmission base revenues (TCOS revenues)
Billed to third-party wholesale customers		196		143		681		548		608
Billed to REPs serving Oncor distribution customers, through TCRF		109		85		391		310		332
Total transmission base revenues		305		228		1,072		858		940
AMS surcharges and other miscellaneous revenues (c)		16		17		77		71		166
Total revenues contributing to earnings		817		744		3,292		3,068		2,983
Revenues collected for pass-through expenses:
TCRF - third party wholesale transmission service		245		260		1,005		962		928
EECRF and other regulatory surcharges		10		12		50		71		47
Revenues collected for pass-through expenses		255		272		1,055		1,033		975
Total operating revenues	$	1,072	$	1,016	$	4,347	$	4,101	$	3,958

(a) SAIDI is the average number of minutes electric service is interrupted per consumer in a year. SAIFI is the average number of electric service interruptions per consumer in a year. CAIDI is the average duration in minutes per electric service interruption in a year.

(b) Excludes impacts of the Sharyland 2017 Asset Exchange.

(c) The separate reconcilable AMS surcharge ceased on November 27, 2017 and AMS-related expenses and returns became recoverable through distribution base revenues.

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Financial Results — Three Months Ended March 31, 2020 Compared to Three Months Ended March 31, 2019

Total operating revenues increased $56 million, or 6%, to $1,072 million in 2020. Revenue is billed under tariffs approved by the PUCT. Our next general rate review is required to be filed with the PUCT on or before October 1, 2021.

Revenues that contribute to earnings increased $73 million during the three months ended March 31, 2020. The change reflected the following components:

• A Decrease in Distribution Base Revenues — Distribution base rate revenues decreased $3 million during the three months ended March 31, 2020. Distribution base rates are set periodically in a rate review docket initiated by either us or the PUCT. The PUCT allows utilities to file, under certain circumstances, DCRF rate adjustments between comprehensive base rate proceedings to recover distribution investments and certain other related costs on an interim basis. The decrease in distribution base rate revenues primarily reflects:

• $22 million net decrease due to lower consumption driven primarily by weather,

Partially offset by:

• $8 million increase due to growth in points of delivery,

• $6 million increase due to the effects of the DCRF rate increases effective September 1, 2019, and

• $5 million increase due to NTU wholesale distribution substation service revenue following the closing of the InfraREIT Acquisition on May 16, 2019.

See the DCRF Filings Table below for a listing of annual filings impacting revenues for 2020 and 2019.

DCRF Filings Table

Docket No.	Filed	Effective	Annual Revenue Impact
50734 (a)	April 2020	September 2020	$	70
49427	April 2019	September 2019	$	25
48231	April 2018	September 2018	$	15

(a) Effective date and annual revenue impact reflect the terms of the unopposed stipulated settlement agreement we filed in the docket on June 24, 2020. The settlement agreement is pending PUCT approval.

• An Increase in Transmission Base Revenues — Transmission base revenues (or TCOS revenues) increased $77 million during the three months ended March 31, 2020. TCOS revenues are collected from load serving entities benefitting from our transmission system. REPs serving customers in our service territory are billed through the TCRF mechanism discussed below, while other load serving entities are billed directly. In order to reflect changes in our invested transmission capital, PUCT rules allow us to update our TCOS rates by filing up to two interim TCOS rate adjustments in a calendar year. The increase in TCOS revenues for the three months ended March 31, 2020 compared to the 2019 period reflects a:

• $57 million increase due to the InfraREIT Acquisition, and

• $20 million increase due to effects of TCOS updates.

See TCOS Filings Table below for a listing of transmission interim rate update applications and anticipated impacts on revenues for the three months ended March 31, 2020 and 2019, as well as filings and the anticipated impact to revenues for the year ended December 31, 2020.

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TCOS Filings Table

Docket No.	Filed	Effective	Annual Revenue Impact		Third-Party Wholesale Transmission		Included in TCRF
50490	January 2020	March 2020	$	32	$	21	$	11
49793	July 2019	September 2019	$	33	$	21	$	12
49160	January 2019	April 2019	$	19	$	12	$	7
48559	July 2018	October 2018	$	21	$	13	$	8

Revenues collected for pass-through expenses decreased $17 million during the three months ended March 31, 2020. While changes in these pass-through tariffs affect revenues and the timing of cash flows, they do not impact operating income and do not contribute to earnings. The net change reflected the following components:

• A Decrease in TCRF – third-party wholesale transmission service (TCRF Third-Party) — TCRF revenues decreased $15 million during the three months ended March 31, 2020. TCRF is a reconcilable distribution rate charged to REPs to recover fees we pay to third-party transmission service providers under their TCOS rates and the retail portion of our own TCOS rate described above. Changes in our TCRF Third-Party revenue are to pass through an increase in third-party wholesale transmission service expense. At March 31, 2020, $14 million was deferred as over-recovered wholesale transmission service expense (see Note 2 to Interim Financial Statements). PUCT rules require us to update the TCRF component of our retail delivery rates on March 1 and September 1 each year. See TCRF Filings Table below for a listing of TCRF filings impacting cash flows for the three months ended March 31, 2020 and 2019, as well as filings and the anticipated impacts to cash flows for the year ended December 31, 2020.

TCRF Filings Table

Docket No.	Filed	Effective	Billing Impact for Period Effective Increase (Decrease)
50300	December 2019	March 2020 - August 2020	$	(72	)
49593	May 2019	September 2019 - February 2020	$	192
48930	November 2018	March 2019 - August 2019	$	(121	)
48408	May 2018	September 2018 - February 2019	$	110

• A Net Decrease in EECRF and Other Regulatory Surcharges — EECRF and other regulatory surcharge revenues decreased by $2 million during the three months ended March 31, 2020. The EECRF is a reconcilable rate designed to recover current energy efficiency program costs and performance bonuses earned by exceeding PUCT targets in prior years and refund or recover any over/under recovery of our costs in prior years. We recognize the performance bonuses in other miscellaneous revenues upon approval by the PUCT. PUCT rules require us to file an annual EECRF tariff update by the first business day in June of each year for implementation on March 1 of the next calendar year. The decrease is due to $2 million lower energy efficiency program costs. See EECRF Filings Table below for a listing of EECRF filings impacting revenues for the three months ended March 31, 2020 and 2019, as well as filings that will impact revenues for the year ended December 31, 2020.

EECRF Filings Table

Docket No.	Filed	Effective	Program Costs		Performance Bonus		Under-/ (Over)- Recovery
49594	May 2019	March 2020	$	50	$	9	$	(3	)
48421	June 2018	March 2019	$	50	$	7	$	—
47235	June 2017	March 2018	$	50	$	12	$	(6	)

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Wholesale transmission service expense decreased $15 million, or 6%, to $245 million in 2020 due to lower fees paid to third-party transmission entities.

Operation and maintenance expense increased $11 million to $232 million in 2020. The increase includes $9 million in higher labor and contractor related costs and $2 million in higher vegetation management costs.

Depreciation and amortization increased $21 million to $193 million in 2020. The increase is attributable to ongoing investments in property, plant and equipment with $12 million related to the InfraREIT Acquisition.

Provision in lieu of income taxes totaled $26 million (including a $3 million benefit related to nonoperating income) in 2020 compared to $22 million (including a $3 million benefit related to nonoperating income) in 2019.

The effective income tax rate was 16.6% and 15.9% for the 2020 and 2019 periods, respectively. The effective tax rate on pretax income differs from the U.S. federal statutory rate of 21% primarily due to the amortization of the regulatory liability for excess deferred taxes as a result of the TCJA, partially offset by the effects of the Texas margin tax.

Taxes other than income taxes increased $9 million and reflects an $8 million increase in property taxes, including $4 million resulting from the InfraREIT Acquisition and $1 million in higher local franchise fees.

Other income and (deductions) - net was $4 million favorable in 2020 compared to 2019. The variance is primarily due to allowance for funds used during construction (AFUDC) equity income in the current period. See Note 10 to Interim Financial Statements for more information.

Interest expense and related charges increased $15 million to $101 million in 2020. The current period includes a $19 million increase due to higher average borrowings including an $11 million increase attributable to the InfraREIT Acquisition, partially offset by a $5 million decrease due to lower average interest rates.

Net income was $15 million higher than the prior period, primarily driven by the impacts of the InfraREIT Acquisition, increases in base transmission and distribution rates and customer growth, partially offset by lower consumption due to weather, increases in operation and maintenance expense, depreciation and amortization, property taxes and interest expense.

OTHER COMPREHENSIVE INCOME

In February and March 2020, we entered into interest rate hedge transactions hedging the variability of benchmark bond rates used to determine the interest rates on anticipated issuances of ten-year and thirty-year senior secured notes (see Note 5 to Interim Financial Statements for information regarding the debt issuances). The hedges were terminated in March 2020 upon the issuance of the 2030 Notes and 2050 Notes, and a $29 million ($23 million after-tax) loss was reported in other comprehensive income. We expect approximately $4 million of the amount reported in accumulated other comprehensive loss at March 31, 2020 related to interest rate hedges to be reclassified into net income as an increase to interest expense within the next twelve months, including $2 million related to current period transactions.

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Financial Results — Year Ended December 31, 2019 Compared to Year Ended December 31, 2018

Total operating revenues increased $246 million, or 6%, to $4,347 million in 2019. Revenue is billed under tariffs approved by the PUCT.

Revenues that contribute to earnings increased $224 million during 2019. The change reflected the following components:

• An Increase in Distribution Base Revenues — Distribution base rates are set periodically in a rate review docket initiated by either us or the PUCT. The PUCT allows utilities to file, under certain circumstances, once per year to recover distribution investments and certain other related costs on an interim basis. The $4 million increase in distribution base rate revenues primarily reflects:

• $26 million increase due to growth in points of delivery,

• $18 million increase due to the effects of the DCRF rate increases effective September 1, 2019, and

• $12 million increase due to NTU wholesale distribution substation service revenue following the closing of the InfraREIT Acquisition.

• Partially offset by $31 million decrease due to refund of excess deferred federal income taxes beginning October 2018, and

• $21 million decrease due to lower consumption driven primarily by weather.

See the DCRF Filings Table below for a listing of annual filings impacting revenues for 2019 and 2018.

DCRF Filings Table

Docket No.	Filed	Effective	Annual Revenue Impact
49427	April 2019	September 2019	$	25
48231	April 2018	September 2018	$	15

• An Increase in Transmission Base Revenues —TCOS revenues increased $214 million during the year ended December 31, 2019. TCOS revenues are collected from load serving entities benefitting from our transmission system. REPs serving customers in our service territory are billed through the TCRF mechanism discussed below, while other load serving entities are billed directly. In order to reflect changes in our invested transmission capital, PUCT rules allow us to update our TCOS rates by filing up to two interim TCOS rate adjustments in a calendar year. The increase in TCOS revenues for the year ended December 31, 2019 compared to the year ended December 31, 2018 reflects a:

• $142 million increase due to the InfraREIT Acquisition, and

• $88 million increase due to effects of TCOS updates,

• Partially offset by a $11 million decrease due to the refund of excess deferred federal income taxes resulting from the TCJA, and

• $5 million decrease due to a requirement in the PUCT final order approving the InfraREIT Acquisition that we provide merger-savings rate credits to customers, $5 million of which was required to be paid in 2019, and an additional $5 million to be paid in each of 2020 and 2021.

See TCOS Filings Table below for a listing of transmission interim rate update applications and anticipated impacts on revenues for the years ended December 31, 2019 and 2018, as well as filings and the anticipated impact to revenues for the year ending December 31, 2020.

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TCOS Filings Table

Docket No.	Filed	Effective	Annual Revenue Impact			Third-Party Wholesale Transmission			Included in TCRF
50490	January 2020	March 2020	$	32		$	21		$	11
49793	July 2019	September 2019	$	33		$	21		$	12
49160	January 2019	April 2019	$	19		$	12		$	7
48559 (a)	July 2018	October 2018	$	21		$	13		$	8
48325 (TCJA)	May 2018	July 2018	$	(15	)	$	(10	)	$	(5	)
47988	January 2018	March 2018	$	14		$	9		$	5

(a) This docket includes a $12 million annual revenue reduction for excess deferred taxes related to the Docket No. 48325 (TCJA) line below.

• An Increase in Other Miscellaneous Revenues — Other miscellaneous revenues increased $6 million primarily due to a $2 million higher energy efficiency program bonus and $3 million higher other service revenue including facility studies and mutual assistance.

Revenues collected for pass-through expenses include the following components. While changes in these tariffs affect revenues and the timing of cash flows, they do not impact operating income and do not contribute to earnings. These revenues increased $22 million during the year ended December 31, 2019 and the change reflected:

• An Increase in TCRF – third-party wholesale transmission service (TCRF Third-Party) — TCRF revenues increased $43 million during the year ended December 31, 2019. TCRF is a reconcilable distribution rate charged to REPs to recover fees we pay to third-party transmission service providers under their TCOS rates and the retail portion of our own TCOS rate described above. Changes in our TCRF Third-Party revenue are to pass through an increase in third-party wholesale transmission service expense. At December 31, 2019, $30 million was deferred as over-recovered wholesale transmission service expense (see Note 3 to Annual Financial Statements). PUCT rules require us to update the TCRF component of our retail delivery rates on March 1 and September 1 each year.

See TCRF Filings Table below for a listing of TCRF filings impacting cash flows for the year ended December 31, 2019 and 2018, as well as filings and the anticipated impacts to cash flows for the year ended December 31, 2020.

TCRF Filings Table

Docket No.	Filed	Effective	Billing Impact for Period Effective Increase (Decrease)
50300	December 2019	March 2020 - August 2020	$	(72	)
49593	May 2019	September 2019 - February 2020	$	192
48930	November 2018	March 2019 - August 2019	$	(121	)
48408	May 2018	September 2018 - February 2019	$	110
47824	December 2017	March 2018 - August 2018	$	(52	)
46957 (rate review)	March 2017	December 2017 - February 2018	$	(28	)

• A Net Decrease in EECRF and Other Regulatory Surcharges — EECRF and other regulatory surcharge revenues decreased by $21 million during the year ended December 31, 2019. The EECRF is a reconcilable rate designed to recover current energy efficiency program costs and performance bonuses earned by exceeding PUCT targets in prior years and to refund or recover any over/under recovery of our costs in prior years. We recognize the performance bonuses in other miscellaneous revenues upon approval by the PUCT. PUCT rules require us to file an annual EECRF tariff update by the first business day in June of each year for implementation on March 1 of the next calendar year. The net decrease includes a $25 million reduction due to cessation of certain surcharges related to rate case expenses and recovery of certain municipal franchise fees as part of the 2017 rate review, offset by a $4 million increase in energy efficiency program costs.

See EECRF Filings Table below for a listing of EECRF filings impacting revenues for the year ended December 31, 2019 and 2018, as well as filings that will impact revenues for the year ended December 31, 2020.

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EECRF Filings Table

Docket No.	Filed		Effective		Monthly Charge per Residential Customer (a)		Program Costs		Performance Bonus		Under-/ (Over)- Recovery
49594		May 2019		March 2020	$	0.89	$	50	$	9	$	(3	)
48421		June 2018		March 2019	$	0.91	$	50	$	7	$	—
47235		June 2017		March 2018	$	0.92	$	50	$	12	$	(6	)
46013		June 2016		March 2017	$	0.94	$	49	$	10	$	(4	)

(a) Monthly charges are for a residential customer using an assumed 1,200 kWh.

Wholesale transmission service expense increased $43 million, or 4%, to $1,005 million in 2019 primarily due to higher fees paid to other transmission entities.

Operation and maintenance expense increased $24 million, or 3%, to $899 million in 2019. The increase includes $9 million higher labor and contractor related costs, $8 million in higher materials and transportation costs and $4 million higher energy efficiency program costs.

Depreciation and amortization increased $52 million to $723 million in 2019. The increase is primarily attributable to ongoing investments in property, plant and equipment and $29 million from property, plant and equipment acquired in the InfraREIT Acquisition.

Provision in lieu of income taxes totaled $123 million (including a $15 million benefit related to nonoperating income) in 2019 compared to $117 million (including a $35 million benefit related to nonoperating income) in 2018.

The effective income tax rate was 15.9% and 17.7% for the 2019 and 2018 periods, respectively. The effective tax rate on pretax income differs from the U.S. federal statutory rate of 21% primarily due to the amortization of the regulatory liability for excess deferred taxes as a result of the TCJA, partially offset by the effects of the Texas margin tax.

Taxes other than income taxes increased $12 million, or 2%, to $508 million in 2019. The increase is primarily due to $28 million higher property taxes in the current period including $16 million related to the InfraREIT Acquisition and $4 million higher local franchise fees, partially offset by $20 million expense in the prior period related to recovery of certain municipal franchise fees as part of the 2017 rate review.

Other deductions and (income) - net was $21 million favorable in 2019 compared to 2018. The variance is primarily due to allowance for funds used during construction (AFUDC) equity income recorded in the current period and Sempra Acquisition related costs reflected in the prior period. See Note 13 to Annual Financial Statements for more information.

Interest expense and related charges were $375 million and $351 million for 2019 and 2018, respectively. The $24 million increase is primarily driven by a $61 million increase due to higher average borrowings including $27 million related to the InfraREIT Acquisition, partially offset by a $36 million decrease attributable to lower average interest rates.

Net income was $106 million higher than the prior period, primarily driven by an increase in revenues that contribute to earnings, the impacts of the InfraREIT Acquisition and favorable other income including AFUDC equity, partially offset by increases in operation and maintenance expense, property taxes, depreciation and amortization and a TCJA related write-off in the prior period.

FINANCIAL CONDITION

Liquidity and Capital Resources

Cash Flows — Three Months Ended March 31, 2020 Compared to Three Months Ended March 31, 2019

Cash provided by operating activities totaled $202 million and $186 million in 2020 and 2019, respectively. The $16 million increase is primarily the result of a $119 million increase in transmission and distribution receipts and a $6 million decrease in commercial paper interest payments, partially offset by a $40 million increase in long-term debt interest

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payments, $30 million increase in property tax payments, $13 million increase in employee benefit plan funding, $10 million increase in materials and supplies purchasing, $8 million decrease in customer deposits and $7 million increase in storm costs.

Cash provided by financing activities totaled $704 million and $327 million in 2020 and 2019, respectively. The $377 million net increase includes $800 million of outstanding note issuances, $450 million in borrowings under our January 2020 Term Loan Agreement, partially offset by the repayment of $462 million principal amount of long-term debt (consisting of the $460 million principal amount outstanding under our 2019 Term Loan Agreement and $2 million principal amount of the quarterly amortizing debt for senior secured notes issued under one of our Note Purchase Agreements), $374 million net decrease in outstanding CP Notes, and $34 million in debt discount and financing costs. For more details, see Notes 4 and 5 to the Interim Financial Statements for additional information regarding short-term borrowings and long-term debt activity, respectively, and Note 7 to Interim Financial Statements for additional information regarding capital contributions from and distributions to our members.

Cash used in investing activities totaled $620 million and $511 million in 2020 and 2019, respectively. The $109 million increase is primarily due to the increase in capital expenditures for transmission and distribution facilities to serve new customers and infrastructure capital maintenance spending in the current period.

Depreciation and amortization expense reported in the statements of consolidated cash flows was $20 million more than the amounts reported in the statements of consolidated income in both the three months ended March 31, 2020 and 2019. The differences result from certain regulatory asset amortization reported in operation and maintenance expense and taxes other than income taxes.

Cash Flows — Year Ended December 31, 2019 Compared to Year Ended December 31, 2018

Cash provided by operating activities totaled $1,275 million and $1,482 million in 2019 and 2018, respectively. The $207 million decrease is primarily the result of a $162 million increase in storm costs, a $66 million decrease in transmission and distribution receipts, a $27 million increase in materials and supply purchases, and a $23 million increase in interest payments. The decreases were partially offset by $47 million of lower employee benefit plan funding and $15 million of higher stock-based compensation related payments in the prior period.

Cash provided by financing activities totaled $2,104 million and $249 million in 2019 and 2018, respectively. The $1,855 million net increase includes debt restructuring activity in connection with the InfraREIT Acquisition that included new debt issuances and the receipt of capital contributions, partially offset by the extinguishment of certain debt of InfraREIT and its subsidiaries. The current period activity also includes an increase due to $1,160 million of new debt issuances, the repayment of all short-term debt and the repayment of Oncor senior secured notes that matured during the period. For more details, see Notes 6 and 7 to Annual Financial Statements for additional information regarding short-term borrowings and long-term debt activity, respectively, and Note 9 to Annual Financial Statements for additional information regarding capital contributions from our members.

Cash used in investing activities totaled $3,378 million and $1,749 million in 2019 and 2018, respectively. The $1,629 million increase is primarily due to the $1,324 million purchase price paid for the InfraREIT Acquisition and a $330 million increase in capital expenditures for transmission and distribution facilities to serve new customers and infrastructure capital maintenance spending in the current period. The “Other” line includes proceeds of $18 million from the sale of certain distribution assets. For more details on the purchase price paid for the InfraREIT Acquisition, see Note 2 to Annual Financial Statements.

Depreciation and amortization expense reported in the statements of consolidated cash flows was $83 million and $106 million more than the amounts reported in the statements of consolidated income for the years ended December 31, 2019 and 2018, respectively. The differences result from certain regulatory asset amortization reported in operation and maintenance expense and taxes other than income taxes.

Long-Term Debt Activity

Senior Secured Notes Issuances — In March 2020, we issued $400 million aggregate principal amount of outstanding 2030 notes and $400 million aggregate principal amount of outstanding 2050 notes. For more information on the outstanding note issuances, see Note 5 to Interim Financial Statements.

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Long-Term Unsecured Term Loan Credit Agreements — On January 28, 2020, we executed the January 2020 Term Loan Agreement, a $450 million term loan credit agreement that matures on June 1, 2021. At March 31, 2020, we had borrowed the full $450 million available under the agreement, through borrowings of $163 million on January 29, 2020, $55 million on February 28, 2020 and $232 million on March 17, 2020. The proceeds from each borrowing were used for general corporate purposes, including the repayment of notes outstanding under our CP Program. Loans under the January 2020 Term Loan Agreement bear interest at per annum rates equal to, at our option, (i) LIBOR plus 0.50% until June 1, 2021, or (ii) an alternate base rate (the highest of (1) the prime rate of Sumitomo Mitsui Banking Corporation, the administrative agent and a lender under the agreement, (2) the federal funds effective rate plus 0.50%, and (3) daily one-month LIBOR plus 1%).

On March 23, 2020, we entered into the March 2020 Term Loan Agreement with a commitment equal to an aggregate principal amount of $350 million. We entered into an amendment to the March 2020 Term Loan Agreement on June 19, 2020. As amended, the March 2020 Term Loan Agreement has a maturity date of June 30, 2021. We may borrow up to $350 million in up to four borrowings which may be made, at our option, at any time in the period beginning on April 1, 2020 and ending on the earliest to occur of (i) the date on which the term loans are funded in full and no commitments remain unused, (ii) the fourth funding date and (iii) 5:00 p.m. Eastern time on August 7, 2020. As amended, the March 2020 Term Loan Agreement provides for loans to bear interest at per annum rates equal to, at our option, (x) LIBOR plus 0.950%, or (y) an alternate base rate (the highest of (1) the prime rate of Wells Fargo, (2) the federal funds effective rate plus 0.50%, and (3) daily one-month LIBOR plus 1%). No amounts were outstanding under the March 2020 Term Loan Agreement as of March 31, 2020. On June 30, 2020, we made our first borrowing under the March 2020 Term Loan Agreement, in the amount of $15 million.

The January 2020 Term Loan Agreement and March 2020 Term Loan Agreement contain customary covenants for facilities of this type, restricting, subject to certain exceptions, us and our subsidiaries from, among other things: incurring certain additional liens (not including liens relating to obligations secured pursuant to our Deed of Trust, which are permitted); entering into mergers and consolidations; sales of substantial assets and acquisitions and investments in subsidiaries. Each of these term loan credit agreements also contains a senior debt-to-capitalization ratio covenant that effectively limits our ability to incur indebtedness in the future. See “Credit Rating Provisions, Covenants and Cross Default Provisions” below for additional information on this covenant and the calculation of this ratio.

Long-Term Debt Repayments — Repayments of long-term debt in the three months ended March 31, 2020 included repayment of the $460 million principal amount borrowed under the 2019 Term Loan Agreement and $2 million principal amount of the quarterly amortizing debt for senior secured notes issued under one of our Note Purchase Agreements.

See Note 5 to Interim Financial Statements for more information regarding the new long-term debt issuances and long-term debt repayments.

Short-Term Debt Activity

Our first borrowing under the 2020 Term Loan Agreement was made on June 30, 2020 in the amount of $15 million.

CP Program — As discussed in Note 4 to Interim Financial Statements, in March 2018 we established the CP Program, under which we may issue CP Notes on a private placement basis up to a maximum aggregate amount outstanding at any time of $2.0 billion. A national bank acts as the issuing and paying agent under the CP Program pursuant to the terms of an issuing and paying agent agreement. Under the CP Program, we issue CP Notes from time to time, and the proceeds of the CP Notes are used for short-term financing of our business operations. At March 31, 2020, we had no CP Notes outstanding.

The CP Program obtains liquidity support from our Credit Facility discussed below. If at any time funds are not available on favorable terms under the CP Program, we may utilize the Credit Facility for funding.

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The maturities of the CP Notes will vary, but may not exceed 364 days from the date of issue. Interest rates will vary based upon market conditions at the time of issuance of the CP Notes and may be fixed or floating determined by reference to a base rate and spread.

Credit Facility — At March 31, 2020, we had a $2.0 billion unsecured Credit Facility with a five-year term expiring in November 2022. The Credit Facility may be used for working capital and general corporate purposes, issuances of letters of credit and support for our CP Program. We have the option of requesting up to two one-year extensions and an option to request an increase in our borrowing capacity of $400 million, in increments of not less than $100 million, provided certain conditions are met, including lender approvals. Borrowings under the Credit Facility are classified as short term on the balance sheet. At March 31, 2020, we had no outstanding borrowings under the Credit Facility and $9 million in letters of credit.

Because the CP Program is supported by the Credit Facility, CP Notes outstanding reduces the available borrowing capacity. Considering the letters of credit and the CP Notes outstanding and the limitations described below, available borrowing capacity under the Credit Facility totaled $1.991 billion and $1.944 billion at March 31, 2020 and December 31, 2019, respectively.

The Credit Facility contains customary covenants for facilities of this type, restricting, subject to certain exceptions, us and our subsidiaries from, among other things: incurring certain additional liens (not including liens relating to obligations secured pursuant to our Deed of Trust, which are permitted); entering into mergers and consolidations; sales of substantial assets and acquisitions and investments in subsidiaries. The Credit Facility also contains a senior debt-to-capitalization ratio covenant that effectively limits our ability to incur indebtedness in the future. At March 31, 2020, we were in compliance with this covenant and all other covenants in the Credit Facility. See “Credit Rating Provisions, Covenants and Cross Default Provisions” below for additional information on this covenant and the calculation of this ratio.

Under the terms of the Credit Facility, the commitments of the lenders to make loans to us are several and not joint. Accordingly, if any lender fails to make loans to us, our available liquidity could be reduced by an amount up to the aggregate amount of such lender’s commitments under the facility.

Regulatory Capital Structure — We have committed to the PUCT to maintain a regulatory capital structure at or below the assumed debt-to-equity ratio established periodically by the PUCT for ratemaking purposes, which is currently 57.5% debt to 42.5% equity. Our actual regulatory capitalization ratio was 56.5% debt to 43.5% equity at March 31, 2020. See Note 7 to Interim Financial Statements for discussion of the regulatory capitalization ratio. Our ability to incur additional long-term debt is limited by our regulatory capital structure, as we are able to issue future long-term debt only to the extent that we are in compliance therewith.

Available Liquidity and Liquidity Needs, Including Capital Expenditures

Capital Expenditures — Our board of directors, which annually approves capital expenditure estimates for the following year, has approved capital expenditures totaling $2.5 billion in 2020. Management currently expects to recommend to our board of directors capital expenditures of $2.3 billion to $2.4 billion in each of the years 2021 through 2024, for a total of $11.9 billion for the five year period 2020 through 2024, based on the long-term plan presented to our board of directors. These capital expenditures are expected to be used for investment in transmission and distribution infrastructure, including expansion, maintenance and information technology.

Available Liquidity — Our primary source of liquidity, aside from operating cash flows, has been our ability to borrow under our Credit Facility, which also supports our CP Program. Because the CP Program is supported by the Credit Facility, commercial paper outstanding is a reduction to the available borrowing capacity. Cash and cash equivalents totaled $290 million and $4 million at March 31, 2020 and December 31, 2019, respectively. Considering commercial paper and letters of credit outstanding, available liquidity (cash and available Credit Facility borrowing capacity) at March 31, 2020 totaled $2.281 billion, reflecting an increase of $333 million from December 31, 2019 primarily due to the issuance of new long-term debt and repayment of CP Notes. See Note 4 to Interim Financial Statements for more information on these transactions.

In March 2020, we took steps to increase our available liquidity by borrowing the remaining $232 million available under our January 2020 Term Loan Agreement, issuing an aggregate of $800 million of the outstanding notes, repaying outstanding commercial paper and the $460 million principal amount outstanding under the 2019 Term Loan Agreement, and entering into the March 2020 Term Loan Agreement. See Notes 4 and 5 to Interim Financial Statements for more information on these transactions. Beginning April 1, 2020, we were able to borrow up to $350 million under the March 2020 Term Loan Agreement increasing our available liquidity to $2.631 billion as of that date.

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We expect cash flows from operations as well as availability under the March 2020 Term Loan Agreement, our Credit Facility and, to the extent we can access the commercial paper market on reasonable terms during the COVID-19 pandemic and its aftermath, the CP Program, to provide sufficient liquidity to fund current obligations, projected working capital requirements, maturities of long-term debt and capital spending for at least the next twelve months. Should additional liquidity or capital requirements arise, we may need to access the capital and credit markets, seek member capital contributions or preserve equity through reductions or suspension of distributions to members. In addition, we may also consider additional new debt issuances, repurchases, exchange offers and other transactions in order to refinance or manage our long-term debt. The inability to raise capital on favorable terms or failure of counterparties to perform under credit or other financial agreements, particularly during any uncertainty in the financial markets including any uncertainty due to the COVID-19 pandemic, could impact our ability to sustain and grow the business and would likely increase capital costs that may not be recoverable through rates.

The COVID-19 pandemic has not had a material adverse impact on our liquidity to date. However, we do face risks and uncertainties related to the pandemic, including as a result of its impact on capital and credit markets, and cannot predict whether, or to what extent, the pandemic will have a material adverse impact on our liquidity in the future. The COVID-19 pandemic has caused significant disruption in the commercial paper market and has substantially impacted capital markets and the availability of financing from commercial banks. As a result our ability to access the capital markets or obtain new credit commitments from commercial banks could become materially constrained. For further discussion of risks and uncertainties related to the COVID-19 pandemic, see “Risk Factors.”

Various federal and state actions implemented in connection with the COVID-19 pandemic could also impact our liquidity. For example, the federal Coronavirus Aid, Relief, and Economic Security Act (CARES Act) permits retirement plan sponsors to defer certain pension plan contributions required by ERISA. As a result, we could elect to defer some or all of our 2020 required Oncor Retirement Plan contributions.

In addition, the PUCT issued an order in PUCT Project No. 50664 on March 26, 2020 creating the COVID-19 ERP to aid certain residential customers unable to pay their electricity bills as a result of the impact of COVID-19. The PUCT order includes a surcharge to collect funds to cover costs relating to the COVID-19 ERP and a $7 million unsecured ERCOT loan. The PUCT order is designed to minimize the impact that COVID-19 related costs have on the liquidity of transmission and distribution utilities. For more information on PUCT Project No. 50664 and COVID-19-related regulatory matters, see Note 2 to Interim Financial Statements.

Member Contributions and Distributions

Cash Contributions — We received cash capital contributions from our members on February 18, 2020 and April 27, 2020 each totaling $87 million. During 2019, we received the following capital cash contributions from our members:

Received	Amount
November 21, 2019	$	340
October 28, 2019		98
July 29, 2019		70
May 15, 2019		1,330
April 30, 2019		70
February 19, 2019		70
	$	1,978

Cash Distributions — The PUCT order issued in the Sempra Acquisition and our Limited Liability Company Agreement set forth various restrictions on distributions to our members. Among those restrictions is the commitment that we will make no distributions that would cause us to be out of compliance with the PUCT’s approved debt-to-equity ratio, which is currently 57.5% debt to 42.5% equity. The distribution restrictions also include the ability of our board, a majority of the Disinterested Directors, or either of the two member directors designated by Texas Transmission to limit distributions to the extent each determines it is necessary to meet expected future requirements of Oncor (including continuing compliance with the PUCT debt-to-equity ratio commitment). At March 31, 2020, our regulatory capitalization ratio was 56.5% debt to 43.5% equity and we had $301 million available to distribute to our members.

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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 including finance leases 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 accumulated other comprehensive loss and the effects of acquisition accounting from a 2007 transaction.

On February 19, 2020, our board of directors declared a cash distribution of $91 million, which was paid to our members on February 20, 2020. On April 29, 2020, our board of directors declared a cash distribution of $91 million, which was paid to our members on April 30, 2020. During 2019, our board of directors declared, and we paid, the following cash distributions to our members:

Declaration Date	Payment Date	Amount
October 29, 2019	October 31, 2019	$	106
July 30, 2019	July 31, 2019		71
May 1, 2019	May 2, 2019		71
February 20, 2019	February 22, 2019		71
		$	319

See Note 7 to Interim Financial Statements and Note 9 to Annual Financial Statements for a discussion of distribution restrictions.

Pension and OPEB Plan Funding

Our funding for the pension plans and Oncor OPEB Plans in the calendar year 2020 is expected to total $177 million and $35 million, respectively. In the three months ended March 31, 2020, we made cash contributions of $13 million to the pension plans and $10 million to the Oncor OPEB Plans. Based on the funded status of the pension plans at December 31, 2019, our aggregate pension and Oncor OPEB plans funding is expected to total approximately $747 million in the five year period 2020 to 2024. In 2019, we made cash contributions to the pension and OPEB plans of $41 million and $35 million, respectively. See Note 8 to Interim Financial Statements and Note 10 to Annual Financial Statements for additional information regarding pension and OPEB plans.

Credit Rating Provisions, Covenants and Cross Default Provisions

Impact on Liquidity of Credit Ratings — The rating agencies assign credit ratings to certain of our debt securities. Our access to capital markets and cost of debt could be directly affected by our credit ratings. Any adverse action with respect to our credit ratings could generally cause borrowing costs to increase and the potential pool of investors and funding sources to decrease. In the event any adverse action with respect to our credit ratings takes place and causes borrowing costs to increase, we may not be able to recover such increased costs if they exceed our PUCT-approved cost of debt determined in our most recent rate review or subsequent rate reviews.

Most of our large suppliers and counterparties require an expected level of creditworthiness in order for them to enter into transactions with us. If our credit ratings decline, the costs to operate our business could increase because counterparties could require the posting of collateral in the form of cash-related instruments, or counterparties could decline to do business with us.

A rating reflects only the view of a rating agency, and is not a recommendation to buy, sell or hold securities. Ratings can be revised upward or downward at any time by a rating agency, if such rating agency decides that circumstances warrant such a change.

Material Credit Rating Covenants — The Credit Facility contains terms pursuant to which the interest rates charged under the agreement may be adjusted depending on credit ratings. Borrowings under the Credit Facility bear interest at per annum rates equal to, at our option, (i) adjusted LIBOR plus a spread ranging from 0.875% to 1.50% 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) adjusted LIBOR plus 1.00%) plus a spread ranging from 0.00% to 0.50% depending on credit ratings assigned to our senior secured non-credit enhanced long-term debt. Based on the ratings assigned to our senior secured debt securities at May 4, 2020, our borrowings are generally LIBOR-based and will bear interest at LIBOR plus 1.00%. A decline in credit ratings would increase the cost of borrowings

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under the Credit Facility and likely increase the cost of our CP Program and any other debt issuances and additional credit facilities. The CP Program requires prompt notice to the dealer of any notice of intended or potential downgrade of our credit ratings.

Material Financial Covenants — Our Credit Facility, the Note Purchase Agreements, and term loan agreements each contain a financial covenant that requires maintenance of a consolidated debt-to-capitalization ratio of no greater than 0.65 to 1.00. For purposes of this ratio, debt is calculated as indebtedness defined in the applicable agreement (principally, the sum of long-term debt, any capital leases (referred to as finance leases under current accounting literature), short-term debt and debt due currently in accordance with GAAP). Capitalization for our Credit Facility and term loan agreements is calculated as membership interests determined in accordance with GAAP plus debt described above. The ratio under our Note Purchase Agreements is calculated as total debt (all debt of the company and subsidiaries on a consolidated basis) divided by the sum of total debt plus capitalization. Capitalization under the Note Purchase Agreements is calculated as membership interests plus liabilities for indebtedness maturing more than 12 months from the date of determination, with capitalization determined in accordance with GAAP and practices applicable to our type of business. At March 31, 2020, we were in compliance with this covenant and all other covenants under the Credit Facility, term loan credit agreements and Note Purchase Agreements.

Material Cross Default Provisions — Certain financing arrangements contain provisions that may result in an event of default if there was a failure under other financing arrangements to meet payment terms or to observe other covenants that could result in an acceleration of payments due. Such provisions are referred to as “cross default” provisions.

Under the Credit Facility our term loan agreements and the Note Purchase Agreements, a default by us or any subsidiary in respect of indebtedness in a principal amount in excess of $100 million or any judgments for the payment of money in excess of $100 million that are not discharged within 60 days may cause the maturity of outstanding balances under those facilities to be accelerated.

Under the Deed of Trust, an event of default under our indentures or, after all applicable notices have been given and all applicable grace periods have expired, under the Note Purchase Agreements, would permit the holders of our senior secured notes to exercise their remedies under the Deed of Trust.

Long-Term Contractual Obligations and Commitments

The following table summarizes our contractual cash obligations at March 31, 2020. See Notes 5 and 6 to Interim Financial Statements for additional disclosures regarding long-term debt and operating lease obligations, respectively.

Contractual Cash Obligations	Less Than One Year		One to Three Years		Three to Five Years		More than Five Years		Total
Long-term debt (a) – principal	$	148	$	1,350	$	520	$	7,451	$	9,469
Long-term debt (a) – interest		409		786		693		4,843		6,731
Operating leases		23		52		30		28		133
Obligations under outsourcing agreements		41		9		—		—		50
Total contractual cash obligations	$	621	$	2,197	$	1,243	$	12,322	$	16,383

(a) See Note 5 to Interim Financial Statements for more information regarding our long-term debt.

The following are not included in the table above:

• individual contracts that have an annual cash requirement of less than $1 million (however, multiple contracts with one counterparty that are more than $1 million on an aggregated basis have been included);

• employment contracts with management;

• estimated funding of the pension and OPEB plans totaling $212 million in 2020 and $747 million in the five-year period 2020 to 2024 as discussed above under “Pension and OPEB Plan Funding”; and

• capital expenditure commitments made as part of the Sempra Acquisition (see Note 8 to Annual Financial Statements).

Guarantees

At March 31, 2020, we did not have any material guarantees.

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OFF-BALANCE SHEET ARRANGEMENTS

At March 31, 2020, we did not have any material off-balance sheet arrangements with special purpose entities or variable interest entities.

COMMITMENTS AND CONTINGENCIES

See Note 6 to Interim Financial Statements for discussion of commitments and contingencies.

CHANGES IN ACCOUNTING STANDARDS

See Note 1 to Interim Financial Statements for discussion of changes in accounting standards.

REGULATION AND RATES

Matters with the PUCT

DCRF (PUCT Docket No. 50734) — PUCT rules provide that DCRF applications may only be filed from April 1 to April 8 of each year. Accordingly, on April 3, 2020, we filed with the PUCT, as well as with cities with original jurisdiction over our rates, an application for approval of an updated DCRF. The DCRF allows us to recover, primarily through our tariff for retail delivery service, certain costs related to our distribution investments. In our DCRF application, we requested a $76 million increase in annual distribution revenues primarily related to 2019 distribution investments. On June 24, 2020, we filed an unopposed stipulation and settlement agreement that included a $70 million increase in annual distribution revenues and, on June 29, 2020, interim rates based on the settlement agreement were authorized to begin effective September 1, 2020. All parties to the proceeding have either joined in the settlement agreement or indicated they are unopposed. The settlement agreement and rates are subject to final PUCT approval.

See Note 2 to Interim Financial Statements for a discussion of other significant PUCT matters.

In addition, in May 2020 we also filed for approval of a TCRF update in PUCT Docket. No. 50883 (proposed anticipated billing impact of $81 million and effective period September 2020-February 2021) and an EECRF application in PUCT Docket No. 50886 (proposed $52 million in program costs effective March 2021). Both are pending PUCT approval.

Summary

We cannot predict future regulatory or legislative actions or any changes in economic and securities market conditions. Such actions or changes could significantly alter our financial position, results of operations or cash flows.

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CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS

ON ACCOUNTING AND FINANCIAL DISCLOSURE

None.

QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Interest Rate Risk

Market risk is the risk that we may experience a loss in value as a result of changes in market conditions such as interest rates that may be experienced in the ordinary course of business. We may transact in financial instruments to hedge interest rate risk related to our debt from time to time, but there are currently no such hedges in place. At December 31, 2019 and 2018, all of our long-term debt except for the $460 million and $350 million term loan credit agreement balances at December 31, 2019 and 2018, respectively, carried fixed interest rates. The following table summarizes our long-term debt maturities at December 31, 2019.

	Expected Maturity Date
	2020			2021			2022			2023			2024			There- after			2019 Total Carrying Amount			2019 Total Fair Value		2018 Total Carrying Amount			2018 Total Fair Value
	(millions of dollars and percent)
Long-term debt (including current maturities):
Fixed rate debt amount (a)	$	148		$	9		$	891		$	10		$	510		$	6,653		$	8,221		$	9,543	$	6,126		$	6,736
Weighted average interest rate		4.83	%		6.72	%		5.70	%		6.72	%		2.83	%		4.67	%		4.39	%		—		5.03	%		—
Variable rate debt amount (a)	$	460		$	—		$	—		$	—		$	—		$	—		$	460		$	460	$	350		$	350
Average interest rate		2.28	%		—			—			—			—			—			2.28	%		—		3.44	%		—
Total Debt	$	608		$	9		$	891		$	10		$	510		$	6,653		$	8,681		$	10,003	$	6,476		$	7,086

(a) Excludes unamortized premiums, discounts and debt issuance costs. See Note 7 to Annual Financial Statements for a discussion of changes in long-term debt obligations.

At December 31, 2019, the potential reduction of annual pretax earnings over the next twelve months due to a one percentage-point (100 basis points) increase in floating interest rates on debt (including short-term borrowings) totaled $5 million.

Our term loan credit agreements contain terms pursuant to which the interest rate charged can vary, at our option, depending on the selected interest period. Our Credit Facility contains terms pursuant to which the interest rates charged under the agreement may be adjusted depending on credit ratings. Borrowings under the CP Program may bear interest on a fixed rate or floating rate basis and will vary based on market conditions at the time of borrowings. For information on our interest rates charged under: (i) the Credit Facility, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Financial Condition – Liquidity and Capital Resources – Credit Rating Provisions, Covenants and Cross Default Provisions – Material Credit Rating Covenants,” (ii) the January 2020 Term Loan Agreement, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Financial Condition – Liquidity and Capital Resources – Long-Term Debt Activity,” and (iii) the March 2020 Term Loan Agreement, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Financial Condition – Liquidity and Capital Resources – Long-Term Debt Activity.”

Credit Risk

Credit risk relates to the risk of loss associated with nonperformance by counterparties. Our customers consist primarily of REPs. As a prerequisite for obtaining and maintaining certification, a REP must meet the financial resource standards established by the PUCT. Meeting these standards does not guarantee that a REP will be able to perform its

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obligations. REP certificates granted by the PUCT are subject to suspension and revocation for significant violation of PURA and PUCT rules. Significant violations include failure to timely remit payments for invoiced charges to a transmission and distribution utility pursuant to the terms of tariffs approved by the PUCT. We believe PUCT rules that allow for the recovery of uncollectible amounts due from REPs through rates significantly reduce our credit risk.

Our exposure to credit risk associated with trade accounts receivable totaled $662 million at March 31, 2020 and $666 million at December 31, 2019. The receivable amount is before the allowance for uncollectible accounts, which totaled $6 million at March 31, 2020 and $5 million at December 31, 2019. The exposure includes trade accounts receivable from REPs totaling $461 million and $492 million at March 31, 2020 and December 31, 2019, respectively, which are almost entirely noninvestment grade and from transmission customers totaling $50 million and $48 million at March 31, 2020 and December 31, 2019, respectively, which include investment grade distribution companies and cooperatives and municipalities, which are generally considered low credit risk. At March 31, 2020, REP subsidiaries of our two largest customers represented 15% and 11% of the trade receivable balance, respectively. At December 31, 2019, REP subsidiaries of two entities represented 15% and 11% of the trade receivable balance. No other parties represented 10% or more of the total trade accounts receivable balance at March 31, 2020 or December 31, 2019. We view our exposure to these customers to be within an acceptable level of risk tolerance considering PUCT rules and regulations; however, this concentration increases the risk that a default could have a material effect on cash flows.

Our net exposure to credit risk associated with trade accounts and other receivables from affiliates was zero at both March 31, 2020 and December 31, 2019.

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DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE

The names of our directors and information about them, as furnished by the directors themselves, are set forth below:

Name	Age	Business Experience and Qualifications
James R. Adams	81	James R. Adams has served as a member of our board of directors since July 2015. He served as Chairman of our board of directors from July 2015 to the closing of the Sempra Acquisition in March 2018. Mr. Adams has served as a business consultant, business advisor and private investor since 1998. He previously served from 1996 to 1998 as the Chairman of Texas Instruments Incorporated, a NASDAQ-listed, global Fortune 500 semiconductor company. Prior to 1996, Mr. Adams had an extensive career in the telecommunications industry, serving in various leadership positions with SBC Communications (now AT&T Inc.) and its affiliates and predecessors from 1965 until his retirement in 1995, including serving as Group President of SBC Communications Inc. from 1993 to 1995, President and CEO of Southwestern Bell Telephone Company from 1989 to 1993, President of the Texas division of Southwestern Bell from 1984 to 1989, and Executive Vice President of AT&T Residence Business from 1981 to 1984. Mr. Adams currently serves as a senior advisor to Texas Next Capital, a private equity partnership that invests in Texas businesses to drive economic growth in Texas. He also serves on the boards of directors of TransPecos Financial Corp. and several non-profit organizations, including serving as Chairman of University Health System, a county government-owned public district hospital for the San Antonio, Texas metropolitan area. He previously served as a board member of Texas Instruments Inc. from 1989 to 2010, and as a board member of Storage Tek Inc., Inet Inc., Prodigy Inc., Telefonos de Mexico, Republic Bank Corporation, and Interfirst Corporation. We believe Mr. Adam’s extensive leadership, business, and board experience bring great value to our company and our board of directors. Mr. Adams’s decades of board service for various public and private companies, including over 20 years of board experience with Texas Instruments, two of which as Chairman, provides our board of directors with a unique understanding of corporate governance. In addition, Mr. Adams’s 30 years of experience at SBC Communications brings significant management expertise to our board of directors. His roles at SBC Communications also provided him with a great deal of experience in the regulated telecommunications industry, and we believe that regulatory experience is of great value to our regulated transmission and distribution company.
Thomas M. Dunning (3)	77	Thomas M. Dunning has served as a member of our board of directors since October 2007 and in July 2010 was elected Lead Independent Director by our board of directors. Since his retirement in 2008 as Chairman of Lockton Dunning Benefits, a company specializing in the design and servicing of employee benefits, he has served as Chairman Emeritus. Mr. Dunning also served as Chairman and Chief Executive Officer of Lockton Dunning Benefit Company, its predecessor company, from 1998 to 2007 following the 1998 acquisition of Dunning Benefits Corporation by the Lockton Group of Companies. Mr. Dunning currently serves on the boards of directors of Oncor Holdings, and a number of non-profit organizations. He is also a former Chairman of Dallas Fort Worth International Airport board and a former director of the Southwestern Medical Foundation, as well as a former director of American Beacon Funds. We believe Mr. Dunning’s experience with employee benefit programs and his understanding of employee benefits as part of an overall employee compensation program is important to Oncor in his roles as a director and member of the Organization and Compensation Committee (O&C Committee). As member and former chair of the O&C Committee, overseeing the design and effectiveness of Oncor’s executive compensation programs, Mr. Dunning offers broad experience in understanding and addressing compensation-related issues and challenges. His past appointments by Texas Governors as Chairman of the Texas Water Development Board and a director on the boards of the Texas Department of Transportation, Texas Department of Human Services and Texas Department of Criminal Justice, as well as his past service as Chairman of the Dallas/Fort Worth International Airport board, add to the extensive experience and leadership skills Mr. Dunning provides to our board. His experience and familiarity with Texas government, combined with over 50 years of experience in business and strong record of civic involvement in Texas, are valuable to our Texas-based business.

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Name	Age	Business Experience and Qualifications
Robert A. Estrada (1)	73	Robert A. Estrada has served as a member of our board of directors since October 2007. Mr. Estrada is Chief Compliance Officer, Senior Managing Director and Chairman Emeritus of Estrada Hinojosa & Company, Inc., an investment banking firm specializing in public finance that he co-founded in 1992. In addition to these positions, he also previously served as Chairman of the Board and as President and Chief Executive Officer of the firm. Since its inception, Estrada Hinojosa & Company, Inc. has been involved in municipal bond underwritings totaling over $80 billion and has provided financial advisory services on financings totaling more than $50 billion. Mr. Estrada is a member of the boards of directors of Oncor Holdings and several civic and arts organization boards. From 2001 until 2008, Mr. Estrada served on the Board of Regents of the University of Texas System, a system with over 60,000 employees and a budget of approximately $14 billion, pursuant to an appointment by the Governor of Texas. While serving on the University of Texas System Board of Regents, Mr. Estrada chaired its audit, compliance and management review committee. From 2004 until 2010, he served two consecutive terms on the board of directors of the Federal Reserve Bank of Dallas. From 1990 to 1994, Mr. Estrada also served on the board of directors of the Student Loan Marketing Association (Sallie Mae), a $45 billion entity and was a member of the board’s executive committee. We believe Mr. Estrada’s skills and experience in the financial and legal sectors qualify him to serve as a director of Oncor and chair of the Audit Committee. We also believe his comprehensive understanding of financial, compliance and business matters pertinent to us and his experience in serving large clients and boards regarding these matters are significant assets to our board. Mr. Estrada also has over 30 years of legal experience as a securities attorney, giving him a familiarity with securities law issues and investor disclosure requirements relevant to our company.
Printice L. Gary (1)	73	Printice L. Gary has served as a member of our board of directors since February 2014. Mr. Gary is the founding partner of, and since its founding in 1991 has served as the chief executive officer of, Carleton Residential Properties, a real estate firm engaged in investing, developing, general contracting and asset management of properties throughout Texas and the Southwest. His prior business experience includes serving as a Texas division partner for multi-family development with Trammel Crow Residential from 1985 to 1991 and serving as the president of Centex Corporation’s homebuilding and mortgage banking subsidiary, Fox & Jacobs Homes, from 1978 to 1985. Mr. Gary also served on the board of directors of the National Equity Fund, Inc., a Chicago-based nonprofit tax credit syndicator and asset manager from 2012 to 2016. Mr. Gary currently serves on the board of directors of Preservation of Affordable Housing Inc. (Boston, Massachusetts) and the board of directors of Oncor Holdings. Mr. Gary has served on the governing bodies of various state entities pursuant to appointments by the Governor(s) of Texas, including the board of directors of the University of Texas Investment Management Company, a $27 billion endowment fund, from 2009 until 2013, the University of Texas System Board of Regents from 2007 until 2013, where he was chairman of the facilities planning and construction committee, the University of Texas System Board for Lease of University Lands from 2008 to 2013, the Texas State Tax Reform Commission in 2003, and the North Texas Tollway Authority board of directors from 1996 to 2000. We believe Mr. Gary’s extensive skills and experience in the business and financial sectors are a significant asset to us in his role both as a director of Oncor and as a member of the Audit Committee. In addition, Mr. Gary’s entrepreneurial background, founding Carleton Residential Properties, a residential real estate company active for more than 25 years across Oncor’s prime North Texas service territory brings valuable development and construction experiences to our board of directors. His experience with Texas government through his service on various state entities also brings great value to our Texas-based business.

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Name	Age	Business Experience and Qualifications
William T. Hill, Jr. (2)	77	William T. Hill, Jr. has served as a member of our board of directors since October 2007. Mr. Hill currently practices law with the law firm of William T. Hill, Jr., Attorney at Law, a firm he established in 2007. Until 2012, he was also of counsel to the Dallas criminal defense law firm of Fitzpatrick Hagood Smith & Uhl LLP. In 2007, he served as Director of Strategic Initiatives of Mercy Street Ministries. From 1999 to 2007, Mr. Hill was Criminal District Attorney of the Dallas County District Attorney’s office. Mr. Hill serves on the boards of directors of Hilltop Holdings, Incorporated, a New York Stock Exchange listed company in the insurance industry, Oncor Holdings and a number of charitable organizations and previously served on the board of directors of the Baylor Hospital Foundation. We believe Mr. Hill’s experience of over 50 years with legal and compliance matters, along with his management of a large group of highly skilled professionals, have given him considerable knowledge concerning many matters that come before our board of directors. In addition, as District Attorney he developed judgment and decision-making abilities that assist him today in evaluating and making decisions on issues that face our board of directors. Mr. Hill has also served on several civic and charitable boards, which has given him invaluable experience in corporate governance matters.
Timothy A. Mack (2)	67	Timothy A. Mack has served as a member of our board of directors since February 2014. Mr. Mack currently is of counsel to the Dallas, Texas law firm, Matheson & Marchesoni PLLC. Mr. Mack was a member of the Dallas, Texas law firm, Mack Matheson & Marchesoni PLLC, from March 2009 until his retirement in August 2017. Prior thereto, Mr. Mack was a partner at an international law firm, Hunton & Williams LLP (now known as Hunton Andrews Kurth LLP), and its predecessor firm in Dallas, Texas, where he had practiced law since 1980. Mr. Mack’s law practice focuses on energy-related matters, particularly finance, securities, corporate and partnership law, corporate governance and mergers and acquisitions. Mr. Mack is a member of the board of directors of Oncor Holdings and various local non-profit organizations. We believe Mr. Mack’s experience of over 30 years in advising energy companies in finance, securities, corporate governance and merger and acquisition matters, as well as his prior experience in participating in the management of a large international law firm, brings to the Board additional knowledge and valuable first-hand experience with the duties of directors.
Jeffrey W. Martin (3)	58	Jeffrey W. Martin has served as a member of our board of directors since the March 2018 closing of the Sempra Acquisition. Mr. Martin has served as Chief Executive Officer and a member of the board of directors of Sempra since May 1, 2018, and has served as Chairman of Sempra since December 1, 2018. Mr. Martin served as Executive Vice President and Chief Financial Officer of Sempra from January 2017 to April 30, 2018. Mr. Martin served at San Diego Gas & Electric Company (SDG&E), an indirect subsidiary of Sempra, as the Chief Executive Officer and a director beginning in January 2014. Continuing in those roles, Mr. Martin was also appointed as the President in October 2015 and as the Chairman in November 2015, serving in each of these roles through December 2016. From 2010 to 2013, Mr. Martin served as the President and Chief Executive Officer of Sempra U.S. Gas & Power (USGP), a business unit of Sempra, and USGP’s predecessor organization, Sempra Generation, and before that, served as the Vice President of Investor Relations for Sempra. Prior to joining Sempra in December 2004, Mr. Martin was chief financial officer of NewEnergy, Inc. He also formerly served as corporate counsel at UniSource Energy Corporation and was an attorney at the law firm of Snell & Wilmer, LLP. Mr. Martin is also a member of the board of directors of Oncor Holdings and is on the Business Roundtable and the board of trustees of the University of San Diego. He previously served on the boards of directors of the Edison Electric Institute, California Chamber of Commerce and National Association of Manufacturers. Mr. Martin was appointed by Sempra (through Oncor Holdings) as a member of our board of directors pursuant to Sempra’s indirect right under the Limited Liability Company Agreement to designate two directors. We believe Mr. Martin’s extensive financial, management and operations experience qualifies him to serve on our board of directors. In addition, his extensive knowledge and experience in utility and energy infrastructure matters brings great value to our board of directors and our company.

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Name	Age	Business Experience and Qualifications
Trevor I. Mihalik (1) (2)	53	Mr. Mihalik has served as a member of our board of directors since March 2020. Mr. Mihalik is Executive Vice President and Chief Financial Officer of Sempra, a role he has held since May 2018. Prior to that role, he served as Sempra’s Senior Vice President from December 2013 until April 2018 and as its Controller and Chief Accounting Officer from July 2012 until April 2018. Prior to joining Sempra, he served as Senior Vice President of Finance for Iberdrola Renewables, the U.S. subsidiary of Iberdrola S.A., a multinational utility and energy company headquartered in Bilbao, Spain. Prior to that, he was Vice President of Finance for Chevron Natural Gas and also served as its Vice President of Finance and Chief Financial Officer for their natural gas marketing, trading and storage joint venture, Bridgeline Holdings. Mr. Mihalik spent the first nine years of his career working in Houston and London in the energy practice of Price Waterhouse. Since December 2019 he has served on the board of directors of WD-40 Company, a Nasdaq listed global marketing organization that develops and sells maintenance, homecare and cleaning products, and since 2017 he has served on the board of directors of San Diego Gas and Electric Company and Southern California Gas Company, both of which are indirect subsidiaries of Sempra. He is also on the advisory board for the University of San Diego’s School of Business Administration. Mr. Mihalik was appointed by Sempra (through Oncor Holdings) as a member of our board of directors pursuant to Sempra’s indirect right under the Limited Liability Company Agreement to designate two directors. We believe Mr. Mihalik’s significant financial, business, and management experience qualifies him to serve on our board of directors. His extensive experience in the utility and energy industries in particular brings substantial benefits to our board of directors.
Helen Newell (1)	52	Ms. Newell has served as a member of our board of directors since July 2019. Ms. Newell has served as a Senior Vice President - Infrastructure for GIC Special Investments Pte Ltd (GIC) focused on asset management in the Americas since October 2018. Ms. Newell has over 20 years of experience in operations and corporate roles in the infrastructure, transportation and mining sectors. Before joining GIC, Ms. Newell held various roles at Rio Tinto PLC and Rio Tinto Limited, a global diversified mining company listed on the London Stock Exchange and Australian Securities Exchange, serving as Global Head of Risk from 2014 until 2018 and Vice President - Infrastructure from 2011 until 2014. Prior to joining Rio Tinto, Ms. Newell worked for several Australian listed transportation and infrastructure companies. Ms. Newell began her career in management consulting, working on various transportation and telecommunications projects in Australia, Asia and North America. Ms. Newell currently serves on the board of directors of Duquesne Holdings, LLC, Duquesne Light Holdings Inc., Duquesne Light Company, ABP (Jersey) Limited, ABPA Holdings Limited, Associated British Ports Holdings Limited, WaterBridge Resources LLC, and Genesee & Wyoming Inc. Ms. Newell was appointed as a member of our board of directors by Texas Transmission pursuant to Texas Transmission’s right under our Limited Liability Company Agreement to designate two directors. We believe Ms. Newell’s extensive business, operations and management experience qualifies her to serve on our board of directors. In addition, her extensive knowledge and experience in infrastructure matters brings great value to our board of directors and our company.

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Name	Age	Business Experience and Qualifications
E. Allen Nye, Jr.	52	E. Allen Nye, Jr. has served as a member of our board of directors and our Chief Executive since the March 2018 closing of the Sempra Acquisition. From January 2011 until March 2018, Mr. Nye served as our Senior Vice President, General Counsel and Secretary, and in such role was responsible for overseeing all of Oncor’s legal and compliance matters. In January 2013, his responsibilities were expanded to include oversight of all regulatory and governmental affairs activity of Oncor. From June 2008 until joining Oncor, Mr. Nye practiced law as a partner in the Dallas office of Vinson & Elkins LLP, where he focused on representation of regulated energy companies before state and federal government agencies, including the PUCT, the State Office of Administrative Hearings and the FERC. Prior to Vinson & Elkins, Mr. Nye was a partner in the law firm of Hunton & Williams LLP (now known as Hunton Andrews Kurth LLP) from January 2002 until May 2008. Mr. Nye is a member of the board of directors of Oncor Holdings and since January 2019, also serves as a member of the board of directors of Infraestructura Energética Nova, S.A.B. de C.V., an entity indirectly majority-owned by Sempra that develops, builds and operates energy infrastructure in Mexico and is listed on the Mexican Stock Exchange. As our Chief Executive, Mr. Nye brings his unique knowledge of our company and our industry to the board of directors. His prior experience as Senior Vice President, General Counsel and Secretary of Oncor and vast experience in the energy industry and first-hand knowledge of and experience with state and federal government and regulatory agencies brings great value and benefit to our board of directors and company. Mr. Nye’s previous experience as Senior Vice President, General Counsel and Secretary of Oncor also brings to the board additional knowledge and valuable first-hand experience with the duties of directors and governance matters.
Robert S. Shapard	64	Robert S. Shapard has served as a member of our board of directors since April 2007. He has served as Chairman of our board of directors since the March 2018 closing of the Sempra Acquisition and before that, served as Chairman from April 2007 until July 2015. From April 2007 until the March 2018 closing of the Sempra Acquisition, he also served as Chief Executive of Oncor. Mr. Shapard joined EFH Corp.’s predecessor in October 2005 as a strategic advisor, helping implement and execute growth and development strategies for Oncor. Between March and October 2005, he served as Chief Financial Officer of Tenet Healthcare Corporation, one of the largest for-profit hospital groups in the United States, and was Executive Vice President and Chief Financial Officer of Exelon Corporation, a large electricity generator and utility operator, from 2002 to February 2005. Before joining Exelon, he was executive vice president and chief financial officer of Ultramar Diamond Shamrock, a North American refining and marketing company, since 2000. Previously, from 1998 to 2000, Mr. Shapard was CEO and managing director of TXU Australia Pty. Ltd., a subsidiary of the former TXU Corp., which owned and operated electric generation, wholesale trading, retail, and electric and gas regulated utility businesses. Mr. Shapard has served since September 2013 as a member of the board of directors of Leidos Holdings, Inc. (formerly SAIC, Inc.), a New York Stock Exchange-listed provider of scientific, engineering and systems integration service, and currently serves as lead director as well as chair of the governance and ethics committee and as a member of the audit and finance committee. Mr. Shapard is also a director of Oncor Holdings. As our former Chief Executive, Mr. Shapard brings his unique knowledge of our company and our industry to the board of directors. His prior experience with EFH Corp., Exelon and as CEO of TXU Australia gives him extensive leadership experience in the electric industry in both regulated and unregulated markets. Mr. Shapard’s previous experience as chief financial officer of Tenet Healthcare Corporation and Ultramar Diamond Shamrock provided him with substantial experience in other complex financial and business environments.

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Name	Age	Business Experience and Qualifications
Richard W. Wortham III (2) (3)	81	Richard W. Wortham III has served as a member of our board of directors since October 2007. Since 1976, he has served as Trustee of The Wortham Foundation, Inc., a private philanthropic foundation with assets of approximately $280 million dedicated to the support and development of Houston’s cultural fabric. Mr. Wortham has held various offices at The Wortham Foundation, Inc., currently serving as the President, a position he has held since November 2018, and previously serving as the Chairman from November 2014 until November 2018, the President from 2011 until November 2014, the Secretary and Treasurer from 2008 until 2011 and the Chairman and the Chief Executive Officer from 2005 until 2008. Mr. Wortham also serves as a Trustee and member of the audit committee of HC Capital Trust, a $14 billion family of mutual funds, and a Life Trustee of The Museum of Fine Arts, Houston. Mr. Wortham is also a director of Oncor Holdings. Additionally, Mr. Wortham has held a leadership role in several companies, including a founding role in several national banks. We believe Mr. Wortham’s over 30 years of extensive business and civic experience qualify him to serve on our board of directors and chair our O&C Committee. Mr. Wortham also currently serves on the executive, finance, audit and investment committees of the Museum of Fine Arts, Houston, which presently has an endowment of approximately $1 billion. Mr. Wortham’s experience has given him substantial and significant knowledge and experience regarding financial management and corporate governance matters relevant to our board of directors.
Steven J. Zucchet (2) (3)	54	Steven J. Zucchet has served as a member of our board of directors since November 2008. Mr. Zucchet is a Managing Director of OMERS Infrastructure Management Inc. (OMERS Infrastructure) (formerly Borealis Infrastructure Management, Inc.), an investment arm of Canada’s OMERS pension plan, a position he has held since September 2014, having previously served as a Senior Vice President of OMERS Infrastructure from November 2003 until September 2014. From 1996 until joining OMERS Infrastructure, Mr. Zucchet served as Chief Operating Officer of Enwave Energy Ltd., where he was responsible for operations and major infrastructure projects. In his role as an officer of OMERS Infrastructure, Mr. Zucchet has also been appointed as an officer and director of several OMERS Infrastructure affiliates and companies in which OMERS Infrastructure invests. Through OMERS Infrastructure, Mr. Zucchet has served since April 2019 on the boards of directors of Puget Energy, Inc. and Puget Sound Energy, Inc., a regulated gas and electric utility in the State of Washington, and also currently serves on the board of directors of Bruce Power, an eight reactor nuclear site located in Ontario, Canada. His focus at OMERS Infrastructure is in the energy sector, where he has led the pursuit of investment opportunities in the energy sector and is currently responsible for leading the asset management of several of its portfolio investments. Mr. Zucchet was appointed as a member of our board of directors by Texas Transmission pursuant to Texas Transmission’s right under the Limited Liability Company Agreement to designate two directors. We believe Mr. Zucchet’s extensive experience in the energy industry gives him an important and valuable understanding of our business, and that experience, along with his business, management and operations experience, qualifies him to serve on our board of directors.

(1) Member of Audit Committee.

(2) Member of Nominating and Governance Committee.

(3) Member of Organization & Compensation Committee.

Director Appointments

As of March 9, 2018, pursuant to our Limited Liability Company Agreement (which was amended and restated in connection with the Sempra Acquisition) and the Sempra Order, the board of directors is required to consist of thirteen members, constituted as follows:

• seven Disinterested Directors, who (i) shall be independent directors in all material respects under the rules of the New York Stock Exchange in relation to Sempra or its subsidiaries and affiliated entities and any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, and (ii) shall have no material relationship with Sempra or its subsidiaries or affiliated entities or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, currently or within the previous ten years;

• two members designated by Sempra (through Oncor Holdings);

• two members designated by Texas Transmission; and

• two Oncor Officer Directors.

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Mr. Martin and Mr. Mihalik were each designated to serve on our board of directors by Sempra (through Oncor Holdings) and Ms. Newell and Mr. Zucchet were each designated to serve on our board of directors by Texas Transmission. Directors designated by Sempra and Texas Transmission are referred to as member directors.

Our Limited Liability Company Agreement provides that seven of our directors will be Disinterested Directors under the standards set forth in our Limited Liability Company Agreement. See “Certain Relationships and Related Transactions, and Director Independence — Director Independence” for a discussion of the director qualifications. We have determined that Messrs. Adams, Dunning, Estrada, Gary, Hill, Mack and Wortham are Disinterested Directors. Disinterested Directors are appointed by the nominating committee of Oncor Holdings’ board of directors subject to the approval by a majority of the Disinterested Directors of Oncor Holdings’ board of directors. The nominating committee of Oncor Holdings is required to consist solely of Disinterested Directors. The Sempra Order and our Limited Liability Company Agreement provide that the current Disinterested Directors of Oncor will serve, if willing and able, for a term of three years from the closing of the Sempra Acquisition (subject to continuing to meet the disinterested director requirements). Thereafter, two of these directors will roll off of the board every two years, with the nominating committee of Oncor Holdings (subject to approval by a majority of the Disinterested Directors of the Oncor Holdings board of directors) determining the order of departure of these directors. Each new Disinterested Director will have a term of four years and the appointment of such directors will be consistent with the mandatory retirement age of 75, with each Disinterested Director’s term being able to be renewed for only one additional term of four years. To the extent any Disinterested Director is removed, retires or is otherwise unable to or unwilling to serve, a replacement new Disinterested Director will be chosen by the nominating committee of Oncor Holdings and subject to approval by a majority vote of the Disinterested Directors of Oncor Holdings’ board of directors. Any change to the size, composition, structure or rights of the boards must first be approved by the PUCT.

Oncor Holdings, at the direction of STIH (a subsidiary of STH, which is a wholly owned, indirect subsidiary of, and controlled by, Sempra following the Sempra Acquisition), has the right, pursuant to the terms of our Limited Liability Company Agreement, to nominate two directors that are current or former officers of Oncor, subject to approval of any such nomination by a majority of the Oncor board of directors. Mr. Shapard and Mr. Nye serve as these directors. Our Limited Liability Company Agreement provides that until March 9, 2028, to be eligible to serve as an Oncor Officer Director, a current and/or former Oncor officer cannot have worked for Sempra or any of its affiliates (other than Oncor or Oncor Holdings) or any such entity’s affiliates, or any other direct or indirect beneficial owner of Oncor in the ten years prior to commencement of such officer’s employment with Oncor.

Audit Committee

The Audit Committee is a separately-designated standing audit committee, established in accordance with section 3(a)(58)(A) of the Securities Exchange Act of 1934, as amended. Our Audit Committee is composed of Messrs. Estrada, Gary, Mihalik and Ms. Newell. Our board of directors has determined that each of Messrs. Estrada and Gary is an “audit committee financial expert” as defined in Item 407(d)(5) of Regulation S-K. Messrs. Estrada and Gary are Disinterested Directors under the standards set forth in our Limited Liability Company Agreement. See “Certain Relationships and Related Transactions, and Director Independence – Director Independence” for a description of the requirements to be deemed disinterested.

Mr. Mihalik is a member director designated by Sempra (through Oncor Holdings) and Ms. Newell is a member director designated by Texas Transmission.

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Executive Officers

The names of our executive officers and information about them, as furnished by the executive officers themselves, are set forth below:

Name	Age	Positions and Offices Presently Held	Business Experience (Preceding Five Years)
E. Allen Nye, Jr.	52	Chief Executive and Director	E. Allen Nye, Jr. has served as a member of our board of directors and our Chief Executive since the March 2018 closing of the Sempra Acquisition. From January 2011 until March 2018, Mr. Nye served as our Senior Vice President, General Counsel and Secretary, and in such role was responsible for overseeing all of Oncor’s legal and compliance matters. In January 2013, his responsibilities were expanded to include oversight of all regulatory and governmental affairs activity of Oncor. From June 2008 until joining Oncor, Mr. Nye practiced law as a partner in the Dallas office of Vinson & Elkins LLP, where he focused on representation of regulated energy companies before state and federal government agencies, including the PUCT, the State Office of Administrative Hearings and the FERC. Prior to Vinson & Elkins, Mr. Nye was a partner in the law firm of Hunton & Williams LLP (now known as Hunton Andrews Kurth LLP) from January 2002 until May 2008. Mr. Nye is a member of the board of directors of Oncor Holdings and since January 2019, also serves as a member of the board of directors of Infraestructura Energética Nova, S.A.B. de C.V., an entity indirectly majority-owned by Sempra that develops, builds and operates energy infrastructure in Mexico and is listed on the Mexican Stock Exchange.
Joel S. Austin	56	Senior Vice President and Chief Digital Officer	Joel S. Austin has served as our Senior Vice President since the March 2018 closing of the Sempra Acquisition and as our Chief Digital Officer since February 2019. From May 2010 until March 2018, he served as our Vice President and Chief Information Officer. In his role as Senior Vice President and Chief Digital Officer, Mr. Austin oversees activities including market relations, customer engagement, measurement and billing, as well as the information technology function. He joined Oncor in 2008 and has held a leadership position in the information technology function since that time. Prior to joining Oncor in 2008, Mr. Austin served in a number of positions within EFH Corp. and EFH Corp.’s predecessor, including roles in information technology, operations, sourcing management and business development since 1990. Mr. Austin has extensive experience in technology, management consulting, operations, cybersecurity, and global delivery management.
Walter Mark Carpenter	68	Senior Vice President, T&D Operations	Walter Mark Carpenter has served as our Senior Vice President, T&D Operations since October 2011, and in such role is responsible for overseeing transmission grid management operations and Oncor’s interface with ERCOT. Mr. Carpenter also oversees Oncor’s distribution operation centers, as well as Oncor’s distribution management and transmission management systems supporting such operations, and, since March 2018, he has been responsible for Oncor’s environmental and NERC compliance activities. From February 2010 until October 2011 he served as our Vice President and Chief Technology Officer, and from 2008 until February 2010 he served as our Vice President and Chief Information Officer. Mr. Carpenter has served EFH Corp’s predecessor and Oncor for over 40 years and has held various field management and engineering management positions in transmission and distribution. Mr. Carpenter is a registered Professional Engineer in the State of Texas and is a member of the Institute of Electrical and Electronic Engineers Power System Relaying Committee and the Texas Society of Professional Engineers.

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Name	Age	Positions and Offices Presently Held	Business Experience (Preceding Five Years)
Don J. Clevenger	49	Senior Vice President and Chief Financial Officer	Don J. Clevenger has served as our Senior Vice President and Chief Financial Officer since the March 2018 closing of the Sempra Acquisition. From January 2013 until March 2018, he served as our Senior Vice President, Strategic Planning. From February 2010 through December 2012, he served as our Senior Vice President, External Affairs and before that, served as our Vice President, External Affairs from June 2008 until February 2010. Mr. Clevenger also served as our Vice President, Legal and Corporate Secretary from December 2007 to June 2008. Between November 2005 and December 2007, Mr. Clevenger held a leadership position in our company with various legal and regulatory responsibilities. Prior to his transfer to Oncor in November 2005, he was Senior Counsel of the Business Services unit of EFH Corp. since April 2004. Mr. Clevenger was a partner in the law firm of Hunton & Williams LLP (now known as Hunton Andrews Kurth LLP) before he joined EFH Corp.’s predecessor.
Deborah L. Dennis	66	Senior Vice President, Chief Customer Officer and Chief HR Officer	Deborah L. Dennis has served as our Senior Vice President since January 2013, as our Chief Customer Officer since the March 2018 closing of the Sempra Acquisition, and as our Chief HR Officer since February 2020. From January 2013 until February 2020, she also held the title of Senior Vice President, Human Resources & Corporate Affairs. In her role, Ms. Dennis oversees activities including customer service, community relations, economic development initiatives, human resources and corporate affairs. Ms. Dennis has been employed with Oncor and its predecessors and affiliates for over 40 years in a number of corporate and customer service functions, including 13 years as a Vice President, most recently serving as Vice President of Corporate Affairs from 2011 to December 2012, and Vice President—Dallas Customer Operations from 2007 to 2011. Ms. Dennis has extensive experience in customer services, human resources, supply chain, outsourcing management and corporate philanthropy.
James A. Greer	59	Executive Vice President and Chief Operating Officer	James A. Greer has served as our Executive Vice President since the March 2018 closing of the Sempra Acquisition and as Chief Operating Officer since October 2011. Mr. Greer previously served as our Senior Vice President and Chief Operating Officer from October 2011 until March 2018. From October 2007 until October 2011, he served as our Senior Vice President, Asset Management and Engineering and in such role was responsible for the development of strategies, policies and plans for optimizing the value and performance of electric delivery systems and related assets. From 2004 to 2007, Mr. Greer served a similar role as our Vice President. Since joining EFH Corp.’s predecessor in 1984, Mr. Greer has held a number of leadership positions within Oncor and EFH Corp. in such areas as engineering, operations and governmental relations. Mr. Greer is a registered Professional Engineer in the State of Texas.
Angela Y. Guillory	50	Senior Vice President, Human Resources & Corporate Affairs	Angela Y. Guillory has served as our Senior Vice President, Human Resources & Corporate Affairs since February 2020. In her role as Senior Vice President, Human Resources & Corporate Affairs, Ms. Guillory is responsible for Oncor’s human resource and corporate affairs functions, a role she performed as Vice President, Human Resources & Corporate Affairs, from March 2018 until February 2020. From November 2013 to March 2018, Ms. Guillory was Vice President, Customer and Market Operations where she led Oncor’s customer and market relations functions. Ms. Guillory has been employed with Oncor and its predecessor and affiliates for 26 years with experience in engineering, distribution operations, rates and regulatory, customer experience, and customer and market operations.

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Name	Age	Positions and Offices Presently Held	Business Experience (Preceding Five Years)
Matthew C. Henry	51	Senior Vice President, General Counsel & Secretary	Matthew C. Henry has served as our Senior Vice President, General Counsel and Secretary since the March 2018 closing of the Sempra Acquisition, and in such role is responsible for overseeing all of Oncor’s legal and compliance matters as well as its regulatory and governmental affairs activity. From June 2008 until joining Oncor in March 2018, Mr. Henry practiced law as a partner in the Dallas office of Vinson & Elkins LLP, where he led the firm’s energy regulatory practice and focused on representation of regulated energy companies before state and federal government agencies, including the PUCT, the State Office of Administrative Hearings and the FERC. Prior to joining Vinson & Elkins, Mr. Henry was a partner in the law firm of Hunton & Williams LLP (now known as Hunton Andrews Kurth LLP) from January 2002 until May 2008.
Malia Hodges	42	Senior Vice President and Chief Information Officer	Malia Hodges has served as our Senior Vice President since February 2020 and as our Chief Information Officer since March 2018, and in such role is responsible for Oncor’s information technology function. Ms. Hodges previously served a similar role as our Vice President and Chief Information Officer from March 2018 until February 2020. From January 2014 to March 2018, Ms. Hodges served as Director, Technology Program Management Office and in such role was responsible for the strategic execution of Oncor’s information technology investment portfolio and organizational change management activities. Prior to joining Oncor in 2014, Ms. Hodges was a management consultant at Sendero Business Services, L.P., where she advised clients, including Oncor, on the implementation of various strategic technology and customer engagement initiatives. Ms. Hodges has experience in technology, management consulting, organizational design and change management, global delivery management, business process design and operations.

There is no family relationship between any of our executive officers, between any of our directors, or between any executive officer and any director.

Code of Conduct

We maintain certain corporate governance documents on our website at www.oncor.com. Our Code of Conduct can be accessed by selecting “Corporate Governance” in the “Investor Relations” portion of the website. Our Code of Conduct applies to all of our employees and officers, including our Chief Executive, Chief Operating Officer, Chief Financial Officer and Controller, and it also applies to our directors, except for provisions pertinent only to employees. Any amendments to our Code of Conduct will be posted on our website promptly. Printed copies of the corporate governance documents that are posted on our website are available to any person without charge upon written request to the Corporate Secretary of Oncor Electric Delivery Company LLC at 1616 Woodall Rodgers Freeway, Suite 7E-002, Dallas, Texas 75202-1234.

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EXECUTIVE COMPENSATION

Compensation Discussion and Analysis

Overview

In this Compensation Discussion and Analysis, we describe our executive compensation philosophy and the elements of our executive compensation program. We also discuss how the executive officers named in the Summary Compensation table (our Named Executive Officers) were compensated in 2019. In 2019, our Named Executive Officers, as well as their current titles, were:

Name	Title
E. Allen Nye, Jr.	Chief Executive
Don J. Clevenger	Senior Vice President and Chief Financial Officer
Deborah L. Dennis	Senior Vice President, Chief Customer Officer and Chief HR Officer(1)
James A. Greer	Executive Vice President and Chief Operating Officer
Matthew C. Henry	Senior Vice President, General Counsel and Secretary

(1) Ms. Dennis became Senior Vice President, Chief Customer Officer and Chief HR Officer in February 2020. Until then, she served as Senior Vice President, Human Resources & Corporate Affairs, and Chief Customer Officer.

Role of the Organization and Compensation Committee

Our board of directors has designated an Organization and Compensation Committee of the board of directors (O&C Committee) to establish, administer, and assess our executive compensation policies, which include participation in various employee benefit programs. The O&C Committee met three times in 2019.

The responsibilities of the O&C Committee include:

• Determining and overseeing executive compensation programs, including making recommendations to our board of directors, when and if its approval is required, with respect to the adoption, amendment or termination of incentive compensation, equity-based and other executive compensation and benefit plans, policies and practices;

• Establishing, reviewing and approving corporate goals and objectives relevant to executive compensation, evaluating the performance of our Chief Executive (CEO) and other executive officers in light of those goals and objectives and ultimately approving executive compensation based on those evaluations; and

• Advising our board of directors with respect to compensation of its disinterested directors and non-executive chairman of the board of directors.

The O&C Committee conducts reviews of the level of individual compensation elements as well as total direct compensation for our executive officers, from time to time as it deems appropriate. The O&C Committee conducted such compensation reviews in the fourth quarter of 2019. In determining the total direct compensation of our executive officers, the O&C Committee considers the performance and responsibilities of the executives and a competitive market and peer group analysis of executive compensation provided by compensation consultants engaged by the O&C Committee. The O&C Committee obtains the input of the CEO on the performance of executive officers other than the CEO. The CEO assesses the performance of each executive in light of the executive’s business unit and function and presents a performance evaluation and compensation recommendation for each of these individuals to the O&C Committee. The CEO also reviews and considers the competitive market analysis in making his recommendation. The O&C Committee also evaluates the CEO’s performance. The O&C Committee determines total compensation, including base salary, annual incentive awards and long-term incentive awards, for each of our executive officers as it deems appropriate.

In the first quarter of each fiscal year, the O&C Committee (1) approves corporate goals and objectives under our annual and long-term incentive programs for our executive officers for awards for the current fiscal year, and (2) certifies the

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performance results for incentive payments for performance periods that ended on December 31 of the previous fiscal year. Following the completion of each fiscal year, in connection with the annual determination of the incentive awards to be paid to our executive officers other than the CEO, the CEO conducts an annual performance review of each executive officer and evaluates each executive’s performance relative to the corporate goals and objectives for the completed fiscal year set by the O&C Committee. The CEO then makes recommendations to the O&C Committee with respect to other executive officers’ annual incentive compensation. The O&C Committee also annually evaluates the CEO’s performance in light of the goals and objectives for the previous fiscal year. After considering this evaluation, as well as the CEO’s recommendations, the O&C Committee determines the annual incentive award payouts for all of our executive officers, as well as goals and objectives under the annual and long-term incentive programs for the current fiscal year. In the first quarter of 2019, the O&C Committee also revised the payout methodologies under the executive annual and long-term incentive programs following a review of those programs that included a peer group analysis.

Compensation Philosophy

Our compensation philosophy, principles and practices are intended to compensate executives appropriately for their contribution to the attainment of key strategic objectives, and to strongly align the interests of executives and equity holders through both short and long-term performance goals. We believe that:

• Levels of executive compensation should be based upon an evaluation of the performance of our business (through operational metrics including safety, reliability, operational efficiency and infrastructure readiness and financial performance) and individual executives, as well as a comparison to compensation levels of persons with comparable responsibilities in business enterprises of similar size, scale, complexity, risk and performance;

• Compensation plans should balance both short-term and long-term objectives; and

• The overall compensation program should emphasize variable compensation elements that have a direct link to company and individual performance.

Objectives of Compensation Philosophy

Our compensation philosophy is designed to meet the following objectives:

• Attracting and retaining high performers;

• Rewarding company and individual performance by providing compensation levels consistent with the level of contribution and degree of accountability;

• Aligning performance measures with our goals and allocating a significant portion of the compensation to incentive compensation in order to drive the performance of our business;

• Basing incentive compensation in part on the satisfaction of company operational metrics (including safety, reliability, operational efficiency and infrastructure readiness) with the goal of motivating performance towards improving the services we provide our customers; and

• Creating value for our equity holders and promoting the long-term performance of the company by strengthening the correlation between the long-term interests of our executives and the interests of our ultimate equity holders.

Elements of Compensation

In an effort to achieve our compensation objectives, we have established a compensation program for our executives that principally consists of:

• Base salary;

• Short-term incentives through the opportunity to earn an annual performance bonus pursuant to the Oncor Electric Delivery Company LLC Sixth Amended and Restated Executive Annual Incentive Plan (Executive Annual Incentive Plan);

• Long-term incentives through awards under Oncor’s long-term incentive plan (Long-Term Incentive Plan);

• Deferred compensation and retirement plans through (1) the opportunity to participate in a 401(k) savings plan (thrift plan) and a salary deferral program (Salary Deferral Program) and receive certain company matching contributions, (2) the opportunity to participate in a defined benefit retirement plan and a supplemental retirement plan, and (3) an employer-paid subsidy for health coverage upon the executive’s retirement from Oncor for executives hired prior to January 1, 2002;

• Perquisites and other benefits, including, for executives hired prior to January 1, 2004, the opportunity to participate in the Oncor Split-Dollar Life Insurance Program (Split Dollar Life Insurance Plan);

• Contingent payments through an executive change of control policy and an executive severance plan; and

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• In certain instances, performance bonus and retention agreements.

For more information about the incentive and other benefit plans available to our executives see “—Compensation Elements” below and the compensation tables and the accompanying narratives immediately following this “Compensation Discussion and Analysis.”

Compensation Consultants

PricewaterhouseCoopers LLP, a compensation consultant, has been engaged by the O&C Committee since 2014 to advise and report to the O&C Committee on executive compensation issues. In February 2019, we engaged PricewaterhouseCoopers to perform a peer group analysis of annual and long-term incentive compensation. In October 2019, the O&C Committee engaged PricewaterhouseCoopers to advise and report on executive and independent director compensation, including a competitive market analysis and peer group study, as discussed in more detail under “-Market Data” below. PricewaterhouseCoopers and its affiliates also provide consulting and related services to Oncor with respect to human resources, tax, internal audit, industry intelligence, strategy formulation and other matters. Oncor purchases compensation surveys (both executive and non-executive) from Willis Towers Watson who, from time to time, provides consulting and other services to Oncor’s human resources department.

Market Data

While we try to ensure that the greater part of an executive officer’s compensation is directly linked to the executive’s individual performance and Oncor’s financial and operational performance, we also seek to set our executive compensation program in a manner that is competitive with that of our peer group and industry compensation survey data in order to promote retention of key personnel and to attract high-performing executives from outside our company.

2018 Survey and Peer Group

In the fourth quarter of 2018, the O&C Committee assessed total compensation of our executives against a number of companies in the transmission/distribution industry and fully integrated utilities using both survey data and peer group comparisons. For purposes of the 2018 assessment, PricewaterhouseCoopers completed a competitive market analysis of executive compensation for the O&C Committee in October 2018. This analysis involved a review of U.S. energy utility industry compensation survey data using our 2017 annual revenues. The survey data was compared to our executive compensation elements targeted at both the 50^th and 75^th percentiles with respect to base salary, target cash annual incentives, and long-term incentives, and the resulting target total cash compensation (base salary and target cash annual incentives) and total direct compensation (base salary, target cash annual incentives and long-term incentives). The survey data was aged from the reporting date to January 1, 2019, using an annual rate of 3.0%, which is the projected increase factor for 2018 for officers and executives based on the World at Work 2018 Salary Budget Survey.

In addition to the market data for utilities in the national marketplace, PricewaterhouseCoopers also provided publicly available data for a subset of these utilities, a peer group of transmission/distribution utility companies as well as fully integrated utility companies. Oncor’s size, based on revenues, is in the 49th percentile of this peer group. PricewaterhouseCoopers provided information on total target direct compensation, base salary, annual incentive targets and long-term incentives with respect to the five highest paid executives at each of those companies, along with comparisons of each such executive to the comparable Oncor executive using regression analysis based on Oncor’s revenue size. The primary peer group consisted of 16 companies, 12 of which were used in PricewaterhouseCoopers’ 2017 study:

Ameren Corp.	CMS Energy Corp.	OGE Energy Corp.
American Electric Power Co., Inc.	Consolidated Edison, Inc.	Pinnacle West Capital
Alliant Energy	El Paso Electric Co.	Portland General Electric Co.
Avangrid Inc.	Eversource Energy	SCANA Corp.
CenterPoint Energy, Inc.	IdaCorp Inc.
Cleco Power LLC	ITC Holdings Corp.

PricewaterhouseCoopers recommended including four new peer companies in addition to the 12 companies that were considered in the 2017 analysis: Ameren Corp., Avangrid Inc., CMS Energy Corp., and SCANA Corp. The addition of these new peers would more closely align Oncor’s revenue size to the 50^th percentile versus its 64^th percentile positioning in the 2017 peer group, as well as increase the sample size of the peer group from 12 to 16. Based on PricewaterhouseCoopers’ analysis and recommendation, the O&C Committee agreed to include the additional companies in the 2018 analysis.

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The O&C Committee considered both peer group data and the 2018 competitive market survey data, along with individual performance and responsibilities, when determining total direct executive compensation, as well as each element of total direct compensation (base salary, annual incentives and long-term incentives). The O&C Committee targeted total direct compensation, including target payouts under annual and long-term incentive awards, at approximately the 50th percentile of the 2018 competitive market survey group. The 2018 competitive market analysis indicated that the aggregate target total direct compensation of our executives was generally below the 50^th percentile of the competitive market survey group. As a result of its review of the PricewaterhouseCoopers studies and each executive’s individual performance and responsibilities, the O&C Committee increased the base salaries of all Named Executive Officers, including our CEO, effective November 26, 2018.

February 2019 Incentive Compensation Peer Group Analysis

In February 2019, the O&C Committee assessed the payout methodologies under our annual and long-term incentive plans. In the course of that review, they considered data provided by PricewaterhouseCoopers to management regarding annual and long-term incentive programs of companies in the 2018 peer group discussed above. As a result of this review, the O&C Committee elected to revise the calculation methodology for awards under the Executive Annual Incentive Plan for 2019 (payable in 2020) and grants made in 2019 (payable in 2022) under the Long-Term Incentive Plan. For a discussion of the calculation methodologies for these plans, see “- Compensation Elements” below.

October 2019 Survey and Peer Group

In the fourth quarter of 2019, the O&C Committee assessed total compensation of our executives against a number of companies in the transmission/distribution industry and fully integrated utilities using both survey data and peer group comparisons. For purposes of the 2019 assessment, PricewaterhouseCoopers completed a competitive market analysis of executive compensation for the O&C Committee in October 2019. This analysis involved a review of U.S. energy utility industry compensation survey data using our 2018 annual revenues. The survey data was compared to our executive compensation elements targeted at both the 50^th and 75^th percentiles with respect to base salary, target cash annual incentives, and long-term incentives, and the resulting target total cash compensation (base salary and target cash annual incentives) and total direct compensation (base salary, target cash annual incentives and long-term incentives). The survey data was aged from the reporting date to January 1, 2020, using an annual rate of 3.0%, which is the projected increase factor for 2019 for officers and executives based on the World at Work 2019 Salary Budget Survey.

In addition to the market data for utilities in the national marketplace, PricewaterhouseCoopers also provided publicly available data for a subset of these utilities, a peer group of transmission/distribution utility companies as well as fully integrated utility companies. Oncor’s size, based on revenues, is in the 51st percentile of this peer group. PricewaterhouseCoopers provided information on total target direct compensation, base salary, annual incentive targets and long-term incentives with respect to the five highest paid executives at each of those companies, along with comparisons of each such executive to the comparable Oncor executive using regression analysis based on Oncor’s revenue size. The primary peer group consisted of 16 companies, 15 of which were used in PricewaterhouseCoopers’ 2018 study:

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Ameren Corp.	CMS Energy Corp.	ITC Holdings Corp.
American Electric Power Co., Inc.	Consolidated Edison, Inc.	OGE Energy Corp.
Alliant Energy	El Paso Electric Co.	Pinnacle West Capital
Avangrid Inc.	Eversource Energy	Portland General Electric Co.
CenterPoint Energy, Inc.	Evergy Inc.
Cleco Power LLC	IdaCorp Inc.

PricewaterhouseCoopers recommended using the same peer companies as in 2018 with the exception of substituting Evergy Inc. for SCANA Corp., which discontinued filing executive compensation information with the SEC. Based on PricewaterhouseCoopers’ analysis and recommendation, the O&C Committee approved this peer group revision in the 2019 compensation analysis.

The O&C Committee considered both peer group data and the 2019 competitive market survey data, along with individual performance and responsibilities, when determining total direct executive compensation, as well as each element of total direct compensation (base salary, annual incentives and long-term incentives). The O&C Committee targeted total direct compensation, including target payouts under annual and long-term incentive awards, at approximately the 50th percentile of the 2019 competitive market survey group and peer group. With respect to long-term incentives, the O&C Committee also considered the cost of equity differential between Oncor’s long-term incentive program which offers cash awards versus equity-based long-term incentive awards which are more common among the peer group. PricewaterhouseCoopers provided adjusted market data for long-term incentives to address this issue and better reflect Oncor’s competitive position versus the market. The 2019 competitive market analysis indicated that the aggregate target total direct compensation of certain of our executives was generally below the 50^th percentile of the competitive market survey group, and that base salary was below the 50^th percentile of the competitive market survey group for most of our executives. As a result of its review of the PricewaterhouseCoopers studies and each executive’s individual performance and responsibilities, the O&C Committee increased the base salaries of all Named Executive Officers, including our CEO, effective November 26, 2019 and increased the long-term incentive target percentages for our CEO, Executive Vice President and Chief Operating Officer and Senior Vice President and Chief Financial Officer effective January 1, 2020, as detailed below under “— Compensation Elements.”

Compensation Elements

A significant portion of each executive officer’s compensation is variable, at-risk and directly linked to achieving company performance objectives set by the O&C Committee and the alignment with equity owner interests in order to achieve long-term success of our company. Other factors impacting compensation include individual performance, scope of responsibilities, retention risk, and market compensation data. None of these other factors are assigned individual weights, but are considered together. The company has no policies or formula for allocating compensation among the various elements. The following is a description of the principal compensation components provided to our executives.

Base Salary

We believe that base salary should be commensurate with the scope and complexity of each executive’s position, the level of responsibility required, and demonstrated performance. We also believe that a competitive level of base salary is required to attract and retain qualified talent.

As part of its review of total direct compensation for our executive officers, the O&C Committee reviews and determines executive officers’ base salaries periodically as it deems appropriate. The periodic review includes the O&C Committee’s review of the most recent analysis of our executive compensation against competitive market data and comparison to our peer group. Our CEO also reviews this analysis, along with the performance and level of responsibility of each executive officer, and makes recommendations to the O&C Committee regarding any salary changes for those executive officers. The O&C Committee may also approve salary increases as a result of an executive’s performance, promotion or a significant change in an executive’s responsibilities.

As discussed above, the 2019 competitive market analysis prepared by PricewaterhouseCoopers indicated that the base salary of certain of our executives, including Messrs. Nye, Clevenger, and Greer and Ms. Dennis, was generally below the 50th percentile of the competitive market survey group. After considering the results of this market analysis and individual performance and responsibilities, the O&C Committee increased the base salary of each of our Named Executive Officers, including the CEO, effective November 26, 2019, as described below.

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Annual Base Salary for Named Executive Officers

The annual base salaries of Named Executive Officers at December 31, 2019 were as follows:

Name	Current Title	At December 31, 2019 (1)
E. Allen Nye, Jr.	Chief Executive	$	973,000
Don J. Clevenger	Senior Vice President and Chief Financial Officer	$	542,000
Deborah L. Dennis	Senior Vice President, Chief Customer Officer and Chief HR Officer (2)	$	404,000
James A. Greer	Executive Vice President and Chief Operating Officer	$	568,000
Matthew C. Henry	Senior Vice President, General Counsel and Secretary	$	557,000

(1) Annual base salaries were increased effective November 26, 2019 as follows: Mr. Nye increased from $927,000 to $973,000; Mr. Clevenger increased from $511,000 to $542,000; Ms. Dennis increased from $381,000 to $404,000; Mr. Greer increased from $546,000 to $568,000; and Mr. Henry increased from $536,000 to $557,000.

(2) Ms. Dennis became Senior Vice President, Chief Customer Officer and Chief HR Officer in February 2020. Until then, she served as Senior Vice President, Human Resources & Corporate Affairs, and Chief Customer Officer.

Executive Annual Incentive Plan

The O&C Committee and our CEO are responsible for administering the Executive Annual Incentive Plan. The award targets under the plan are established on a company-wide basis and the O&C Committee seeks to set these targets at performance challenging levels. The O&C Committee determines annual target award percentages for executives based on executive responsibilities and performance goals, an evaluation of the most recent competitive market analysis conducted by PricewaterhouseCoopers, and, with respect to executives other than our CEO, recommendations from our CEO. In making his recommendations to the O&C Committee regarding target award percentages, our CEO assesses the performance goals of each executive against the goals of the executive’s business unit and function and reviews the competitive market analysis. Executive Annual Incentive Plan awards are based on a target payout, which is set as a percentage of a participant’s base salary and is based on the performance of Oncor and individual participant performance. The annual incentive target payout for each executive is based on a review of the executive’s responsibilities and consideration of the 50^th percentile of target direct compensation of executives with similar responsibilities among our competitive market survey group and peer group. The O&C Committee reviewed target payout opportunities in its October 2019 review of the 2019 competitive market survey information described above and each executive’s performance and responsibilities and did not make any changes to the existing target payout opportunities for our Named Executive Officers.

The awards payable in 2019 were determined based on (1) the target award levels of participants in the Executive Annual Incentive Plan, (2) achievement of a threshold or target funding trigger, and (3) achievement of threshold, target or superior levels of any additional operational or other metrics that the O&C Committee elects to apply in determining the aggregate amount of awards, which we sometimes refer to as the operational funding percentage. Based on the level of attainment of the funding trigger and the operational funding percentage, the O&C Committee determined an aggregate performance final funding percentage. This final funding percentage was then multiplied by each target award, and the resulting amount was then multiplied by any performance modifiers to determine a final award amount. The O&C Committee sets operational metrics, performance goals, target awards and individual performance modifiers in its discretion, and also has broad discretion to adjust funding percentages and individual awards. The funding trigger described in (2) above was based on “EBITDA,” which means Oncor’s earnings before interest, taxes, depreciation and amortization, as determined by the O&C Committee. For 2019 awards, the O&C Committee excluded from EBITDA all earnings, expenses and transition costs relating to the InfraREIT Acquisition, long-term incentive compensation, performance bonus compensation, executive change of control policy expenses, certain special project professional fees, and non-cash actuarial adjustments. EBITDA was used as the funding trigger because we believe it is an effective measure to assess profitability of the business.

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Funding of incentive awards in 2019 was based first on the achievement of stated EBITDA threshold and target funding trigger levels set by the O&C Committee. Incentives were only payable under the Executive Annual Incentive Plan in the event the threshold EBITDA is achieved. The level of EBITDA achieved was used to calculate a funding trigger percentage, as illustrated in the table below.

Funding Trigger Achieved	Funding Trigger Percentage
Actual EBITDA is less than threshold	0%
Actual EBITDA equals threshold	50%
Actual EBITDA is greater than threshold but less than target	Percentage between 50% - 100% based on the percentage of EBITDA achieved
Actual EBITDA is equal to or greater than target	100%

Since the EBITDA threshold was met, an operational funding percentage was calculated based on achievement of the operational or other metrics set by the O&C Committee. For 2019, the O&C Committee established operational funding percentage metrics based solely on operational targets because it believes that incentives should be based on achievement of operational goals. The purpose of these operational targets, which are based on safety, reliability, operational efficiency and infrastructure readiness metrics, is to promote enhancement of our services to customers. The table below sets forth these operational metrics in further detail.

Operational Metric	Description	Purpose
Safety	Number of employee injuries using a Days Away, Restricted or Transfer (DART) system with a modifier for fatalities resulting from a safety violation	Promotes the health and welfare of our employees. Lowering the number of accidents also reduces our operating costs, which in turn contributes to lower rates for our customers.
Reliability	Non-storm System Average Interruption Duration Index (SAIDI), which measures the average number of minutes electric service is interrupted per customer in a year. Since weather can greatly impact reliability and is outside of our control, the reliability metric measures SAIDI on a non-storm, weather-normalized basis	Promotes our commitment to minimizing service interruptions to our customers, as the lower the SAIDI level for the year, the greater our customers’ service level and satisfaction.
Operational Efficiency	Based on the achievement of targeted operation and maintenance expense (O&M) and sales, general and administrative expense (SG&A) levels determined on a per customer cost basis	Promotes lower rates for our customers by keeping expenditures low.
Infrastructure Readiness	Measured by a metric based on capital expenditure per three year average kW peak; expressed as a cumulative percentage	Promotes enhanced service to our customers by focusing on the improvement of our facilities through achievement of the capital plan.

An operational funding percentage was calculated based on the level of achievement of each operational metric. The O&C Committee determined the weighting of each of those metrics within the operational funding percentage and the threshold, target and superior levels of each metric. For 2019 awards, the O&C Committee excluded from operational efficiency calculations the impacts from the InfraREIT Acquisition, regulatory mandated cost of service expenses, energy efficiency expenses, certain third party network transmission fees that are recovered through tariff adjustments, and long-term incentive compensation. As with the EBITDA funding trigger, each operational metric must meet a threshold level in order to provide any funding for that metric. Meeting the threshold amount results in 50% of the available funding for that metric, with target and superior levels resulting in 100% and 150%, respectively, of the available funding for that metric. Once threshold has been achieved, actual results in between each level result in a funding percentage equal to the percentage of the

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target achieved (up to 150% for achievement of the superior performance level). Once an operational funding percentage was calculated, the final funding percentage was determined in accordance with the table below.

Achieved Funding Trigger Performance	Final Funding Percentage
Actual EBITDA is less than threshold	0%
Actual EBITDA is greater than threshold but less than or equal to target	Lesser of the funding trigger percentage or the operational funding percentage
Actual EBITDA is greater than target	Equals the operational funding percentage (up to 150%)

For 2019, our EBITDA for purposes of the Executive Annual Incentive Plan exceeded the target EBITDA, resulting in a funding trigger percentage of 100%. Our operational funding percentage was 99.7%. As a result, the final funding percentage was calculated using the operational funding percentage, resulting in a final funding percentage of 99.7%.

To calculate an executive officer’s award amount, the final funding percentage is first multiplied by the executive officer’s target award, which is computed as a percentage of actual base salary. Based on the executive officer’s performance, an individual performance modifier is then multiplied by the calculated award to determine the final incentive payment. An individual performance modifier is based on reviews and evaluations of the executive officer’s performance by the CEO and the O&C Committee (or solely the O&C Committee in the case of our CEO) and may adjust an award upward or downward. Factors used in determining individual performance modifiers may include operational measures (including the safety, reliability, operational efficiency and infrastructure readiness metrics discussed above), company objectives, individual management and other goals, specific job objectives and competencies, the demonstration of team building and support attributes and general demeanor and behavior. The CEO and the O&C Committee (or solely the O&C Committee in the case of our CEO) do not assign these factors individual weights, but consider them together. Each executive officer’s individual performance modifier is set by the O&C Committee within a range determined in its discretion. In October 2019, in recognition of his oversight of all legal, regulatory and legislative matters throughout the year, including the legal and regulatory complexities involved in the InfraREIT Acquisition and matters relevant to Oncor in the 2019 Texas legislative session, the O&C Committee approved an individual performance modifier for the 2019 plan year of 120% for Mr. Henry. In February 2020, the O&C Committee approved individual modifiers for Messrs. Nye, Clevenger and Greer of 153.7%, 151.9%, and 120.1%, respectively, to bring those executives’ total direct compensation closer to the 50^th percentile of the competitive market survey group.

The following table provides a summary of the 2019 targets and actual awards for each Named Executive Officer. All awards under the Executive Annual Incentive Plan are made in the form of lump sum cash payments to participants by March 15 of the year following the plan year to which the award relates.

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2019 Annual Incentives (Payable in 2020) for Named Executive Officers

Name	Target Payout Opportunity (% of Salary)			Target Award ($ Value)		Actual Award ($) (1)		Actual Award (% of Target)
E. Allen Nye, Jr.		95	%		884,290		1,355,076		153.2	%
Don J. Clevenger		65	%		333,829		505,563		151.4	%
Deborah L. Dennis		65	%		248,895		248,148		99.7	%
James A. Greer		65	%		356,091		426,382		119.7	%
Matthew C. Henry		65	%		349,537		418,186		119.6	%

(1) Actual award reflects target award multiplied by the final funding percentage of 99.7%, multiplied by any applicable individual performance modifiers (153.7% for Mr. Nye, 151.9% for Mr. Clevenger, 120.1% for Mr. Greer and 120% for Mr. Henry.)

For more detailed information on terms of the Executive Annual Incentive Plan, including the calculation of the 2019 EBITDA funding percentage and the operational funding percentage, the 2019 operational funding triggers and the actual performance levels achieved, see the narrative that follows the Grants of Plan-Based Awards – 2019 table.

In February 2020, the Executive Annual Incentive Plan was amended and restated to revise the calculation for awards beginning with the 2020 plan year. Pursuant to these revisions, there will be no funding trigger and awards will be calculated based on achievement of operational metrics established by the O&C Committee for each plan year.

Long-Term Incentives

Our long-term incentive program currently consists of the Long-Term Incentive Plan. The Long-Term Incentive Plan was adopted in 2013. The purpose of our long-term incentive program is to promote the long-term interests and growth of Oncor by attracting and retaining management and other personnel and key service providers. Our long-term incentive program was developed to enable us to be competitive in our compensation practices. It was also developed to reflect our belief that the opportunity to benefit from positive long-term performance of the company motivates our management to work towards the long-term success of our business and align management’s interests with those of our equity holders.

The Long-Term Incentive Plan encourages retention of executive officers and key employees by stipulating performance periods of generally 36 months. We also believe that these multi-year performance periods encourage participants to strive for the long-term, sustained success of the company. The nature of the performance targets also ensures that participants strive towards both financial and operational goals.

Our board of directors delegated administration of the Long-Term Incentive Plan to the O&C Committee. Our executive officers and any other key employees of the company or its subsidiaries designated by the O&C Committee are eligible to participate. The plan provides for cash awards to be paid after completion of a performance period based on achievement of certain stated performance goals. A performance period under the Long-Term Incentive Plan is the 36 month period beginning each January 1, unless otherwise determined by the O&C Committee in its sole discretion. The participants for each performance period shall be determined by the O&C Committee not later than the 90^th day after commencement of the performance period. Performance goals consist of one or more specific performance objectives established by the O&C Committee in its discretion within the first 90 days of the commencement of the applicable performance period. Performance goals may be designated with respect to the company as a whole or one or more operating units, and may also be determined on an absolute basis or relative to internal goals, or relative to levels attained in prior years, or relative to other companies or indices, or as ratios expressing relationships between two or more performance goals. For 2019 grants, the O&C Committee set the performance targets on a company-wide basis and at levels it believes are performance challenging.

The long-term incentive target payout for each executive is set so that the target total direct compensation is near the 50th percentile (normalized in consideration of the cost of equity) of executives with similar responsibilities among our 2019 competitive market survey group and our peer group (when regressed to Oncor’s revenue size). As a result of this study and after considering individual performance and responsibilities, as well as the fact that most companies in our peer group

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provide equity-based long-term incentives as opposed to cash-based incentives, the O&C Committee increased the long-term incentive target percentages for our CEO, Executive Vice President and Chief Operating Officer and Senior Vice President and Chief Financial Officer effective January 1, 2020.

The O&C Committee determined that the performance goals used for the Long-Term Incentive Plan awards granted in 2017-2019 would consist of a financial trigger and operational metrics. The funding of these Long-Term Incentive Plan awards is contingent first upon Oncor achieving a cumulative threshold net income level for the three-year performance period. For awards granted in 2017-2019, if Oncor fails to achieve the stated net income level for the performance period, no award is payable. For awards granted in 2019, the funding trigger percentage for the performance period equals 50% if the threshold level is met or 100% if target level is met or exceeded. The applicable percentage for performance between threshold and target performance levels is determined on a straight line interpolation basis. Once a funding trigger percentage is determined, an operational goal percentage is determined based on Oncor’s satisfaction of four operational metrics. The operational goals used for the Long-Term Incentive Plan awards granted in 2017-2019 mirror the operational metrics used for 2019 awards under the Executive Annual Incentive Plan. These goals relate to (1) a safety metric based on the number of employee injuries using a Days Away, Restricted or Transfer (DART) system with a modifier for fatalities as a result of a safety violation, (2) a reliability metric as measured by the System Average Interruption Duration Index (SAIDI), (3) an operational efficiency metric based on the achievement of targeted operation and maintenance expense (O&M) and sales, general and administrative expense (SG&A) levels determined on a per customer cost basis (excluding the impacts from the InfraREIT Acquisition, regulatory mandated cost of service expenses, energy efficiency expenses, certain third party network transmission fees that are recovered through tariff adjustments, and long-term incentive compensation) and (4) an infrastructure readiness metric based on the capital expenditure per three year average kW peak, expressed as a cumulative percentage. The purpose of these operational targets, which are based on safety, reliability, operational efficiency and infrastructure readiness metrics, is to promote enhancement of our services to customers. For additional discussion on the purposes of the operational metrics, see the table and discussion of the Operational Metrics in “Compensation Elements—Executive Annual Incentive Plan.”

The O&C Committee set the threshold, target and superior levels for each operational metric. The achievement of those levels results in funding for a specific metric of 50%, 100% and 150%, respectively. Once the threshold has been achieved, actual results in between each level result in a funding percentage based on the percentage of the target achieved, determined on a straight line interpolation basis. Based on the weighting for each operational metric, an aggregate weighted average of operational goal percentage is determined.

The final funding percentage for long-term incentive awards granted in 2019 is the product of the funding trigger percentage multiplied by the weighted operational goal percentage. If net income is below the funding trigger threshold, the funding trigger percentage equals zero and no Long-Term Incentive Plan award will be payable.

The amount of each Long-Term Incentive Plan award granted is then determined based on the product of the final funding percentage, multiplied by the target opportunity dollar amount stated in each individual award letter.

The plan also gives the O&C Committee the discretion to adjust long-term awards to prevent unintended dilution or enlargement as a result of certain extraordinary events. For each operational goal, the O&C Committee may set threshold, target and superior levels of attainment and the manner of calculating the award amounts at each level (such as a specified dollar amount or a percentage or multiple of base salary). However, the Long-Term Incentive Plan provides that the maximum award payable for a performance period shall not exceed 150% of the target award.

In February 2020, the O&C Committee revised the form of award agreement under the Long-Term Incentive Plan for awards involving performance periods beginning on or after January 1, 2020. Under the revised form of agreement awards will not use a funding trigger and will instead be calculated based on achievement of performance metrics set by the O&C Committee.

Long-Term Incentive Awards Granted in 2019 (Payable in 2022)

The following table provides a summary of the target awards granted to each Named Executive Officer in February 2019. All awards under the Long Term Incentive Plan are to be made in the form of lump sum cash payments to participants on or before April of the year following the last year of the performance period. For target awards granted in 2019, awards are generally payable on or before April 1, 2022.

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2019 Target Long-Term Incentive Award Grants (Payable in 2022) for Named Executive Officers

Name	Target Award ($ Value)
E. Allen Nye, Jr.		2,551,104
Don J. Clevenger		752,192
Deborah L. Dennis		341,376
James A. Greer		873,600
Matthew C. Henry		788,992

Long-Term Incentive Awards Granted in 2017 (Payable in 2020)

In February 2020, the O&C Committee certified the level of attainment of performance goals established for long-term incentive awards granted in 2017 with a performance period that ended on December 31, 2019. Awards granted in 2017 and 2018 use the same metrics as described above for awards granted in 2019 with respect to the calculation of the funding trigger percentage, except that for awards granted in 2017 and 2018, superior net income levels were available. Achievement of a superior net income level resulted in a funding trigger percentage of 150%, with performance between superior and target levels determined on a straight-line interpolation basis. Awards granted in 2017 and 2018 are also subject to a slightly different calculation of final funding percentage. The final funding percentage for long-term incentive awards granted in 2017 was calculated using the funding trigger percentage and weighted operational goal percentage, as set forth in the table below.

Long-Term Incentive Plan Final Funding Percentage Calculation – Grants made in 2017 and 2018
Achieved Funding Trigger Performance	Final Funding Percentage
Actual funding trigger is less than threshold	0%
Actual funding trigger is greater than threshold but less than or equal to target	Lesser of the funding trigger percentage or the weighted operational goal percentage
Actual funding trigger is greater than target	Funding trigger percentage multiplied by the weighted operational goal percentage, up to a payout percentage not exceeding the funding trigger percentage

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The performance goals achieved for the 2017-2019 performance goal period were certified by the O&C Committee as follows:

2017 -2019 Performance Period Results (awards granted in 2017, payable in 2020)
Funding Trigger		Threshold	Target	Superior	Actual	Achievement
Net Income ($ millions; 2017-2019 cumulative)		1,328.9	1,563.4	1,797.9	1,644.0	117.2%
2017-2019 Performance Goals
Weighting	Performance Metric	Performance Level			Actual	Achievement(1)
30%	Safety - measured by Days Away, Restricted or Transferred (DART); cumulative	Threshold	0.69
		Target	0.58		0.36	40.0%
		Superior	0.41
30%	Reliability - measured by non-storm System Average Interruption Duration Index (SAIDI) in minutes; cumulative	Threshold	291.0
		Target	273.0		267.1	31.8%
		Superior	224.0
30%	Operational efficiency – measured by operation and maintenance expense (O&M) and sales, general and administrative expense (SG&A) on a cost per customer basis, $; average	Threshold	193.62
		Target	180.95		180.07	31.0%
		Superior	168.29
10%	Operational efficiency – measured by an infrastructure readiness metric based on the capital expenditure per three year average kW peak; %; cumulative	Threshold	97.00, 105.00
		Target	98.00, 103.00		103.11%	9.7%
		Superior	99.00 - 101.49
Operational Goal Percentage:						112.5%

(1) Achievement reflects actual performance after taking into account applicable modifiers.

(2) For purposes of the year 2019 in the performance period, the O&C Committee excluded from net income all earnings, expenses and transition costs relating to the InfraREIT Acquisition, long-term incentive compensation, performance bonus compensation, executive change of control policy expenses, certain special project professional fees, and non-cash actuarial adjustments. For purposes of the years 2017 and 2018 in the performance period, the O&C Committee excluded from net income the impact of long-term incentive compensation, performance bonus compensation, expenses related to the EFH Bankruptcy Proceedings and the Sempra Acquisition, executive change of control policy expenses, and non-cash actuarial adjustments. In addition, the O&C Committee excluded from 2017 and 2018 results the effects of writing off a non-regulated deferred tax asset (resulting from the TCJA). The O&C Committee also excluded from operational efficiency for each year in the performance period the regulatory mandated cost of service expenses, energy efficiency expenses, certain third party network transmission fees that are recovered through tariff adjustments, and long-term incentive compensation, and, for the year 2019 in the performance period, the impacts from the InfraREIT Acquisition. Pursuant to the terms of the 2017 long-term incentive awards, the amount of each award was determined based on the product of the final funding percentage certified by the O&C Committee in February 2020 and the target opportunity dollar amount stated in each individual award. The O&C Committee certified a funding trigger percentage of 117.2%, an operational goal percentage of 112.5%, and a final funding percentage of 117.2%, resulting in long-term incentive awards as set forth below for the Named Executive Officers.

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2017 - 2019 Performance Period Long-Term Incentive Awards (Payable in 2020) for Named Executive Officers in Office at December 31, 2019

Name	Actual Award ($ Value)
E. Allen Nye, Jr.	897,096
Don J. Clevenger	798,760
Deborah L. Dennis	348,637
James A. Greer	829,814
Matthew C. Henry(1)	—

(1) Mr. Henry was not employed by Oncor when these awards were granted.

In accordance with the terms of the plan, these amounts will be paid to the officers prior to April 1, 2020.

For a more detailed description of the Long-Term Incentive Plan, the net income funding trigger, the performance metrics and the actual performance levels achieved for the 2017-2019 performance period, refer to the narrative that follows the Grants of Plan-Based Awards – 2019 table.

Deferred Compensation and Retirement Plans

Our executive compensation package includes the ability to participate in the Salary Deferral Program, Oncor’s thrift plan, the Oncor Retirement Plan and the Supplemental Retirement Plan and for executives hired before January 1, 2002, subsidized retiree health care coverage. We believe that these programs, which are common among companies in the utility industry, are important to attract and retain qualified executives.

Salary Deferral Program

Oncor executive officers are eligible to participate in a Salary Deferral Program that allows employees to defer a portion of their salary and annual incentive award and to receive a matching award based on their salary deferrals. Executives can currently defer up to 50% of their base salary and up to 85% of any annual incentive award. At the executive officer’s option the deferral period can be set for seven years, until retirement or a combination of both. Oncor generally matches 100% of deferrals up to 8% of base salary deferred under the program. Oncor does not match deferred annual incentive awards. Matching contributions vest at the earliest of seven years after the deferral date, retirement, death, disability or termination without cause following a change in control of Oncor (as defined in the Salary Deferral Program). The program encourages employee retention as, generally, participants who terminate their employment with us prior to the seven year vesting period forfeit our matching contribution to the program.

Additionally, Oncor, at the direction of the O&C Committee, can make additional discretionary contributions into a Salary Deferral Program participant’s account. Discretionary contributions made into a Salary Deferral Program participant’s account by Oncor vest as determined by the O&C Committee.

Refer to the narrative that follows the Nonqualified Deferred Compensation table below for a more detailed description of the Salary Deferral Program.

Thrift Plan

All eligible employees of Oncor may contribute a portion of their regular salary or wages to the thrift plan and Oncor matches a portion of an employee’s contributions. This matching contribution is 75% of the employee’s contribution up to the first 6% of the employee’s salary for employees covered under the traditional defined benefit component of the Oncor Retirement Plan, and 100% of the employee’s contribution up to 6% of the employee’s salary for employees covered under the cash balance component of the Oncor Retirement Plan. All matching contributions are invested in thrift plan investments as directed by the participant and are immediately vested.

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Retirement Plan

All Oncor employees are eligible to participate in the Oncor Retirement Plan, which is qualified under applicable provisions of the Code. The Oncor Retirement Plan contains both a traditional defined benefit component and a cash balance component. Effective January 1, 2002, the defined benefit plan changed from a traditional final average pay design to a cash balance design. This change was made to better align the retirement program with competitive practices. All participants were extended an opportunity to remain in the traditional program component or transition to the cash balance component. Ms. Dennis and Mr. Greer elected to remain in the traditional program. All employees employed after January 1, 2002 who have completed one year of service with the company are eligible to participate only in the cash balance component. As a result, Messrs. Nye, Clevenger, and Henry are covered only under the cash balance component. For a more detailed description of the Oncor Retirement Plan, refer to the narrative that follows the Pension Benefits table and Note 10 to Financial Statements.

Supplemental Retirement Plan

Oncor executives participate in the Supplemental Retirement Plan. The Supplemental Retirement Plan provides for the payment of retirement benefits that:

• Would otherwise be capped by the Code’s statutory limits for qualified retirement plans;

• Include Executive Annual Incentive Plan awards in the definition of earnings (for participants in the traditional program component only); and/or

• Oncor is obligated to pay under contractual arrangements.

For a more detailed description of the Supplemental Retirement Plan, please refer to the narrative that follows the Pension Benefits table below.

Retiree Health Care

Employees hired by Oncor (or a predecessor) prior to January 1, 2002 are generally entitled to receive an employer-paid subsidy for retiree health care coverage upon their retirement from Oncor. As such, Ms. Dennis and Mr. Greer will be entitled to receive a subsidy from Oncor for retiree health care coverage upon their retirement from Oncor. Messrs. Nye, Clevenger, and Henry were hired after January 1, 2002 and are not eligible for the employer subsidy.

Perquisites and Other Benefits

Perquisites provided to our executive officers are intended to serve as part of a competitive total compensation program and to enhance our executives’ ability to conduct company business. These benefits include financial planning, a preventive physical health exam, and reimbursements for certain business-related country club and/or luncheon club membership costs. Perquisites do not include personal use of company property or services for which we are reimbursed for the incremental cost to the company of personal use. For a description of the total amount of perquisites for each of our named executive officers, refer to Footnote 4 in the Summary Compensation Table below.

The following is a summary of benefits offered to our executive officers that are not available to all employees:

Executive Financial Planning: All executive officers are eligible to receive executive financial planning services. These services are intended to support them in managing their financial affairs, which we consider especially important given the high level of time commitment and performance expectation required of our executives. Furthermore, these services help ensure greater accuracy and compliance with individual tax regulations.

Executive Physical Health Exam: All executive officers are also eligible to receive an annual physical examination. We recognize the importance of the health of our senior management team and the vital leadership role they play in directing and operating the company. The executive officers are important assets of the company and this benefit is designed to help ensure their health and long-term ability to serve our equity holders.

Country Club/Luncheon Club Membership: Certain executive officers are entitled to reimbursement of country club or luncheon club memberships if the company determines that a business need exists for the executive’s memberships, as such clubs provide those officers with a setting for cultivating business relationships and interaction with key community leaders and officials.

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Split-Dollar Life Insurance: Split-dollar life insurance policies were purchased for eligible executives of Oncor. Ms. Dennis was the only Named Executive Officer who participated in the program, and in July 2019, all of her policies matured and were rolled out of the program. The eligibility provisions of this program were modified in 2003 so that no new participants were added after December 31, 2003. Individuals who first became eligible to participate in the Split-Dollar Life Insurance Program after October 15, 1996, vested in the insurance policies issued under the Split-Dollar Life Insurance Program over a six-year period. Oncor pays the premiums for the policies and has received a collateral assignment of the policies equal in value to the sum of all of its insurance premium payments. Although the Split-Dollar Life Insurance Program is terminable at any time, it is designed so that if it is continued, Oncor will fully recover all of the insurance premium payments covered by the collateral assignments either upon the death of the participant or, if the assumptions made as to policy yield are realized, upon the later of 15 years of participation or the participant’s attainment of age 65. In 2007, the Split-Dollar Life Insurance Program was amended to freeze the death benefits at the then current level.

Travel & Security: We may pay travel and security expenses for executives related to service on certain third party boards of directors. These expenses could include personal security and non-commercial aircraft flights when we deem there to be a heightened security risk and/or to enhance an executive’s ability to conduct Oncor business. The incremental cost to Oncor of non-commercial flights consists of actual invoiced incremental costs for each flight pursuant to Oncor’s contracts with non-commercial aircraft providers minus any amounts reimbursed or reimbursable by the executive or a third party. From time to time an executive’s spouse and/or children may accompany the executive on a business trip. We may pay the incremental costs for the executive’s spouse to travel with the executive, if their presence contributes to the business purpose. However, any incremental costs incurred by Oncor with respect to expenses for an executive’s children to accompany the executive must be fully reimbursed by the executive.

Event Tickets: We may from time to time provide executives with sporting or other event tickets for personal use.

Additional Benefits: In addition to the benefits described above, Oncor offers its executive officers the ability to participate in benefit plans for medical, dental and vision insurance, group term life insurance and accidental death and disability, which are generally made available to all employees at the company.

Individual Named Executive Officer Compensation

Compensatory Agreements

Named Executive Officer Performance Bonus Agreements

On February 22, 2018, we entered into performance bonus agreements with each of Mr. Nye and Mr. Greer that were effective upon closing of the Sempra Acquisition and provide for a performance bonus opportunity to each executive for each of the 2018 and 2019 fiscal years. As each of Mr. Nye and Mr. Greer received promotions upon closing of the Sempra Acquisition, the O&C Committee determined that the performance bonus opportunities were necessary to bring each of their total direct compensation in line with compensation for each of their expanded roles and responsibilities, based on the 2017 peer group compensation analysis and competitive market study. The long-term incentive nature of the performance bonus agreements also provide significant value in retaining the executives and motivating them to help the company achieve certain performance goals. The performance bonus agreements provide that if the executive remains in the continuous employ of Oncor or an affiliate through the last day of each such fiscal year, the executive will be entitled to a performance bonus equal to an award amount multiplied by a performance bonus funding percentage. The performance bonus funding percentage is calculated based on a comparison of Oncor’s achieved net income for such fiscal year to the net income included in Oncor’s annual financial plan for such fiscal year approved by Oncor’s board of directors, subject to any adjustments approved by the O&C Committee. Under the terms of the performance bonus agreements, the performance bonus funding percentage shall equal 50% if the achieved net income is 80% of such fiscal year’s financial plan net income or 150% if the achieved net income is 120% of such fiscal year’s financial plan net income. The performance bonus funding percentage for achieved net income amounts between 80% and 120% of such fiscal year’s financial plan net income will be determined on a straight line interpolation basis. The O&C Committee will certify the final performance bonus funding percentage for each fiscal year and shall have the discretion to make any adjustments it deems necessary and advisable. Mr. Nye’s performance bonus agreement provides for a target award amount of $1,575,000 for the 2019 fiscal year. Mr. Greer’s performance bonus agreement provides for a target award amount of $135,000 for the 2019 fiscal year. The O&C Committee certified a final performance bonus funding percentage of 118.4% for the 2019 fiscal year, resulting in awards of $1,864,800 to Mr. Nye and $159,840 to Mr. Greer, which will be paid in March 2020.

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Retention Agreement

In January 2018, we entered into a retention agreement with Mr. Henry in connection with our offer of employment to him to serve as Oncor’s Senior Vice President, General Counsel and Secretary upon closing of the Sempra Acquisition. We believe the retention agreement, which was approved by the O&C Committee, was necessary to induce him to join the company and offer him a market competitive compensation package (targeting around the 50^th percentile of the 2017 competitive market study) that addresses the fact that as a new hire he would not receive long-term incentive award payments under the Long-Term Incentive Plan until 2021 (for the 2018-2020 performance period) and would not be eligible for an Executive Annual Incentive Plan annual incentive until 2019 (for the 2018 plan year). The retention agreement serves to reinforce and encourage Mr. Henry’s dedication to us as a member of the executive management team and to assure that we will retain his services in the key role of overseeing all of Oncor’s legal, regulatory and legislative efforts. The agreement provides for an initial retention bonus in March 2018 and payments in each of March 2019 and 2020 of retention bonuses equal to $758,080 multiplied by the approved Long-Term Incentive Plan scorecard results for each of the 2016-2018 and 2017-2019 performance periods, respectively, contingent upon Mr. Henry’s continued employment and satisfactory performance of his job duties as directed by Oncor. As a result, Mr. Henry received $801,291 in March 2019 as the second retention bonus (reflecting $758,080 multiplied by 105.7%, the approved Long-Term Incentive Plan funding percentage for the 2016-2018 performance period) and will receive $888,470 in March 2020 as the third retention bonus (reflecting $758,080 multiplied by 117.2%, the approved Long-Term Incentive Plan funding percentage for the 2017-2019 performance period). The retention agreement provides that in the event Mr. Henry’s employment is terminated by Oncor prior to March 1, 2020 for cause, or Mr. Henry terminates without good reason, all unpaid retention bonuses shall be immediately forfeited. In the event of a termination of employment by Oncor without cause, or Mr. Henry’s termination for good reason, any unpaid retention bonuses shall immediately vest and be payable on a pro-rata basis calculated in accordance with the Long-Term Incentive Plan.

CEO Compensation

E. Allen Nye, Jr.

The following is a summary of Mr. Nye’s individual compensation for 2019.

Base Salary: Mr. Nye’s base salary was increased effective November 26, 2019 from $927,000 to $973,000 as a result of the O&C Committee’s annual review of executive compensation discussed above under “-Market Data – October 2019 Survey and Peer Group.”

Annual Incentives: In 2020, the O&C Committee awarded Mr. Nye $1,355,076 pursuant to the Executive Annual Incentive Plan, reflecting the result of Oncor’s 2019 performance, as well as the O&C Committee’s review of Mr. Nye’s overall leadership of the company in 2019, including his leadership in the successful completion of the InfraREIT Acquisition and integration of NTU into our business. The award also reflects an individual performance modifier applied by the O&C Committee to bring his total direct compensation closer to the 50^th percentile of the competitive market survey group. For more detailed information on the calculation of Executive Annual Incentive Awards, see “—Compensation Elements – Executive Annual Incentive Plan” above and the Grants of Plan-Based Awards – 2019 table and related narrative.

Long-Term Incentives: In 2019, Mr. Nye was granted a Long-Term Incentive Plan target award of $2,551,104 for the performance period of January 1, 2019 through December 31, 2021. Actual awards will be based on the Company’s achievement of approved performance goals and are payable on or before April 1, 2022. In February 2020, the O&C Committee certified the results of performance goals for Long-Term Incentive Plan awards granted in 2017 for the January 1, 2017 – December 31, 2019 performance period. Mr. Nye’s Long-Term Incentive Plan award for the 2017-2019 performance period is $897,096 and will be paid on or before April 1, 2020. See “—Long-Term Incentives” above and the Grants of Plan-Based Awards-2019 table and related narrative for additional information on the Long-Term Incentive Plan and target awards.

Performance Bonus Agreement: In 2020, the O&C Committee awarded Mr. Nye $1,864,800 pursuant to the Performance Bonus Agreement, reflecting the results of Oncor’s 2019 achievement of net income. For more detailed information on the calculation of Performance Bonus Agreement awards, see “—Compensatory Agreements — Named Executive Officer Performance Bonus Agreements” above and related narrative.

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Compensation of Other Named Executive Officers

Don J. Clevenger

The following is a summary of Mr. Clevenger’s individual compensation for 2019.

Base Salary: Mr. Clevenger’s base salary as Senior Vice President and Chief Financial Officer was increased effective November 26, 2019 from $511,000 to $542,000 as a result of the O&C Committee’s annual review of executive compensation discussed above under “-Market Data – October 2019 Survey and Peer Group.”

Annual Incentive: In 2020, the O&C Committee awarded Mr. Clevenger $505,563 pursuant to the Executive Annual Incentive Plan, reflecting the result of Oncor’s 2019 performance, as well as Mr. Clevenger’s individual performance in 2019. In evaluating Mr. Clevenger’s performance in 2019 the O&C Committee and the CEO considered his extensive involvement in the successful completion of the InfraREIT Acquisition, particularly his leadership on financial and strategy matters relating to the transaction, and his overall management of Oncor’s financial systems, operations and initiatives (including the maintenance of planning, budgeting accounting, and treasury functions and his management of the liquidity of Oncor’s maintenance and construction programs). The award also reflects an individual performance modifier applied by the O&C Committee to bring his total direct compensation closer to the 50^th percentile of the competitive market survey group. For more detailed information on the calculation of Executive Annual Incentive Awards, see “—Compensation Elements — Executive Annual Incentive Plan” above and the Grants of Plan-Based Awards – 2019 table and related narrative.

Long-Term Incentives: In 2019, Mr. Clevenger was granted a Long-Term Incentive Plan target award of $752,192 for the performance period of January 1, 2019 through December 31, 2021. Actual awards will be based on the Company’s achievement of approved performance goals and are payable on or before April 1, 2022. In February 2020, the O&C Committee certified the results of performance goals for Long-Term Incentive Plan awards granted in 2017 for the January 1, 2017 – December 31, 2019 performance period. Mr. Clevenger’s Long-Term Incentive Plan award for the 2017-2019 performance period is $798,760 and will be paid on or before April 1, 2020. See “— Long-Term Incentives” above and the Grants of Plan-Based Awards-2019 table and related narrative for additional information on the Long-Term Incentive Plan and target awards.

Deborah L. Dennis

The following is a summary of Ms. Dennis’ individual compensation for 2019. Ms. Dennis is our Senior Vice President, Chief Customer Officer and Chief HR Officer. She assumed the Chief HR Officer title in February 2020. Prior to then she served as our Senior Vice President, Human Resources & Corporate Affairs, and Chief Customer Officer.

Base Salary: Ms. Dennis’ base salary was increased from $381,000 to $404,000 effective November 26, 2019 as a result of the O&C Committee’s annual review of executive compensation discussed above under “— Market Data — October 2019 Survey and Peer Group.”

Annual Incentive: In 2020, the O&C Committee awarded Ms. Dennis $248,148 pursuant to the Executive Annual Incentive Plan, reflecting the result of Oncor’s 2019 performance, as well as Ms. Dennis’ individual performance in 2019. The O&C Committee and the CEO evaluated her performance in overseeing employee relations, employee benefit matters, labor matters, corporate and community involvement, and customer related matters, including the successful integration of NTU customer matters into Oncor’s overall customer management sphere. For more detailed information on the calculation of Executive Annual Incentive Awards, see “— Compensation Elements — Executive Annual Incentive Plan” above and the Grants of Plan-Based Awards – 2019 table and related narrative.

Long-Term Incentives: In 2019, Ms. Dennis was granted a Long-Term Incentive Plan target award of $341,376 for the performance period of January 1, 2019 through December 31, 2021. Actual awards will be based on the Company’s achievement of approved performance goals and are payable on or before April 1, 2022. In February 2020, the O&C Committee certified the results of performance goals for Long-Term Incentive Plan awards granted in 2017 for the January 1, 2017 – December 31, 2019 performance period. Ms. Dennis’ Long-Term Incentive Plan award for the 2017-2019 performance period is $348,637 and will be paid on or before April 1, 2020. See “- Long-Term Incentives” above and the Grants of Plan-Based Awards-2019 table and related narrative for additional information on the Long-Term Incentive Plan and target awards.

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James A. Greer

The following is a summary of Mr. Greer’s individual compensation for 2019.

Base Salary: Mr. Greer’s base salary as Executive Vice President and Chief Operating Officer was increased from $546,000 to $568,000 effective November 26, 2019 as a result of the O&C Committee’s annual review of executive compensation discussed above under “-Market Data – October 2019 Survey and Peer Group”.

Annual Incentive: In 2020, the O&C Committee awarded Mr. Greer $426,382 pursuant to the Executive Annual Incentive Plan, reflecting the result of Oncor’s 2019 performance, as well as Mr. Greer’s individual performance in 2019 overseeing the complex operations of Oncor’s entire transmission and distribution system, one of the largest such systems in the country, and the successful integration of NTU’s operations and assets into Oncor’s system. The award also reflects an individual performance modifier applied by the O&C Committee to bring his total direct compensation closer to the 50^th percentile of the competitive market survey group. For more detailed information on the calculation of Executive Annual Incentive Awards, see “—Compensation Elements — Executive Annual Incentive Plan” above and the Grants of Plan-Based Awards – 2019 table and related narrative.

Long-Term Incentives: In 2019, Mr. Greer was granted a Long-Term Incentive Plan target award of $873,600 for the performance period of January 1, 2019 through December 31, 2021. Actual awards will be based on the Company’s achievement of approved performance goals and are payable on or before April 1, 2022. In February 2020, the O&C Committee certified the results of performance goals for Long-Term Incentive Plan awards granted in 2017 for the January 1, 2017 – December 31, 2019 performance period. Mr. Greer’s Long-Term Incentive Plan award for the 2017-2019 performance period is $829,814 and will be paid on or before April 1, 2020. See “—Long-Term Incentives” above and the Grants of Plan-Based Awards-2019 table and related narrative for additional information on the Long-Term Incentive Plan and target awards.

Performance Bonus Agreement: In 2020, the O&C Committee awarded Mr. Greer $159,840 pursuant to the Performance Bonus Agreement, reflecting the results of Oncor’s 2019 achievement of net income. For more detailed information on Mr. Greer’s performance bonus agreement, see “— Compensatory Agreements —Named Executive Officer Performance Bonus Agreements” above and related narrative.

Matthew C. Henry

The following is a summary of Mr. Henry’s individual compensation for 2019.

Base Salary: Mr. Henry’s base salary as Senior Vice President, General Counsel and Secretary was increased from $536,000 to $557,000 effective November 26, 2019 as a result of the O&C Committee’s annual review of executive compensation discussed above under “-Market Data – October 2019 Survey and Peer Group.”

Annual Incentive: In 2020, the O&C Committee awarded Mr. Henry $418,186 pursuant to the Executive Annual Incentive Plan, reflecting the result of Oncor’s 2019 performance, as well as Mr. Henry’s individual performance in 2019 overseeing all legal, regulatory and governmental affairs matters affecting Oncor, including his leadership on the significant legal and regulatory matters relating to the InfraREIT Acquisition and matters relevant to Oncor in the 2019 Texas legislative session. Mr. Henry’s award reflects an individual performance modifier of 120% awarded by the O&C Committee in recognition of his individual performance. For more detailed information on the calculation of Executive Annual Incentive Awards, see “—Compensation Elements — Executive Annual Incentive Plan” above and the Grants of Plan-Based Awards –2019 table and related narrative.

Long-Term Incentives: In 2019, Mr. Henry was granted a Long-Term Incentive Plan target award of $788,992 for the performance period of January 1, 2019 through December 31, 2021. Actual awards will be based on Oncor’s achievement of approved performance goals and are payable on or before April 1, 2022. See “—Long-Term Incentives” above and the Grants of Plan-Based Awards-2019 table and related narrative for additional information on the Long-Term Incentive Plan and target awards.

Retention Agreement: In 2019, Mr. Henry was paid a retention bonus of $801,291 pursuant to his retention agreement. See “—Compensatory Agreements – Retention Agreement” above for more information regarding Mr. Henry’s retention agreement.

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Contingent Payments

Change in Control Policy

Oncor makes available the Change in Control Policy for its eligible executives. The purpose of the Change in Control Policy is to provide the payment of transition benefits to eligible executives if:

• Their employment with the company or a successor is terminated within twenty-four months following a change in control of the company; and

• They:

• are terminated without cause, or

• resign for good reason.

The terms “change in control,” “without cause” and “good reason” are defined in the Change in Control Policy.

We believe these payments, to be triggered upon meeting the criteria above, provide incentive for executives to fully consider potential changes that are in the best interest of Oncor and our equity holders, even if those changes would result in the executives’ termination. We also believe it is important to have a competitive change in control program to attract and retain the caliber of executives that our business requires and to foster an environment of relative security within which we believe our executives will be able to focus on achieving company goals.

Refer to “Potential Payments upon Termination or Change in Control—Change in Control Policy” for detailed information about payments and benefits that our executive officers are eligible to receive under the Change in Control Policy.

Severance Plan

Oncor also makes available a Severance Plan (Severance Plan) to provide certain benefits to eligible executives. The purpose of the Severance Plan is to provide benefits to eligible executives who are not eligible for severance pursuant to another plan or agreement (including an employment agreement) and whose employment is involuntarily terminated for reasons other than:

• Cause (as defined in the Severance Plan);

• Disability of the employee, if the employee is a participant in our long-term disability plan; or

• A transaction involving the company or any of its affiliates in which the employee is offered employment with a company involved in, or related to, the transaction.

We believe it is important to have a severance plan in place to attract and retain the caliber of executives that our business requires and to foster an environment of relative security within which we believe our executives will be able to focus on achieving company goals. Refer to “Potential Payments upon Termination or Change in Control” for detailed information about payments and benefits that our executive officers are eligible to receive under the Severance Plan.

Tax Considerations

The O&C Committee administers our executive compensation programs with the good faith intention of complying with the Code, including Section 409A, as well as other applicable regulations and accounting rules.

Compensation Committee Interlocks and Insider Participation

Three of our O&C Committee members during 2019, Steven J. Zucchet, George W. Bilicic, a former director, and Tania Ortiz, a former director, were not classified as disinterested directors under the standards set forth in the Limited Liability Company Agreement. Mr. Zucchet is employed by OMERS Infrastructure Management Inc., a beneficial owner of Texas Transmission, and serves as an officer and director of Texas Transmission’s parent company. Mr. Zucchet was designated to serve on our board of directors by Texas Transmission. Ms. Ortiz, the Chief Executive Officer of Infraestructura Energética Nova, S.A.B. de C.V. (IEnova), an entity indirectly majority owned by Sempra, was designated to serve on our board of directors by Sempra (through Oncor Holdings) in July 2018 and served on our board of directors and the O&C Committee until August 2019. Mr. Bilicic, who served as President and Chief Legal Officer of Sempra and as a member of our board of directors and the O&C Committee until March 2020, was designated to serve on our board of directors by Sempra (through Oncor Holdings) in August 2019. Mr. Bilicic replaced Ms. Ortiz on our board of directors and the O&C Committee.

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No member of the O&C Committee is or has ever been one of our officers or employees. Mr. Nye, our CEO, was elected to the board of directors of IEnova in January 2019. No other interlocking relationship exists between our executive officers and the board of directors or compensation committee of any other company.

Summary Compensation Table

The following table provides information regarding the aggregate compensation paid to our Named Executive Officers for the fiscal years ended December 31, 2019, 2018 and 2017 in which they served as a Named Executive Officer.

Name and Principal Position	Year		Salary ($)		Bonus ($)(1)		Non-Equity Incentive Plan Compensation ($)(2)		Change in Pension Value and Non- Qualified Deferred Compensation Earnings ($)(3)		All Other Compensation ($)(4)		Total ($)
E. Allen Nye, Jr. (5)
Chief Executive		2019		930,833		1,864,800		2,252,172		149,256		166,688		5,363,749
		2018		791,000		1,880,480		1,588,310		10,062		104,677		4,374,529
		2017		521,333		—		985,039		62,930		94,200		1,663,502
Don J. Clevenger (6)
Senior Vice President & Chief Financial Officer		2019		513,583		—		1,304,323		127,471		77,522		2,022,899
		2018		489,750		—		1,039,929		13,044		76,745		1,619,468
		2017		464,167		—		876,673		45,846		93,565		1,480,251
Deborah L. Dennis (7)
Senior Vice President, Chief Customer Officer and Chief HR Officer		2019		382,917		—		596,785		849,733		71,122		1,900,557
		2018		362,250		—		561,359		1,574		80,814		1,005,997
James A. Greer (8)
Executive Vice President & Chief Operating Officer		2019		547,833		159,840		1,256,196		1,741,181		70,902		3,775,952
		2018		520,500		192,720		1,089,045		27,320		78,611		1,908,196
		2017		482,167		—		910,701		885,118		98,507		2,376,493
Matthew C. Henry (9)
Senior Vice President, General Counsel & Secretary		2019		537,750		801,291		418,186		21,840		71,738		1,850,805
		2018		400,875		1,051,843		279,942		—		49,817		1,782,477

(1) Amounts reported as “Bonus” for Messrs. Nye and Greer for 2018 and 2019 represent amounts paid pursuant to their performance bonus agreements. For more information on the performance bonus agreements, see “– Compensation Discussion and Analysis – Individual Named Executive Officer Compensation – Compensatory Agreements – Named Executive Officer Performance Bonus Agreements.” Amounts reported as “Bonus” for Mr. Henry for 2018 and 2019 represent the amount paid pursuant to his retention agreement. For more information on his retention agreement, see “– Compensation Discussion and Analysis – Individual Named Executive Officer Compensation – Compensatory Agreements – Retention Agreement.”

(2) Amounts reported as “Non-Equity Incentive Plan Compensation” were earned by the executive in the respective year and represent amounts related to awards for such years pursuant to the Executive Annual Incentive Plan and the Long-Term Incentive Plan. Awards under the Executive Annual Incentive Plan for any given year are paid in March of the following year. Awards under the Long-Term Incentive Plan are paid on or before April 1 following a 36-month performance period. Long-Term Incentive Plan amount in this column for 2019 represents awards to be paid in 2020 that were earned by the executive for the 2017-2019 performance period.

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(3) Amounts reported under this column reflect the aggregate change in actuarial value at December 31 of the specified year as compared to December 31 of the previous year of each executive’s accumulated benefits under the Oncor Retirement Plan and the Supplemental Retirement Plan. With respect to the Oncor Retirement Plan, Ms. Dennis and Mr. Greer are covered under the traditional defined benefit component and Messrs. Nye, Clevenger, and Henry are covered under the cash balance component. Mr. Henry became eligible for the cash balance program in 2019 after completing the required one-year of service. There are no above-market or preferential earnings for nonqualified deferred compensation. For a more detailed description of these plans and the calculation of actuarial value, see “– Compensation Discussion and Analysis – Compensation Elements – Deferred Compensation and Retirement Plans” and the narrative that follows the Pension Benefits table below.

(4) Amounts reported as “All Other Compensation” for 2019 are attributable to the executive’s receipt of compensation as described in the table below.

(5) Mr. Nye became Chief Executive on March 9, 2018, upon the closing of the Sempra Acquisition. Until that date he served as our Senior Vice President, General Counsel and Secretary.

(6) Mr. Clevenger became Senior Vice President and Chief Financial Officer on March 9, 2018, upon the closing of the Sempra Acquisition. Until that date he served as our Senior Vice President, Strategic Planning.

(7) Ms. Dennis became Chief Customer Officer on March 9, 2018, upon the closing of the Sempra Acquisition, a role she assumed in addition to her then role as Senior Vice President, Human Resources & Corporate Affairs. In 2019, she served as Senior Vice President, Human Resources & Corporate Affairs, and in February 2020, Ms. Dennis became Senior Vice President, Chief Customer Officer and Chief HR Officer.

(8) Mr. Greer was promoted from Senior Vice President and Chief Operating Officer to Executive Vice President and Chief Operating Officer effective March 9, 2018, upon the closing of the Sempra Acquisition.

(9) Mr. Henry joined Oncor as Senior Vice President, General Counsel and Secretary on March 16, 2018.

2019 All Other Compensation Components for Named Executive Officers

Name	Thrift Plan Company Match ($)		Salary Deferral Program Company Match ($)(1)		Perquisites ($)(2)		Split-Dollar Life Insurance Program  Payments ($)(3)		Total ($)
E. Allen Nye, Jr.		16,609		74,467		75,612		—		166,688
Don J. Clevenger		16,800		41,087		19,635		—		77,522
Deborah L. Dennis		12,600		30,633		25,498		2,391		71,122
James A. Greer		12,600		43,827		14,475		—		70,902
Matthew C. Henry		16,800		43,020		11,918		—		71,738

(1) Amounts represent company matching amounts under the Salary Deferral Program. Refer to the narrative that follows the Nonqualified Deferred Compensation table below for a more detailed description of the Salary Deferral Program.

(2) Amounts reported under this column represent the aggregate amount of perquisites received by each Named Executive Officer. Those perquisites consist of (i) executive physicals and related health tests for each of Messrs. Nye, Clevenger and Greer and Ms. Dennis, (ii) financial planning services for Messrs. Nye and Greer and Ms. Dennis, (iii) country club/luncheon club dues for Messrs. Nye, Clevenger, and Henry and Ms. Dennis, (iv) travel and security expenses for Mr. Nye related to his attendance at board meetings of IEnova (an entity indirectly majority owned by Sempra), including $40,710 in invoiced incremental costs to Oncor for non-commercial flights minus reimbursed amounts, (v) spouse travel expenses for Ms. Dennis, with respect to her spouse accompanying her on a business trip, and (vi) sporting event tickets provided to Messrs. Nye, Clevenger and Henry for personal use. Amounts reported represent the incremental cost to Oncor for the perquisites provided after taking account any reimbursed or reimbursable amounts. For a discussion of the perquisites received by our executive officers, see “– Compensation Discussion and Analysis – Compensation Elements – Perquisites and Other Benefits.”

(3) Amounts represent premium and tax gross-up payments pursuant to the Split-Dollar Life Insurance Program. Ms. Dennis was the only Named Executive Officer eligible to participate in the program because the program was frozen to new participants prior to the qualification for participation by the other Named Executive Officers. Amounts in this column for Ms. Dennis represent the aggregate amount of payments pursuant to the program including interest of $1,809 relative to cumulative premium payments which had been made on her behalf, and Oncor provided tax gross-up payments of $582 to offset the effect of taxes on such payments. In 2019, all of the policies for Ms. Dennis were surrendered to her upon maturity and the Company was reimbursed $197,206 for the full amount of premium payments made. For a discussion of the Split-Dollar Life Insurance Program, please see “– Compensation Discussion and Analysis – Compensation Elements – Perquisites and Other Benefits.”

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Grants of Plan-Based Awards – 2019

The following table sets forth information regarding grants of plan-based awards to Named Executive Officers under our Executive Annual Incentive Plan and Long-Term Incentive Plan during the fiscal year ended December 31, 2019.

	Estimated Possible Payouts Under Non-Equity Incentive Plan Awards
Name	Threshold ($)		Target ($)		Maximum/Superior ($)
E. Allen Nye, Jr.
Executive Annual Incentive Plan (1)		442,145		884,290		1,326,435
Long-Term Incentive Plan (2)		1,275,552		2,551,104		3,826,656
Don J. Clevenger
Executive Annual Incentive Plan (1)		166,914		333,829		500,743
Long-Term Incentive Plan (2)		376,096		752,192		1,128,288
Deborah L. Dennis
Executive Annual Incentive Plan (1)		124,448		248,895		373,343
Long-Term Incentive Plan (2)		170,688		341,376		512,064
James A. Greer
Executive Annual Incentive Plan (1)		178,046		356,091		534,137
Long-Term Incentive Plan (2)		436,800		873,600		1,310,400
Matthew C. Henry
Executive Annual Incentive Plan (1)		174,769		349,537		524,306
Long-Term Incentive Plan (2)		394,496		788,992		1,183,488

(1) The amounts reported reflect the threshold, target and maximum/superior amounts available under the Executive Annual Incentive Plan. Threshold, target and maximum/superior amounts were determined by the O&C Committee in February 2019 and final award payout amounts were determined by the O&C Committee in February 2020. The actual awards for the 2019 plan year will be paid in March 2020 and are reported in the Summary Compensation Table under the heading “Non-Equity Incentive Plan Compensation.”

(2) The amounts reported reflect the threshold, target and maximum/superior amounts available for award grants made in 2019 under the Long-Term Incentive Plan. Target amounts for each Named Executive Officer were determined by the O&C Committee in February 2019 and any final awards will be payable on or before April 1, 2022 based on achievement of performance goals for the 2019-2021 performance period, as discussed in more detail below under “— Long-Term Incentive Plan.” Actual awards for the performance period ending on December 31, 2019 will be paid on or before April 1, 2020 and are reported in the Summary Compensation Table under the heading “Non-Equity Incentive Plan Compensation.”

Executive Annual Incentive Plan 2019 Awards

The Executive Annual Incentive Plan is a cash bonus plan intended to provide a performance-based annual reward for the successful attainment of certain annual performance goals and business objectives that are established by the O&C Committee. Elected officers of the company having a title of vice president or above and other specified key employees are eligible to participate in the Executive Annual Incentive Plan provided they are employed by us for a period of at least three full months during a January 1 to December 31 plan year. The O&C Committee and our CEO are responsible for administering the Executive Annual Incentive Plan. Participants who die, become disabled or retire during a plan year are eligible to receive prorated awards under the plan for that plan year provided they completed at least three full months of employment in such plan year. Any awards to executive officers are in the sole discretion of the O&C Committee, and those awards are prorated for the number of months in which the individual was employed by the company.

Funding for awards payable in 2019 was determined based on a funding trigger based on Oncor’s EBITDA and additional operational metrics that the O&C Committee elected to apply in determining the aggregate amount of awards. Based on the level of attainment of these EBITDA and operational metrics targets, the O&C Committee determined an aggregate final funding percentage. This final funding percentage was multiplied by target awards, which amount was then multiplied by individual performance modifiers to provide the final Executive Annual Incentive Plan award. Each step in the calculation process for 2019 awards is described in more detail below.

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Step 1: EBITDA Achievement

Incentives were only payable under the Executive Annual Incentive Plan for 2019 in the event the threshold EBITDA funding trigger was achieved. The level of EBITDA achieved was used to calculate a funding trigger percentage as illustrated in the table below.

Funding Trigger Achieved	Funding Trigger Percentage
Actual EBITDA is less than threshold	0%
Actual EBITDA equals threshold	50%
Actual EBITDA is greater than threshold but less than target	Percentage between 50% - 100% equal to the percentage of the target EBITDA achieved
Actual EBITDA equals or is greater than target	100%

For 2019, the EBITDA funding triggers (threshold and target), actual results and funding trigger percentage under the Executive Annual Incentive Plan were as follows:

Name	Threshold ($ millions)		Target ($ millions)		Actual Results ($ millions)		Funding Trigger Percentage
EBITDA		1,557.1		1,730.1		1,774.4		100	%

Step 2: Operational Achievement

For 2019 awards, if the threshold EBITDA funding trigger is achieved, then once the EBITDA funding percentage is determined, the operational or other metrics set by the O&C Committee are then applied to determine an operational funding percentage. For 2019, the O&C Committee only used operational metrics, which are set forth in the table below.

Additional Metrics	Description
Safety	Number of employee injuries using a Days Away, Restricted or Transfer (DART) system with a modifier for fatalities resulting from a safety violation
Reliability	Non-storm System Average Interruption Duration Index (SAIDI), which measures the average number of minutes electric service is interrupted per customer in a year on a weather normalized basis.
Operational Efficiency	Based on the achievement of targeted operation and maintenance expense (O&M) and sales, general and administrative expense (SG&A) levels determined on a per customer cost basis
Infrastructure Readiness	Measured by a metric based on capital expenditure per three year average kW peak; expressed as a cumulative percentage

For further information on the operational metrics, see “Compensation Discussion and Analysis—Compensation Elements—Executive Annual Incentive Plan.”

The O&C Committee determined the weighting of each of those metrics within the final operational funding percentage. As with the EBITDA funding trigger, each operational metric must meet a threshold level in order to provide any funding for that metric. Meeting the threshold amount results in 50% of the available funding for that specific metric. The O&C Committee also set target and superior levels for each operational metric, and achievement of those levels results in funding for a specific metric of 100% and 150%, respectively. Once threshold has been achieved, actual results in between each level result in a funding percentage based on the percentage of the target achieved, determined on a straight line interpolation basis (up to 150%, for achievement of the superior performance level). For 2019, the weighting, actual results and operational funding percentages for the operational metrics under the Executive Annual Incentive Plan were as follows:

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Goal	Weighting	Threshold(1)	Target(2)	Superior(3)	Actual Results	Operational Funding Percentage (4)
Safety (measured in number of injuries per 200,000 hours)
DART	30%	0.59	0.47	0.32	0.38	24.0%
Reliability (measured in minutes)
Non-storm SAIDI	30%	94.0	88.0	76.0	84.1	34.9%
Operational Efficiency - O&M Cost Per Customer (measured in $ per customer)
O&M	30%	197.33	184.42	171.51	184.42	30.0%
Infrastructure Readiness
Capital expenditures per three year average kW peak	10%	97.00%, 105.00%	98.00%, 103.00%	99.00%, 101.49%	102.7%	10.8%
		Total Operational Funding Percentage				99.7%

(1) Achievement of the threshold operational metric level results in funding of 50% of the available funding percentage for that specific operational metric. Failure to achieve the threshold results in no funding for that specific operational metric.

(2) Achievement of the target operational metric level results in funding of 100% of the available funding percentage for that specific operational metric.

(3) Achievement above the superior operational metric level results in funding of up to 150% of the available funding percentage for that specific operational metric.

(4) Operational Funding Percentage is calculated using actual results and taking into account any applicable modifiers.

For 2019, achievement of operational metrics resulted in an operational funding percentage of 99.7%. The operational funding percentage can decrease the final funding percentage, as described in more detail below.

Step 3: Determining Final Funding Percentage

For 2019 awards, after a funding trigger percentage and operational funding percentage are determined, a final funding percentage is calculated in accordance with the following table. The final funding percentage will be equal to (i) the weighted operational funding percentage if EBITDA is above target level or (ii) the lesser of the funding trigger percentage or the weighted operational funding percentage if EBITDA is at the target level or between the threshold and target levels. Failure to achieve threshold EBITDA will result in no funding of awards for that plan year.

Achieved Funding Trigger Performance	Final Funding Percentage
Actual EBITDA is less than threshold	0%
Actual EBITDA is greater than threshold but less than or equal to target	Lesser of the funding trigger percentage or the operational funding percentage
Actual EBITDA is greater than target	Equals the operational funding percentage (up to 150%)

For 2019, since actual EBITDA was greater than target the final funding percentage was the equal to the operational funding percentage, resulting in a final funding percentage of 99.7%.

Step 4: Final Award Determination

To calculate an executive officer’s award amount, the final funding percentage is first multiplied by the executive officer’s target award, which is computed as a percentage of actual base salary. Based on the executive officer’s performance, an individual performance modifier is then applied to the calculated award to determine the final incentive payment. An individual performance modifier is based on reviews and evaluations of the executive officer’s performance by the CEO and the O&C Committee (or solely the O&C Committee in the case of our CEO) and may adjust an award upward or downward. The individual performance modifier is determined on a subjective basis. Factors used in determining individual performance modifiers may include operational measures (including the safety, reliability, operational efficiency metrics and infrastructure readiness discussed above), company objectives, individual management and other goals, specific job objectives and competencies, the demonstration of team building and support attributes and general demeanor and behavior. The CEO and the O&C Committee (or solely the O&C Committee in the case of our CEO) do not assign these factors individual weights, but consider them together. Each executive officer’s individual performance modifier is set by the O&C Committee within a range determined in its discretion. In October 2019, in recognition of his oversight of all legal, regulatory and legislative matters throughout the year, including the legal and regulatory complexities involved in the

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InfraREIT Acquisition and matters relevant to Oncor in the 2019 Texas legislative session, the O&C Committee approved an individual performance modifier for the 2019 plan year of 120% for Mr. Henry. In February 2020, the O&C Committee approved individual modifiers for Messrs. Nye, Clevenger and Greer of 153.7%, 151.9%, and 120.1%, respectively, to bring those executives’ total direct compensation closer to the 50^th percentile of the competitive market survey group.

Plan Revisions Applicable for Plan Years Beginning in 2020

In February 2020, the Executive Annual Incentive Plan was amended and restated to revise the calculation for awards beginning with the 2020 plan year. Pursuant to these revisions, there will be no funding trigger and awards will be calculated based on achievement of operational metrics established by the O&C Committee for each plan year.

Long-Term Incentive Plan

Our board of directors adopted the Long-Term Incentive Plan effective January 1, 2013 and delegated administration of the Long-Term Incentive Plan to the O&C Committee. Our executive officers and any other key employees of the company or its subsidiaries designated by the O&C Committee are eligible to participate. The plan provides for cash awards to be paid after completion of a performance period based on achievement of certain stated performance goals. A performance period under the Long-Term Incentive Plan is the 36-month period beginning each January 1, unless otherwise determined by the O&C Committee in its sole discretion. The participants for each performance period shall be determined by the O&C Committee not later than the 90^th day after commencement of the performance period. Performance goals consist of one or more specific performance objectives established by the O&C Committee in its discretion within the first 90 days of the commencement of the applicable performance period. Performance goals may be designated with respect to the company as a whole or one or more operating units, and may also be determined on an absolute basis or relative to internal goals, or relative to levels attained in prior years, or relative to other companies or indices, or as ratios expressing relationships between two or more performance goals.

2019 Grants of Long-Term Incentive Awards

The O&C Committee determined that the performance goals used for the Long-Term Incentive Plan awards granted in 2019 would consist of both a financial trigger and operational metrics, as set forth below.

2019 - 2021 Performance Period (awards granted in 2019, payable in 2022)
Funding Trigger		Threshold	Target
Net Income ($ millions; 2019-2021 cumulative)(1)		85%	100%
Performance Goals
Weighting	Performance Metric	Performance Goal
30%	Safety – measured by Days Away, Restricted or Transferred (DART); cumulative	Threshold	0.56
		Target	0.45
		Superior	0.29
30%	Reliability - measured by non-storm System Average Interruption Duration Index (SAIDI) in minutes; cumulative	Threshold	272
		Target	253
		Superior	225
30%	Operational efficiency - measured by operation and maintenance expense (O&M) and sales, general and administrative expense (SG&A) on a cost per customer basis; $; average(2)	Threshold	107%
		Target	100%
		Superior	93%
10%	Operational efficiency - measured by an infrastructure readiness metric based on the capital expenditure per three year average kW peak; expressed as a cumulative percentage	Threshold	97.0%, 105.0%
		Target	98.0%, 103.0%
		Superior	99.0% - 101.49%

(1) The awards note that no later than 90 days after the start of each year within the performance period, the board of directors will approve the annual financial plan for the year. Threshold and target levels for net income are reflected as percentages of the cumulative net income set forth in the financial plans for the 2019-2021 performance period.

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(2) The awards note that no later than 90 days after the start of each year within the performance period, the board of directors of Oncor will approve the annual financial plan for the year. Threshold, target and superior levels for operational efficiency are reflected as percentages of the average O&M and SG&A (on a cost per customer basis) set forth in the financial plans for the 2019-2021 performance period.

For awards granted in 2017, 2018, and 2019, the net income funding trigger and operational efficiency performance goals measured by O&M and SG&A on a cost per customer basis were noted as percentages of the cumulative amounts set forth in the financial plans approved by our board of directors for each year in the 2017-2019, 2018-2020 and 2019-2020 performance periods. In October 2016 our board of directors approved the financial plan for 2017. Based on the approved financial plan, the O&C Committee in March 2017 declared that for purposes of calculating the cumulative performance goals for the 2017-2019 performance period, the 2017 net income funding trigger threshold, target and superior levels would be $390.3 million, $459.2 million and $528.1 million, respectively, and the 2017 operational efficiency metric (measured by O&M and SG&A on a cost per customer basis) threshold, target and superior levels would be $187.82, $175.53 and $163.25. For purposes of calculating the cumulative performance goals for the 2017-2019 and 2018-2020 performance periods, in February 2018, based on the 2018 financial plan approved by our board of directors in February 2018, the O&C Committee certified that the 2018 net income funding trigger threshold, target and superior levels would be at $445.6 million, $524.2 million and $602.8 million, respectively, and the 2018 operational efficiency metric (measured by O&M and SG&A on a cost per customer basis) threshold, target and superior levels would be at $195.72, $182.91 and $170.11. For purposes of calculating the cumulative performance goals for the 2017-2019, 2018-2020 and 2019-2021 performance periods, in February 2019, based on the 2019 financial plan approved by our board of directors in February 2019, the O&C Committee certified the 2019 net income funding trigger target level at $580 million (with the threshold level and, for awards granted in 2017 and 2018, the superior level of the net income funding trigger equal to 85% and 115% of the relevant target amount, respectively), and the 2019 operational efficiency metric (measured by O&M and SG&A on a cost per customer basis) target level at $184.42 (with the threshold level and the superior level of such operational efficiency metric equal to 107% and 93% of the relevant target amount, respectively). For purposes of calculating the cumulative performance goals for the 2018-2020 and 2019-2021 performance periods, in February 2020, based on the 2020 financial plan approved by our board of directors in October 2019, the O&C Committee certified the 2020 net income funding trigger target level at $741.5 million (with the threshold level and, for awards granted in 2018, the superior level of the net income funding trigger equal to 85% and 115% of the relevant target amount, respectively), and the 2020 operational efficiency metric (measured by O&M and SG&A on a cost per customer basis) target level at $195.31 (with the threshold level and the superior level of such operational efficiency metric equal to 107% and 93% of the relevant target amount, respectively).

The funding of each Long-Term Incentive Plan award granted in 2017-2019 was contingent first upon Oncor achieving a cumulative threshold net income level for the three-year period. If Oncor fails to achieve the stated net income level for the performance period, no award is payable. For Long-Term Incentive Plan awards granted in 2019, the funding trigger percentage for a performance period equals 50% if the threshold level is met and 100% if target level is met or exceeded. The applicable percentage for performance between threshold and target performance levels is determined on a straight line interpolation basis.

Once a funding trigger percentage is determined, an operational goal percentage is determined based on Oncor’s satisfaction of four operational metrics. The operational goals used for the Long-Term Incentive Plan awards mirror the operational metrics used for awards under the Executive Annual Incentive Plan. The table below sets forth the operational goals that the O&C Committee applied for 2019 grants.

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Additional Metrics	Description
Safety	Number of employee injuries using a Days Away, Restricted or Transfer (DART) system with a modifier for fatalities resulting from a safety violation
Reliability	Non-storm System Average Interruption Duration Index (SAIDI), which measures the average number of minutes electric service is interrupted per customer in a year on a weather normalized basis.
Operational Efficiency	Based on the achievement of targeted operation and maintenance expense (O&M) and sales, general and administrative expense (SG&A) levels determined on a per customer cost basis
Infrastructure Readiness	Measured by a metric based on capital expenditure per three year average kW peak; expressed as a cumulative percentage

For further information on the operational goals, which are identical to the operational metrics in the Executive Annual Incentive Plan, see “Compensation Discussion and Analysis—Compensation Elements—Executive Annual Incentive Plan.”

The O&C Committee sets the threshold, target and superior levels for each operational metric. The achievement of those levels results in funding for a specific metric of 50%, 100% and 150%, respectively. Once the threshold has been achieved, actual results in between each level result in a funding percentage equal to the percentage of the target achieved. Based on the weighting for each operational metric, an aggregate weighted average of operational goal percentage is determined.

The final funding percentage for long-term incentive awards granted in 2019 is the product of the funding trigger percentage multiplied by the weighted operational goal percentage. If net income is below the funding trigger threshold, the funding trigger percentage equals zero and no Long-Term Incentive Plan award will be payable.

The amount of each Long-Term Incentive Plan award is then determined based on the product of the final funding percentage, multiplied by the target opportunity dollar amount stated in each individual award.

Certification of Attainment of 2017 Performance Goals

Under the terms of the Long-Term Incentive Plan, the O&C Committee must measure and certify the levels of attainment of performance goals within 90 days following the completion of the performance period. Any awards for such period shall be paid on or about April 1 following the performance period, but in no event later than the end of the calendar year following the end of the applicable performance period.

In February 2020, the O&C Committee certified the level of attainment of performance goals established for long-term incentive awards granted in 2017 with a performance period that ended on December 31, 2019. The performance goals achieved for the 2017-2019 performance goal period were certified by the O&C Committee as follows:

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2017 -2019 Performance Period Results (awards granted in 2017, payable in 2020)
Funding Trigger		Threshold	Target	Superior	Actual	Achievement
Net Income ($ millions; 2017-2019 cumulative)		1,328.9	1,563.4	1,797.9	1,644.0	117.2%
2017-2019 Performance Goals
Weighting	Performance Metric	Performance Level			Actual	Achievement(1)
30%	Safety - measured by Days Away, Restricted or Transferred (DART); cumulative	Threshold	0.69
		Target	0.58		0.36	40.0%
		Superior	0.41
30%	Reliability - measured by non-storm System Average Interruption Duration Index (SAIDI) in minutes; cumulative	Threshold	291.0
		Target	273.0		267.1	31.8%
		Superior	224.0
30%	Operational efficiency - measured by operation and maintenance expense (O&M) and sales, general and administrative expense (SG&A) on a cost per customer basis, $; average	Threshold	193.62
		Target	180.95		180.07	31.0%
		Superior	168.29
10%	Operational efficiency - measured by an infrastructure readiness metric based on the capital expenditure per three year average kW peak; %; cumulative	Threshold	97.00, 105.00
		Target	98.00, 103.00		103.11%	9.7%
		Superior	99.00 – 101.49
			Operational Goal Percentage:			112.5%

(1) Achievement reflects actual performance after taking into account applicable modifiers.

Long-term incentive awards granted prior to 2019 were subject to a different calculation of final funding percentage than awards granted in 2019. For a description of how the final funding percentage for awards granted in 2017 and payable in 2020 was calculated, see “Compensation Discussion & Analysis – Compensation Elements – Long-Term Incentives.”

Award Agreement Revisions Applicable for Performance Periods Beginning in 2020

In February 2020, the O&C Committee revised the form of award agreement under the Long-Term Incentive Plan for awards involving performance periods beginning on or after January 1, 2020. Under the revised form of agreement, awards will not use a funding trigger and will instead be calculated based on achievement of performance metrics set by the O&C Committee.

Other Terms of the Long-Term Incentive Plan

The Long-Term Incentive Plan encourages retention of executive officers and key employees by stipulating performance periods of generally 36 months. Participants must be continuously employed by us through the last day of the performance period in order to receive a long-term incentive award for that performance period. If a participant is employed by us on the last day of the performance period but his/her employment terminates for any reason other than by us for cause prior to the payment of the award for that performance period, the participant will be entitled to receive payment of the award. In the event a participant is terminated by us for cause, the participant will forfeit any unpaid Long-Term Incentive Plan award. For purposes of the Long-Term Incentive Plan, “cause” has the same meaning as defined in any employment agreement or change-in-control agreement of such participant in effect at the time of termination of employment. If there is no such employment or change-in-control agreement, “cause” means (i) the indictment on or pleading guilty or nolo contendere to, a felony or misdemeanor involving moral turpitude of such participant, or upon the participant, in the carrying out his or her duties to the company, (ii) engaging in conduct that causes a breach of his/her fiduciary duties to us, our subsidiaries or our investors, (iii) committing an act of gross negligence, or (iv) committing gross misconduct resulting in material economic harm to us. If a participant’s employment is terminated for reasons other than death, disability, retirement or following a change in control prior to the last day of the performance period, all of such participant’s outstanding and unpaid Long-Term Incentive Plan awards will be cancelled. Upon a termination due to death, disability or retirement, for each outstanding Long-Term Incentive Plan unpaid award, the participant (or his/her beneficiary in the case of death) will be entitled to receive, on the same date as awards are paid for that period to other participants, an award equal to the product of (i) a fraction, the numerator of which is the number of days in the performance period up to and including the date of the separation of service and the denominator of which is the number of days in the entire performance period, and (ii) the Long-Term Incentive Plan award for such performance period based on actual performance of Oncor during the performance

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period. In the event of a termination within two years following a change in control, a participant shall be entitled to receive, within 60 days following the separation from service, an award equal to the product of (i) a fraction, the numerator of which is the number of days in the performance period up to and including the date of the separation of service and the denominator of which is the number of days in the entire performance period, and (ii) the Long-Term Incentive Plan award for such performance period based on target performance.

For purposes of the Long-Term Incentive Plan, a “change in control” means, in one or a series of related transactions, (i) the sale of all or substantially all of the consolidated assets or capital stock of EFH Corp., Oncor Holdings, or Oncor to a person (or group of persons acting in concert) who is not an affiliate of any member of the Sponsor Group; (ii) a merger, recapitalization or other sale by EFH Corp., any member of the Sponsor Group or their affiliates, to a person (or group of persons acting in concert) that results in more than 50% of EFH Corp.’s common stock (or any resulting company after a merger) being held by a person (or group of persons acting in concert) that does not include any member of the Sponsor Group or any of their respective affiliates; or (iii) a merger, recapitalization or other sale of common stock by EFH Corp., any member of the Sponsor Group or their affiliates, after which the Sponsor Group owns less than 20% of the common stock of, and has the ability to appoint less than a majority of the directors to the board of directors of, EFH Corp. (or any resulting company after a merger); and with respect to any of the events described in clauses (i) and (ii) above, such event results in any person (or group of persons acting in concert) gaining control of more seats on the board of directors of EFH Corp. than the Sponsor Group. However, the Long-Term Incentive Plan also provides that should a change in control occur under clauses (i) through (iii) above with respect to the assets or capital stock of EFH Corp., a change in control will not be deemed to have occurred unless the change in control would result in the material amendment or interference with the separateness undertakings set forth in our Limited Liability Company Agreement, or would adversely change or modify the definition of an independent director in our Limited Liability Company Agreement.

As the administrator of the Long-Term Incentive Plan, the O&C Committee has the authority to prescribe, amend and rescind rules and regulations relating to the plan, determine the terms and conditions of any awards and make all other determinations deemed necessary or advisable for the administration of the plan. The O&C Committee has broad discretion under the plan and may delegate to one or more officers of the company the authority to grant Long-Term Incentive Plan awards to employees who are not executive officers. Our board of directors may at any time terminate, alter, amend or suspend the Long-Term Incentive Plan and any awards granted pursuant to it, subject to certain limitations. In the event of a change in control, our board of directors may, in its discretion, terminate the plan and cancel all outstanding and unpaid awards, except that in the event of a termination of the plan in connection with a change in control, participants will be entitled to receive the payout as described above. Payments under the Long-Term Incentive Plan are separate from, and would be in addition to, any payments available under the Change in Control Policy or Severance Plan.

Pension Benefits

The following table sets forth information regarding Oncor’s participation in the retirement plans that provide for benefits, in connection with, or following, the retirement of Named Executive Officers for the fiscal year ended December 31, 2019:

Name	Plan Name	Number of Years Accredited Service (#)(1)		Present Value of Accumulated Benefit ($)		Payments During Last Fiscal Year ($)
E. Allen Nye, Jr.	Oncor Retirement Plan		8.0000		128,844	—
	Supplemental Retirement Plan		8.0000		306,587	—
Don J. Clevenger	Oncor Retirement Plan		14.6667		248,321	—
	Supplemental Retirement Plan		14.6667		240,711	—
Deborah L. Dennis	Oncor Retirement Plan		40.0833		3,301,049	—
	Supplemental Retirement Plan		40.0833		1,554,574	—
James A. Greer	Oncor Retirement Plan		34.5000		2,721,185	—
	Supplemental Retirement Plan		34.5000		3,791,432	—
Matthew C. Henry(2)	Oncor Retirement Plan		0.7500		16,017	—
	Supplemental Retirement Plan		0.7500		5,823	—

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(1) Accredited service for each of the plans is determined based on an employee’s age and hire date. Employees hired by Oncor or an EFH Corp. affiliate prior to January 1, 1985 became eligible to participate in the plan the month after their completion of one year of service and attainment of age 25. Employees hired after January 1, 1985 became eligible to participate in the plan the month after their completion of one year of service and attainment of age 21.

(2) Mr. Henry became eligible to participate in the plans in 2019 upon completion of the required one-year of service.

The Oncor Retirement Plan contains both a traditional defined benefit component and a cash balance component. Only employees hired before January 1, 2002 may participate in the traditional defined benefit component. All new employees hired after January 1, 2002 participate in the cash balance component. In addition, the cash balance component covers employees previously covered under the traditional defined benefit component who elected to convert the actuarial equivalent of their accrued traditional defined benefit to the cash balance component during a special one-time election opportunity effective in 2002. The employees that participate in the traditional defined benefit component do not participate in the cash balance component.

Annual retirement benefits under the traditional defined benefit component, which applied during 2019 to Ms. Dennis and Mr. Greer, are computed as follows: for each year of accredited service up to a total of 40 years, 1.3% of the first $7,800, plus 1.5% of the excess over $7,800, of the participant’s average annual earnings (base salary) during his/her three years of highest earnings. Under the cash balance component, which covers Messrs. Nye, Clevenger, and Henry, a hypothetical account is established for participants and credited with monthly contribution credits equal to a percentage of the participant’s compensation (3.5%, 4.5%, 5.5% or 6.5% depending on the participant’s combined age and years of accredited service), plus interest credits based on the average yield of the 30-year Treasury bond for the 12 months ending November 30 of the prior year. Benefits paid under the traditional defined benefit component of the Oncor Retirement Plan are not subject to any reduction for Social Security payments but are limited by provisions of the Code.

The Supplemental Retirement Plan provides for the payment of retirement benefits, which would otherwise be limited by the Code or the definition of earnings under the Oncor Retirement Plan, including any retirement compensation required to be paid pursuant to contractual arrangements. Under the Supplemental Retirement Plan, retirement benefits are calculated in accordance with the same formula used under the Oncor Retirement Plan, except that, with respect to calculating the portion of the Supplemental Retirement Plan benefit attributable to service under the traditional defined benefit component of the Oncor Retirement Plan, earnings also include Executive Annual Incentive Plan awards. The amount of earnings attributable to the Executive Annual Incentive Plan awards is reported under the Non-Equity Incentive Plan Compensation column of the Summary Compensation Table.

The table set forth above illustrates the present value on December 31, 2019 of each Named Executive Officer’s Retirement Plan benefit and benefits payable under the Supplemental Retirement Plan, based on his or her years of service and remuneration through December 31, 2019. Benefits accrued under the Supplemental Retirement Plan after December 31, 2004 are subject to Section 409A of the Code. Accordingly, certain provisions of the Supplemental Retirement Plan have been modified in order to comply with the requirements of Section 409A and related guidance.

The present value of accumulated benefits for the traditional benefit component of the Oncor Retirement Plan and the Oncor Supplemental Retirement Plan was calculated based on the executive’s annuity payable at the earliest age that unreduced benefits are available under the Plans (generally age 62). Unmarried executives are assumed to elect a single life annuity. For married executives, it is assumed that 60% will elect a 100% joint and survivor annuity and 40% will elect a single life annuity. Post-retirement mortality was based on the Pri-2012 amount-weighted mortality table published by the Society of Actuaries projected generationally from 2012 with scale MP-2019. A discount rate of 3.12% was applied and no pre-retirement mortality or turnover was reflected.

The present value of accumulated benefits for the cash balance component of the Oncor Retirement Plan and the Oncor Supplemental Retirement Plan was calculated as the value of the executive’s cash balance account projected to age 65 at an assumed growth rate of 3.50% and then discounted back to December 31, 2019, at 3.12%. No mortality or turnover assumptions were applied.

Early retirement benefits under the Oncor Retirement Plan are available to our employees covered in the traditional defined benefit component upon their attainment of age 55 and achievement of 15 years of accredited service. Early retirement results in a retirement benefit payment reduction of 4% for each full year (and 0.333% for each additional full calendar month) between the date the participant retires and the date the participant would reach age 62. Participants in the cash balance component of the Oncor Retirement Plan can receive their benefit upon retirement or upon severance of service with the Company. Benefits under the Supplemental Retirement Plan are tied to a participant’s coverage under the Oncor Retirement Plan. For participants in the cash balance program of the Oncor Retirement Plan, Supplemental Retirement Plan benefits are payable upon the later of achievement of 10 years of accredited service or the date the participant would have

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accumulated 10 years of accredited service but for the participant’s separation from service. For participants in the traditional defined benefit component of the Oncor Retirement Plan, Supplemental Retirement Plan benefits are payable in an annuity on the later of (i) the first day of the second month after a participant’s separation from service or (ii) the earliest date the participant would be eligible to commence benefits under the Oncor Retirement Plan. For either traditional defined benefit component or cash balance component participants, Supplemental Retirement Plan benefits are payable upon a separation of service if the total benefit amount is less than the limit set under Section 402(g)(1)(B) of the Code ($19,000 in 2019). Benefits under the Supplemental Retirement Plan are only available to our executive officers and certain other key employees.

Nonqualified Deferred Compensation – 2019

The following table sets forth information regarding the deferral of components of our Named Executive Officers’ compensation on a basis that is not tax-qualified for the fiscal year ended December 31, 2019:

Name	Executive Contributions in Last Fiscal Year ($)(1)		Registrant Contributions in Last Fiscal Year ($)(2)		Aggregate Earnings (Loss) in Last Fiscal Year ($)		Aggregate Withdrawals/ Distributions ($)			Aggregate Balance at Last Fiscal Year End ($)(3)
E. Allen Nye, Jr.
Salary Deferral Program		74,467		74,467		155,994		(111,691	)		863,796
Don J. Clevenger
Salary Deferral Program		41,087		41,087		146,338		(105,017	)		717,006
Deborah L. Dennis
Salary Deferral Program		30,633		30,633		190,658		—			1,046,508
James A. Greer
Salary Deferral Program		43,827		43,827		173,828		(90,476	)		815,692
Matthew C. Henry
Salary Deferral Program		43,020		43,020		14,346		—			152,577

(1) Amounts in this column for the Salary Deferral Program represent salary deferrals pursuant to the Salary Deferral Program and are included in the “Salary” amounts in the Summary Compensation Table above.

(2) Amounts in this column for the Salary Deferral Program represent company-matching awards pursuant to the Salary Deferral Program and are included in the “All Other Compensation” amounts in the Summary Compensation Table above.

(3) $279,434, $240,208, $348,185, $271,734, and $26,096 represent company match accounts prior to 2019 for Mr. Nye, Clevenger, Ms. Dennis, Mr. Greer, and Mr. Henry, respectively, and as a result to the extent any were Named Executive Officers in previous years were included as compensation in the Summary Compensation Table in previous years for the year earned, as applicable.

Salary Deferral Program

Under the Salary Deferral Program, each employee of Oncor, who is in a designated job level and whose annual salary is equal to or greater than an amount established under the Salary Deferral Program ($129,640 for the program year beginning January 1, 2019) may elect to defer up to 50% of annual base salary, and/or up to 85% of any bonus or incentive award. This deferral (including any vested matching contributions, as described below) may be made for a period of seven years, for a period ending with the retirement of such employee, or for a combination thereof, at the election of the employee. Oncor makes a matching award, subject to forfeiture under certain circumstances, equal to 100% of up to the first 8% of base salary deferred under the Salary Deferral Program. Oncor does not match deferred annual incentive awards. Matching contributions vest at the earliest of seven years after the deferral date, retirement, death, disability or termination without cause following a change in control of Oncor (as defined in the Salary Deferral Program). Deferrals are credited with earnings or losses based on the performance of investment alternatives under the Salary Deferral Program selected by each participant.

Additionally, Oncor, at the direction of the O&C Committee, can make additional discretionary contributions into a Salary Deferral Program participant’s account. Discretionary contributions made into a Salary Deferral Program participant’s account by Oncor vest as determined by the O&C Committee.

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At the end of the applicable account maturity period (seven years or retirement, as elected by the participant or, in the case of company discretionary contributions, as determined by the O&C Committee) the trustee for the Salary Deferral Program distributes the deferrals and the applicable earnings in cash as a lump sum or in annual installments at the participant’s election made at the time of deferral. Oncor is financing the retirement option of the Salary Deferral Program through the purchase of corporate-owned life insurance on lives of some participants. The proceeds from such insurance are expected to allow us to fully recover the cost of the retirement option.

Potential Payments upon Termination or Change in Control

The tables and narrative below provide information for payments to Oncor’s Named Executive Officers (or, as applicable, enhancements to payments or benefits) in the event of termination including retirement, voluntary, for cause, death, disability, without cause or change in control of Oncor. The amounts shown below for current executive officers assume that such a termination of employment and/or change in control occurred on December 31, 2019.

In 2019, all of our executive officers were eligible to receive benefits under the terms of the Change in Control Policy and the Severance Plan, as more fully described following the tables below. In addition to the provisions of those plans, the Salary Deferral Program provides that all company-matching awards will become automatically vested in the event of a termination without cause following a change in control, death, disability or retirement. The amounts listed in the tables below regarding the Salary Deferral Program only represent the immediate vesting of company matching contributions resulting from death, disability, retirement or a termination without cause following the occurrence of a change in control. Contributions made to such plan by each Named Executive Officer are disclosed in the Nonqualified Deferred Compensation table above. For a more detailed discussion of the Salary Deferral Program, see the Nonqualified Deferred Compensation table above and the narrative following the Nonqualified Deferred Compensation table.

Retirement benefits under the Oncor Retirement Plan and Supplemental Retirement Plan are available to participants upon their attainment of age 65. Early retirement benefits under the Oncor Retirement Plan are available to our employees covered in the traditional defined benefit component upon their attainment of age 55 and achievement of 15 years of accredited service. Early retirement results in a retirement benefit payment reduction of 4% for each full year (and 0.333% for each additional full calendar month) between the date the participant retires and the date the participant would reach age 62. Participants in the cash balance component of the Oncor Retirement Plan can receive their benefit upon retirement or upon severance of service with the Company. Benefits under the Supplemental Retirement Plan are tied to a participant’s coverage under the Oncor Retirement Plan. For participants in the cash balance program of the Oncor Retirement Plan, Supplemental Retirement Plan benefits are payable upon the later of achievement of 10 years of accredited service or the date the participant would have accumulated 10 years of accredited service but for the participant’s separation from service. For participants in the traditional defined benefit component of the Oncor Retirement Plan, Supplemental Retirement Plan benefits are payable in an annuity on the later of (i) the first day of the second month after a participant’s separation from service or (ii) the earliest date the participant would be eligible to commence benefits under the Oncor Retirement Plan. For either traditional defined benefit component or cash balance component participants, Supplemental Retirement Plan benefits are payable upon a separation of service if the total benefit amount is less than the limit set under Section 402(g)(1)(B) of the Code ($19,000 in 2019). Messrs. Nye, Clevenger and Henry participate in the cash balance component and as a result can elect to receive their Oncor Retirement Plan benefits as a lump sum upon separation of service. In addition, since he has accumulated over 10 years of accredited service, Mr. Clevenger would receive his Supplemental Retirement Plan benefits as a lump sum upon separation of service. As of December 31, 2019, Mr. Henry would have received his Supplemental Retirement Plan benefits as a lump sum if he had experienced a separation of service since he had less than $19,000 in aggregate benefits. As Mr. Nye has not yet achieved ten years of service and has a Supplemental Retirement Plan benefit that exceeds the limit set forth in Code Section 402(g)(1)(B), upon a separation of service he would receive his Supplemental Retirement Plan benefits upon the later of (i) separation of service or (ii) the date he would have achieved ten years of accredited service absent the separation of service. Ms. Dennis and Mr. Greer participate in the traditional defined benefit component of the retirement plans. Since both Ms. Dennis and Mr. Greer have satisfied the age requirement and 15 years of accredited service, they are eligible to retire early upon termination of employment. No additional potential payments will be triggered by any termination of employment or change in control, and as a result no amounts are reported in the tables below for such retirement plans. For a more detailed discussion of the retirement plans, see the Pension Benefits table above and the narrative following the Pension Benefits table.

All our Named Executive Officers participate in benefit plans for group term life insurance and accidental death and disability. Any benefits received under these policies are paid to the beneficiary by a third-party provider.

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1. Mr. Nye

Potential Payments to Mr. Nye Upon Termination ($)

Benefit	Voluntary		For Cause		Death		Disability		Without Cause or For Good Reason(1)		Without Cause or For Good Reason in Connection with Change in Control(2)
Cash Severance		—		—		—		—		4,598,870		6,456,160
Executive Annual Incentive Plan		—		—		884,290		884,290		—		—
Salary Deferral Program(3)		—		—		371,758		371,758		—		371,758
Long-Term Incentive Plan(4)		765,440		—		3,173,076		3,173,076		3,173,076		3,173,076
Performance Bonus Agreement		1,864,800		—		1,864,800		1,864,800		1,864,800		1,864,800
Health & Welfare
– Medical/COBRA		—		—		—		—		58,074		58,074
– Dental/COBRA		—		—		—		—		3,990		3,990
Outplacement Assistance		—		—		—		—		40,000		40,000
Totals		2,630,240		—		6,293,924		6,293,924		9,738,810		11,967,858

(1) Reflects amounts payable pursuant to the Severance Plan.

(2) Reflects amounts payable pursuant to the Change in Control Policy. Cash severance amount reflects both the cash severance payment and pro rata target bonus amount payable pursuant to that policy.

(3) Amounts reported reflect the immediate vesting of unvested company matching contributions resulting from death, disability or the occurrence of termination without cause following a change in control. The Salary Deferral Program does not contain provisions relating to a termination for good reason.

(4) Amounts reported reflect the combined amount of outstanding grants to the executive under the Long-Term Incentive Plan and assumes that target performance for each performance period was met.

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2. Mr. Clevenger

Potential Payments to Mr. Clevenger Upon Termination ($)

Benefit	Voluntary		For Cause		Death		Disability		Without Cause or For Good Reason(1)		Without Cause or For Good Reason in Connection with Change in Control(2)
Cash Severance		—		—		—		—		875,829		2,961,316
Executive Annual Incentive Plan		—		—		333,829		333,829		—		—
Salary Deferral Program(3)		—		—		301,671		301,671		—		301,671
Long-Term Incentive Plan(4)		681,536		—		1,413,433		1,413,433		1,413,433		1,413,433
Health & Welfare
– Medical/COBRA		—		—		—		—		38,716		38,716
– Dental/COBRA		—		—		—		—		2,660		2,660
Outplacement Assistance		—		—		—		—		25,000		25,000
Totals		681,536				2,048,933		2,048,933		2,355,638		4,742,796

(1) Reflects amounts payable pursuant to the Severance Plan.

(2) Reflects amounts payable pursuant to the Change in Control Policy. Cash severance amount reflects both the cash severance payment and pro rata target bonus amount payable pursuant to that policy.

(3) Amounts reported reflect the immediate vesting of unvested company matching contributions resulting from death, disability or the occurrence of a termination without cause following a change in control. The Salary Deferral Program does not contain provisions relating to termination for good reason.

(4) Amounts reported reflect the combined amount of outstanding grants to the executive under the Long-Term Incentive Plan and assumes that target performance for each performance period was met.

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3. Ms. Dennis

Potential Payments to Ms. Dennis Upon Termination ($)

Benefit	Retirement(1)		Voluntary		For Cause		Death		Disability		Without Cause or For Good Reason(2)		Without Cause or For Good Reason in Connection with Change in Control(3)
Cash Severance		—		—		—		—		—		800,231		1,554,685
Executive Annual Incentive Plan		248,895		—		—		248,895		248,895		—		—
Salary Deferral Program(4)		—		—		—		—		—		—		—
Long-Term Incentive Plan(5)		629,585		297,472		—		629,585		629,585		629,585		629,585
Health & Welfare
– Medical/COBRA		—		—		—		—		—		26,583		26,583
– Dental/COBRA		—		—		—		—		—		1,749		1,749
Outplacement Assistance		—		—		—		—		—		25,000		25,000
Totals		878,480		297,472		—		878,480		878,480		1,483,148		2,237,602

(1) Ms. Dennis participates in the traditional defined benefit component of the Oncor Retirement Plan and the Supplemental Retirement Plan, and because she has reached age 55 and achieved 15 years of accredited service, under the terms of the plans she is eligible to retire early upon termination of employment.

(2) Reflects amounts payable pursuant to the Severance Plan.

(3) Reflects amounts payable pursuant to the Change in Control Policy. Cash severance amount reflects both the cash severance payment and pro rata target bonus amount payable pursuant to that policy.

(4) Amounts reported reflect the immediate vesting of unvested company matching contributions resulting from retirement, death, disability or the occurrence of a termination without cause following a change in control. The Salary Deferral Program does not contain provisions relating to termination for good reason. Ms. Dennis was fully vested in the Salary Deferral Program as of December 31, 2019.

(5) Amounts reported reflect the combined amount of outstanding grants to the executive under the Long-Term Incentive Plan and assumes that target performance for each performance period was met.

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4. Mr. Greer

Potential Payments to Mr. Greer Upon Termination ($)

Benefit	Retirement(1)		Voluntary		For Cause		Death		Disability		Without Cause or For Good Reason(2)		Without Cause or For Good Reason in Connection with Change in Control(3)
Cash Severance		—		—		—		—		—		928,462		2,204,273
Executive Annual Incentive Plan		356,091		—		—		356,091		356,091		—		—
Salary Deferral Program(4)		251,585		—		—		317,124		317,124		—		317,124
Long-Term Incentive Plan(5)		1,558,455		708,032		—		1,558,455		1,558,455		1,558,455		1,558,455
Performance Bonus Agreement		159,840		159,840		—		159,840		159,840		159,840		159,840
Health & Welfare
– Medical/COBRA		—		—		—		—		—		38,716		38,716
– Dental/COBRA		—		—		—		—		—		2,644		2,644
Outplacement Assistance		—		—		—		—		—		25,000		25,000
Totals		2,325,971		867,872		—		2,391,510		2,391,510		2,713,117		4,306,052

(1) Mr. Greer participates in the traditional defined benefit component of the Oncor Retirement Plan and the Supplemental Retirement Plan, and because he has reached age 55 and achieved 15 years of accredited service, under the terms of the plans he is eligible to retire early upon termination of employment.

(2) Reflects amounts payable pursuant to the Severance Plan.

(3) Reflects amounts payable pursuant to the Change in Control Policy. Cash severance amount reflects both the cash severance payment and pro rata target bonus amount payable pursuant to that policy.

(4) Amounts reported reflect the immediate vesting of unvested company matching contributions resulting from death, disability or the occurrence of a termination without cause following a change in control. The Salary Deferral Program does not contain provisions relating to termination for good reason.

(5) Amounts reported reflect the combined amount of outstanding grants to the executive under the Long-Term Incentive Plan and assumes that target performance for each performance period was met.

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5. Mr. Henry

Potential Payments to Mr. Henry Upon Termination ($)

Benefit	Voluntary		For Cause		Death		Disability		Without Cause or For Good Reason(1)		Without Cause or For Good Reason in Connection with Change in Control(2)
Cash Severance		—		—		—		—		906,537		3,069,148
Executive Annual Incentive Plan		—		—		349,537		349,537		—		—
Salary Deferral Program(3)		—		—		76,288		76,288		—		76,288
Long-Term Incentive Plan(4)		—		—		767,683		767,683		767,683		767,683
Retention Agreement		—		—		888,470		888,470		888,470		888,470
Health & Welfare
- Medical/COBRA		—		—		—		—		38,716		38,716
- Dental/COBRA		—		—		—		—		2,660		2,660
Outplacement Assistance		—		—		—		—		25,000		25,000
Totals		—		—		2,081,978		2,081,978		2,629,066		4,867,965

(1) Reflects amounts payable pursuant to the Severance Plan.

(2) Reflects amounts payable pursuant to the Change in Control Policy. Cash severance amount reflects both the cash severance payment and pro rata target bonus amount payable pursuant to that policy.

(3) Amounts reported reflect the immediate vesting of unvested company matching contributions resulting from death, disability or the occurrence of termination without cause following a change in control. The Salary Deferral Program does not contain provisions relating to a termination for good reason.

(4) Amounts reported reflect the combined amount of outstanding grants to the executive under the Long-Term Incentive Plan and assumes that target performance for each performance period was met.

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Change in Control Policy

We maintain a Change in Control Policy for our executive team, which consists of our executive officers and certain non-executive vice presidents. The purpose of this Change in Control Policy is to provide the payment of transition benefits to eligible executives if:

• Their employment with the company or a successor is terminated within twenty-four months following a change in control of the company; and

• They:

- are terminated without cause, or

- resign for good reason.

The Change in Control Policy provides for the payment of transition benefits to eligible executives if any of the following occur within 24 months following a change in control:

• The executive is terminated without cause. Cause is defined as either (a) the definition in any executive’s applicable employment agreement or change in control agreement or (b) if there is no such employment or change in control agreement, cause exists: (i) if, in carrying out his or her duties to Oncor, an executive engages in conduct that constitutes (A) a breach of his or her fiduciary duty to Oncor, its subsidiaries or shareholders, (B) gross neglect or (C) gross misconduct resulting in material economic harm to Oncor or its subsidiaries, taken as a whole, or (ii) upon the indictment of the executive, or the plea of guilty or nolo contendere by the executive to, a felony or a misdemeanor involving moral turpitude.

• The executive resigns for good reason. Good reason is defined as any of the following events or actions being taken without the executive’s consent: (a) a material reduction in the executive’s base salary, other than a broad-based reduction of base salaries of all similarly situated executives of the surviving corporation after a change in control, or subsidiary, as applicable, unless such broad-based reduction only applies to former executives of Oncor; (b) a material reduction in the aggregate level or value of benefits for which the executive is eligible, immediately prior to the change in control (as defined below), other than a broad-based reduction applicable on a comparable basis to all similarly situated executives; (c) a material reduction in the executive’s authority, duties, responsibilities or title, including a material reduction in the budget over which the executive retains authority; (d) the executive is required to permanently relocate outside of a fifty (50) mile radius of the executive’s principal residence; (e) the executive is asked or required to resign in connection with a change in control and does so resign; or (f) an adverse change in the executive’s (i) reporting level or responsibilities, (ii) title and/or scope of responsibility, (iii) management authority, or (iv) the scope or size of the business or entity for which the executive had responsibility, in each case as in effect immediately prior to the effective time of a change in control.

“Change in control” is defined in the Change in Control Policy as the occurrence of the following events: (a) the Sponsor Group ceases to beneficially own (within the meaning of Rule 13d-3 of the Securities Exchange Act of 1934, as amended) a majority of our or our successor’s (by consolidation or merger) outstanding equity interest; (b) any sale, lease, exchange or other transfer (in one transaction or in a series of related transactions) of all, or substantially all, of our assets, other than to an entity (or entities) of which the Sponsor Group beneficially owns a majority of the outstanding equity interest; (c) individuals who as of August 1, 2015 constitute our board of directors (the Incumbent Board) cease for any reason to constitute at least a majority thereof, provided that any person becoming a director subsequent to August 1, 2015 whose election or nomination for election was approved by a vote of at least seventy-five percent (75%) of the directors comprising the Incumbent Board shall be, for purposes of this clause (c) considered as though such person were a member of the Incumbent Board; or (d) the consummation of a court-approved plan of reorganization in the proceeding styled In re Energy Future Holdings Corp., et al., Case No. 14-10979 (CSS), pending in the United States Bankruptcy Court for the District of Delaware. For purposes of this definition, the term “Sponsor Group” shall mean investment funds affiliated with Kohlberg Kravis Roberts & Co. L.P., TPG Capital, L.P. and Goldman Sachs & Co.

Our executive officers are eligible to receive the following under the Change in Control Policy:

• A one-time lump sum cash severance payment in an amount equal to the greater of (i) a multiple (3 times for our chief executive, our chief financial officer and our general counsel (Messrs. Nye, Clevenger, and Henry), and 2 times for each other executive officer) of the sum of the executive’s (a) annualized base salary and (b) annual target incentive award for the year of termination or resignation, or (ii) the amount determined under Oncor’s severance plan for non-executive employees (which pays two weeks of an employee’s pay for every year of service up to the 20^th year of service, and three-weeks’ pay for every year of service above 20 years of service);

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• A cash bonus in an amount equal to a pro rata portion of the executive’s target annual incentive award for the year of termination;

• Continued coverage at our expense under our health care benefit plans for the applicable COBRA period with the executive’s contribution for such plans being at the applicable employee rate for 18 months (unless and until the executive becomes eligible for benefits with another employer) and, if the executive is covered under our healthcare plans through the end of such period, at the end of such continued coverage the executive may continue participation in our health care plans at the applicable COBRA rate for 18 months, in the case of the chief executive officer or six months, in the case of each other executive, and Oncor will reimburse the executive the monthly difference between the applicable employee rate for such coverage and the COBRA rate paid by the executive for such period;

• Outplacement assistance at our expense for 18 months, in the case of the Chief Executive, and one year, in the case of the other executive officers, up to a maximum of $40,000 for the chief executive officer, and $25,000 for other executives;

• Reimbursement of reasonable legal fees and expenses incurred by an executive in disputing in good faith the benefits under the plan, up to a maximum of $250,000;

• Any vested, accrued benefits to which the executive is entitled under our employee benefits plans; and

• If any of the severance benefits described in the Change in Control Policy shall result in an excise tax pursuant to Code Sections 280G or 4999 of the Code, payable by the executive, a tax gross-up payment to cover such additional taxes, subject to reduction for certain Section 280G purposes.

The Change in Control Policy contains a one year non-solicitation period and provisions regarding confidentiality and non-disparagement and attaches a form of release agreement that each executive is required to sign prior to receipt of benefits under the policy. The Change in Control Policy also provides that for a period of one year after a termination contemplated by the plan, a participant may not recruit, solicit, induce or in any way cause any employee, consultant or contractor engaged by Oncor to terminate his/her relationship with Oncor. The Change in Control Policy may be amended by our board of directors or a duly authorized committee of our board of directors at any time, except that any amendments that materially decrease the benefits available to eligible participants cannot be made within 24 months of a change in control or while the company is in the process of negotiating a potential transaction that could constitute a change in control.

Severance Plan

We maintain the Severance Plan for our executive team, which consists of our executive officers and certain non-executive vice presidents. The purpose of the Severance Plan is to provide benefits to eligible executives who are not eligible for severance pursuant to another plan or agreement (including an employment agreement) and whose employment is involuntarily terminated for reasons other than:

• Cause;

• Disability of the employee, if the employee is a participant in our long-term disability plan, or

• A transaction involving the company or any of its affiliates in which the employee is offered employment with a company involved in, or related to, the transaction.

The Severance Plan provides for severance payments to executives whose employment is involuntarily terminated for reasons other than:

• Cause, which is defined as either (a) the definition in any executive’s applicable employment agreement or change in control agreement or, (b) if there is no such employment or change in control agreement, cause exists: (i) if, in carrying out his or her duties to the Company, an executive engages in conduct that constitutes (A) a breach of his or her fiduciary duty to Oncor, its subsidiaries or shareholders (including a breach or attempted breach of the restrictive covenants under the Severance Plan), (B) gross neglect or (C) gross misconduct resulting in material economic harm to Oncor or its subsidiaries, taken as a whole, or (ii) upon the indictment of the executive, or the plea of guilty or nolo contendere by the executive to a felony or a misdemeanor involving moral turpitude;

• Participation in our employee long-term disability plan or any successor plan, or

• A transaction involving the Company or any of its affiliates in which the executive is offered employment with a company involved in, or related to, the transaction.

Our executive officers are eligible to receive the following under the Severance Plan:

• For covered executives other than our Chief Executive, a one-time lump sum cash severance payment in an amount equal to the greater of (i) the covered executive’s annualized base salary in effect immediately before the termination, plus the covered executives target annual incentive award for the year of the termination, or (ii) the amount determined under Oncor’s severance plan for non-executive employees;

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• For our Chief Executive, a one-time lump sum cash severance payment in an amount equal to the greater of: (i) (a) a multiple of two times base salary in effect immediately before the termination plus a multiple of two times the target annual incentive award for the year of termination, plus (b) the target annual incentive award for the year of the termination, or (ii) the amount determined under the Oncor Severance Plan for non-executive employees.

• Continued coverage at our expense under the Company’s health care benefit plans for 18 months, with the executive’s contribution for such plans being at the applicable employee rate (unless and until the executive becomes eligible for coverage for benefits through employment with another employer, at which time the executive’s required contribution shall be the applicable COBRA rate) and, if the executive is covered under our healthcare plans through the end of such period, at the end of such continued coverage the executive may continue participation in our health care plans at the applicable COBRA rate for 18 months, in the case of the chief executive officer, or six months, in the case of each other executive, and Oncor will reimburse the executive the monthly difference between the applicable employee rate for such coverage and the COBRA rate paid by the executive for such period;

• Outplacement assistance at the company’s expense for 18 months, in the case of the Chief Executive, and one year, in the case of other executive officers, up to a maximum of $40,000 for the Chief Executive, and $25,000 for other executives, and

• Any vested accrued benefits to which the executive is entitled under Oncor’s employee benefits plans.

In order to receive benefits under the plan, a participant must enter into an agreement and release within 45 days of being notified by us of such participant’s eligibility to receive benefits under the plan. The Severance Plan also provides that for a period of one year after a termination contemplated by the plan, a participant may not recruit, solicit, induce or in any way cause any employee, consultant or contractor engaged by Oncor to terminate his/her relationship with Oncor. The Severance Plan also contains provisions relating to confidentiality and non-disparagement.

Long-Term Incentive Plan

For information concerning change of control and termination payouts for awards granted under the Long-Term Incentive Plan, see the narrative that follows the Grants of Plan-Based Awards – 2019 table.

Performance Bonus Agreements

In February 2018, we entered into performance bonus agreements with each of Mr. Nye and Mr. Greer that were effective upon closing of the Sempra Acquisition and provided for a performance bonus opportunity to each executive for each of the 2018 and 2019 fiscal years. Under the terms of the performance bonus agreements, if the executive was employed by Oncor or an affiliate of Oncor on the last day of the 2018 or 2019 fiscal years, and his employment with Oncor or such affiliate terminated for any reason other than by Oncor or such affiliate for cause (as defined in the applicable performance bonus agreement) prior to the payment of the performance bonus for that fiscal year, the executive would be entitled to receive any earned performance bonus at the same time it would have been paid if the executive had remained an employee. If the executive were terminated for cause, or ceased employment with Oncor or such affiliate for reasons other than death, disability, retirement or a termination following a change in control, all of his outstanding and unpaid performance bonuses would be forfeited. In the event of a separation from service due to death, disability or retirement (other than a retirement that is also a termination following a change in control), the executive would be entitled to, for each outstanding and unpaid performance bonus, payment of an amount equal to the product of (i) a fraction, the numerator of which is the number of days in the fiscal year in which the separation of service occurred, up to and including the date of the executive’s separation from service, and the denominator of which is 365; and (ii) the performance bonus amount that would be payable for that fiscal year based on Oncor’s performance bonus funding percentage for that fiscal year. In the event of a termination following a change in control, the executive would be entitled to, for each outstanding and unpaid performance bonus, payment within 60 days following his separation from service of an amount equal to (i) a fraction, the numerator of which is the number of days in the fiscal year in which the separation of service occurs, up to and including the date of the executive’s separation from service, and the denominator of which is 365; and (ii) the performance bonus amount that would be payable for that fiscal year based on Oncor’s achievement of the financial plan net income for that year. The “Performance Bonus Agreement” row in each of Mr. Nye’s and Mr. Greer’s Potential Payment Upon Termination or Change in Control table reflects the payments that would be owed pursuant to these agreements in the event of certain terminations of their employment as of December 31, 2019. These agreements cease to apply after the 2019 fiscal year. For more detailed information on the performance bonus agreements, see “Executive Compensation — Individual Named Executive Officer Compensation — Compensatory Agreements —Named Executive Officer Performance Bonus Agreements.”

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CEO Pay Ratio for Fiscal Year 2019

Pay Ratio

Our CEO to median employee pay ratio has been calculated in accordance with the rules under the Dodd-Frank Wall Street Reform and Consumer Protection Act and is calculated in a manner consistent with Item 402(u) of Regulation S-K. Mr. Nye’s annual total compensation for 2019, as shown in the Summary Compensation Table above, was $5,363,749.

The median Oncor employee’s annual total compensation in 2019 (other than Mr. Nye) was $180,100, calculated using the same methodology as used in the calculation of the Summary Compensation Table, consisting of base salary, bonus, non-equity incentive plan compensation, change in pension value and non-qualified deferred compensation earnings, and all other compensation (for the median employee, all other compensation consisted of the Oncor Thrift Plan company match). As a result, the ratio of Mr. Nye’s annual total compensation in 2019 to the median annual total compensation of all Oncor employees (other than Mr. Nye) in 2019 was 30:1, when calculated in a manner consistent with Item 402(u) of Regulation S-K.

Identification of Median Employee

We identified a median employee in 2017 who retired in 2019. Because there have been no meaningful changes to our employee population or a change in employee compensation arrangements that we believe would result in a significant modification to the pay ratio disclosure, for 2019 we have used the 2017 data (excluding the previous median employee, who retired) to identify a new median employee. The new median employee’s compensation is substantially similar to that of the retired previous median employee. To identify the median employee, we evaluated all employees, other than the CEO, employed by Oncor as of October 31, 2017 and calculated each such employee’s total cash compensation received through October 31, 2017. Total cash compensation consists of base pay, any incentive compensation, bonuses, and any other cash payments, including, without limitation, any overtime adjustments, overtime meals, taxable reimbursable expenses, holiday pay, and salary deferral program payouts. We did not make any material assumptions, adjustments, or estimates with respect to total cash compensation and we did not annualize the compensation for any full-time employees that were not employed by us for all of 2017. The total compensation of each employee other than the CEO was then ranked lowest to highest to determine the median employee.

Annual Total Compensation

After identifying the median employee based on total cash compensation, as described above, we calculated annual total compensation for such employee using the same methodology we use for our Named Executive Officers as set forth in the Summary Compensation Table above.

Risk Assessment of Compensation Policies and Practices

The O&C Committee reviews the compensation policies and practices applicable to Oncor’s employees (both executive and non-executive) annually during the first quarter of the year in order to determine whether such compensation policies and practices create risks that are reasonably likely to have a material adverse effect on Oncor. In February 2020 the O&C Committee concluded that current compensatory policies and practices do not create risks that are reasonably likely to have a material adverse effect on Oncor. In arriving at this conclusion, the O&C Committee discussed with management the various compensation policies and practices of the company and the compensation payable pursuant to each, and evaluated whether the compensation payable under each plan or policy could result in (i) incenting employees to take risks that could result in a material adverse effect to Oncor, or (ii) payments by the company significant enough to cause a material adverse effect to Oncor.

We believe that the following factors in our employee compensation program limit risks that could be reasonably likely to have a material adverse effect on the company:

• Our compensation program is designed to provide a mix of base salary, annual cash incentives and (for eligible employees) long-term cash incentives, which we believe motivates employees to perform at high levels while mitigating any incentive for short-term risk-taking that could be detrimental to our company’s long-term best interests.

• Our annual cash incentives for both executives and non-executives contain maximum payout levels, which help avoid excessive total compensation and reduce the incentive to engage in unnecessarily risky behavior.

• The funding percentages under the Executive Annual Incentive Plan and the non-executive employee annual incentive plan are based on the performance of our total company, which mitigates any incentive to pursue strategies that might maximize the performance of a single business group to the detriment of the company as a whole.

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• We place an emphasis on individual, non-financial performance metrics in determining individual compensation amounts, serving to restrain the influence of objective factors on incentive pay and providing management (in the case of non-executive employees) and the O&C Committee (in the case of executive employees) the discretion to adjust compensation downward if behaviors are not consistent with Oncor’s business values and objectives.

• Long-term incentives for eligible employees under the Long-Term Incentive Plan are measured over three years to ensure employees have significant value tied to the long-term performance of the company.

• We have internal controls over financial reporting and other financial, operational and compliance policies and practices designed to keep our compensation programs from being susceptible to manipulation by any employee, including our executive officers.

DIRECTOR COMPENSATION

The O&C Committee determines compensation for members of our board of directors. Directors who are current officers of Oncor and the member directors designated by each of Sempra (through Oncor Holdings) and Texas Transmission do not receive any fees for service as a director. See “Directors, Executive Officers and Corporate Governance – Director Appointments” for information regarding the designation of member directors. Oncor reimburses all directors for reasonable expenses incurred in connection with their services as directors.

The table below sets forth information regarding the aggregate compensation paid to the members of our board of directors during the fiscal year ended December 31, 2019, other than E. Allen Nye, Jr., whose compensation from Oncor is discussed in “Executive Compensation – Summary Compensation Table.” Mr. Nye did not receive any compensation for service on our board of directors.

Name	Director Fees Earned or Paid in Cash ($)		Total ($)
James R. Adams (1)		226,250		226,250
George W. Bilicic (2)		—		—
Thomas M. Dunning (3)		276,250		276,250
Robert A. Estrada (4)		242,500		242,500
Rhys Evenden (5)		—		—
Printice L. Gary (6)		226,250		226,250
William T. Hill, Jr. (7)		241,250		241,250
Timothy A. Mack (8)		226,250		226,250
Jeffrey W. Martin (9)		—		—
Helen Newell (10)		—		—
Tania Ortiz (11)		—		—
Robert S. Shapard (12)		476,250		476,250
Richard W. Wortham III (13)		241,250		241,250
Steven J. Zucchet (14)		—		—

(1) Mr. Adams’ “Fees Earned or Paid in Cash” column reflects director fees for his service as a director of (i) $56,250 per quarter for the first three quarters of 2019, and (ii) $57,500 for the fourth quarter of 2019.

(2) Mr. Bilicic was appointed to our board of directors by Sempra (through Oncor Holdings) effective August 26, 2019 and served on our board of directors until March 2020. Mr. Bilicic did not receive any compensation for serving as a member of our board of directors.

(3) Mr. Dunning’s “Fees Earned or Paid in Cash” column reflects the following fees, paid quarterly in arrears (i) $56,250 per quarter for the first three quarters of 2019 (of which $3,375 was attributable to his service as a member of the board of directors of Oncor Holdings) for his service as a member of our board of directors, (ii) $57,500 for his service on our board of directors in the fourth quarter of 2019 (of which $3,450 was attributable to his service as a member of the board of directors of Oncor Holdings), and (iii) $12,500 per quarter for serving as our lead disinterested director.

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(4) Mr. Estrada’s “Fees Earned or Paid in Cash” column reflects the following fees, paid quarterly in arrears: (i) $56,250 per quarter for the first three quarters of 2019 (of which $3,375 was attributable to his service as a member of the board of directors of Oncor Holdings) for his service as a member of our board of directors, (ii) $57,500 for his service on our board of directors in the fourth quarter of 2019 (of which $3,450 was attributable to his service as a member of the board of directors of Oncor Holdings), (iii) $3,750 per quarter for the first three quarters of 2019 for serving as the chair of the Audit Committee of our board of directors, and (iv) $5,000 for serving as the chair of the Audit Committee of our board of directors in the fourth quarter of 2019.

(5) Mr. Evenden was appointed to our board of directors by Texas Transmission in October 2014 and served until July 30, 2019. Mr. Evenden did not receive any compensation from Oncor for serving on our board of directors.

(6) Mr. Gary’s “Fees Earned or Paid in Cash” column reflects director fees for his service as a director of (i) $56,250 per quarter for the first three quarters of 2019 (of which $3,375 was attributable to his service as a member of the board of directors of Oncor Holdings), and (ii) $57,500 for the fourth quarter of 2019 (of which $3,450 was attributable to his service as a member of the board of directors of Oncor Holdings).

(7) Mr. Hill’s “Fees Earned or Paid in Cash” column reflects the following fees, paid quarterly in arrears (i) $56,250 per quarter for the first three quarters of 2019 (of which $3,375 was attributable to his service as a member of the board of directors of Oncor Holdings) for his service as a member of our board of directors, (ii) $57,500 for his service on our board of directors in the fourth quarter of 2019 (of which $3,450 was attributable to his service as a member of the board of directors of Oncor Holdings), and (iii) $3,750 for serving as the chair of the Nominating and Governance Committee of our board of directors.

(8) Mr. Mack’s “Fees Earned or Paid in Cash” column reflects director fees for his service as a director of (i) $56,250 per quarter for the first three quarters of 2019 (of which $3,375 was attributable to his service as a member of the board of directors of Oncor Holdings), and (ii) $57,500 for the fourth quarter of 2019 (of which $3,450 was attributable to his service as a member of the board of directors of Oncor Holdings).

(9) Mr. Martin was appointed to our board of directors by Sempra (through Oncor Holdings) in March 2018. Mr. Martin does not receive any compensation for serving as a member of our board of directors.

(10) Ms. Newell was appointed to our board of directors by Texas Transmission effective July 30, 2019. Ms. Newell does not receive any compensation from Oncor for serving on our board of directors.

(11) Ms. Ortiz was appointed to our board of directors by Sempra (through Oncor Holdings) effective July 2018 and served until August 26, 2019. Ms. Ortiz did not receive any compensation for serving as a member of our board of directors.

(12) Mr. Shapard’s “Fees Earned or Paid in Cash��� column reflects the following fees, paid quarterly in arrears: (i) $56,250 per quarter for the first three quarters of 2019 (of which $3,375 was attributable to his service as a member of the board of directors of Oncor Holdings) for his service as a member of our board of directors, (ii) $57,500 for his service on our board of directors in the fourth quarter of 2019 (of which $3,450 was attributable to his service as a member of the board of directors of Oncor Holdings), (iii) $68,750 per quarter for the first three quarters of 2019 for serving as the non-executive chairman of our board of directors (of which $4,125 was attributable to his service as chairman of the board of directors of Oncor Holdings), and (iv) $43,750 for serving as the non-executive chairman of our board of directors in the fourth quarter of 2019 (of which $2,625 was attributable to his service as chairman of the board of directors of Oncor Holdings). Mr. Shapard, who retired as Oncor’s CEO in 2018, receives certain payments from Oncor attributable to his prior service as an employee under the Salary Deferral Program. As these payments are attributable solely to his previous employment as an officer and are not related to his service as a director, these amounts are not included in this table as director compensation.

(13) Mr. Wortham’s “Fees Earned or Paid in Cash” column reflects the following fees, paid quarterly in arrears: (i) $56,250 per quarter for the first three quarters of 2019 (of which $3,375 was attributable to his service as a member of the board of directors of Oncor Holdings) for his service as a member of our board of directors, (ii) $57,500 for his service on our board of directors in the fourth quarter of 2019 (of which $3,450 was attributable to his service as a member of the board of directors of Oncor Holdings), and (iii) $3,750 for serving as the chair of the O&C Committee of our board of directors.

(14) Mr. Zucchet was appointed to our board of directors by Texas Transmission in November 2008. Mr. Zucchet does not receive any compensation for service as a member of our board of directors.

The O&C Committee determines director compensation for the disinterested directors on our board of directors and our non-executive chairman of the board. All director fees are paid quarterly, in arrears. Each disinterested director and our non-executive chairman receives a fee for serving on the board of directors. In addition, the chair of each committee, our lead disinterested director, and our non-executive chairman each receive additional fees for serving in such roles. For the first three quarters of 2019, each disinterested director and our non-executive chairman (Mr. Shapard) received a fee of $56,250 for service on our board of directors (of which $3,375 for Messrs. Dunning, Estrada, Gary, Hill, Mack, Shapard, and Wortham was attributable to such director’s service as a member of the board of directors of Oncor Holdings and was paid by Oncor but reimbursed to Oncor by Oncor Holdings). In addition, for the first three quarters of 2019, each board committee chair received an additional $3,750 quarterly fee for the extra responsibilities associated with such position, our lead disinterested director (Mr. Dunning) received an additional $12,500 quarterly fee for the additional duties associated with that position, and our chairman (Mr. Shapard) received an additional $68,750 quarterly fee for the additional duties associated with that position (of which $4,125 was attributable to his service as chairman of the board of directors of Oncor Holdings and was paid by Oncor but reimbursed to Oncor by Oncor Holdings).

In October 2019, the O&C Committee engaged PricewaterhouseCoopers LLP to conduct competitive market analyses of disinterested directors compensation, using the same peer group and methodology used in the October 2019 analysis of

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executive compensation. See “Executive Compensation - Compensation Discussion and Analysis – Overview – Market Data” for a description of this peer group and methodology. As a result of this review, the O&C Committee made the following changes, effective as of the quarter beginning October 1, 2019:

• Increased the base fee paid to disinterested directors and our non-executive chairman for serving on the board of directors to $57,500 per quarter (of which $3,450 for Messrs. Dunning, Estrada, Gary, Hill, Mack, Shapard and Wortham, is attributable to such director’s service as a member of the board of directors of Oncor Holdings and is paid by Oncor but reimbursed to Oncor by Oncor Holdings) to bring total direct compensation for these directors closer to the 50^th percentile of Oncor’s peer group;

• Decreased the non-executive chairman retainer fee to $43,750 per quarter (of which $2,625 is attributable to his service as chairman of the board of directors of Oncor Holdings and is paid by Oncor but reimbursed to Oncor by Oncor Holdings) as the increased responsibilities required of him as a result of the Sempra Acquisition and CEO transition were expected to lessen; and

• Increased the audit committee chair retainer fee to $5,000 per quarter to bring this fee closer to the 50^th percentile of Oncor’s peer group for this position.

Our Limited Liability Company Agreement provides that each of Sempra and Texas Transmission has the right to designate two member directors to our board of directors. None of those four director positions (currently held by Messrs. Martin, Mihalik, and Zucchet and Ms. Newell) receives compensation from us for his or her service as a director. Mr. Nye, our Chief Executive, does not receive compensation for his service as a director. For a description of the independence standards applicable to our disinterested directors, see “Certain Relationships and Related Transactions, and Director Independence.”

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SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED EQUITY HOLDER MATTERS

Equity Compensation Plan Information

As of December 31, 2019, Oncor had no compensation plans in place that authorized the issuance of equity securities of Oncor.

Security Ownership of Equity Interests of Oncor by Certain Beneficial Owners and Management

The following table lists the number of limited liability company membership interests (LLC Units) of Oncor beneficially owned at June 26, 2020 by the holders of more than 5% of our LLC Units, our current directors and the Named Executive Officers listed in “Executive Compensation – Summary Compensation Table.”

The amounts and percentages of LLC Units beneficially owned are reported on the basis of SEC regulations governing the determination of beneficial ownership of securities. Under SEC rules, a person is deemed to be a “beneficial owner” of a security if that person has or shares voting power or investment power, which includes the power to dispose of or to direct the disposition of such security. A person is also deemed to be a beneficial owner of any securities of which that person has a right to acquire beneficial ownership within 60 days. Securities that can be so acquired are deemed to be outstanding for purposes of computing such person’s ownership percentage, but not for purposes of computing any other person’s percentage. Under these rules, more than one person may be deemed to be a beneficial owner of the same securities and a person may be deemed to be a beneficial owner of securities as to which such person has no economic interest.

Name	Amount and Nature of Beneficial Ownership		Percent of Class
Sempra Energy (1)		510,841,625		80.45	%
Texas Transmission Investment LLC (2)		125,412,500		19.75	%
Name of Director or Named Executive Officer
James R. Adams		—		—
Don J. Clevenger		—		—
Deborah L. Dennis		—		—
Thomas M. Dunning		—		—
Robert A. Estrada		—		—
Printice L. Gary		—		—
James A. Greer		—		—
Matthew C. Henry		—		—
William T. Hill, Jr.		—		—
Timothy A. Mack		—		—
Jeffrey W. Martin (3)		—		—
Trevor I. Mihalik (4)		—		—
Helen Newell (5)		—		—
E. Allen Nye, Jr.		—		—
Robert S. Shapard		—		—
Richard W. Wortham III		—		—
Steven J. Zucchet (6)		—		—
All current directors and executive officers as a group (21 persons)		—		—

(1) Reflects 509,587,500 LLC Units of Oncor owned by Oncor Holdings and 1,254,125 LLC Units of Oncor beneficially owned by STIH as a result of its 1% ownership interest in Texas Transmission (as described in more detail in footnote 2 below). The sole member of Oncor Holdings is STIH. The sole member of STIH is STH. STH is wholly owned by Sempra Energy. The address of Oncor Holdings is 1616 Woodall Rodgers Freeway, Dallas, TX 75202 and the address of each of Sempra Energy, STIH and STH is 488 8^th Avenue, San Diego, CA 92101.

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(2) Texas Transmission beneficially owns 125,412,500 LLC Units of Oncor. The sole member of Texas Transmission is Texas Transmission Finco, LLC (TTHC Finco), whose sole member is Texas Transmission Holdings Corporation (TTHC). The address of each of Texas Transmission, TTHC Finco, and TTHC is 1105 North Market Street, Suite 1300, Wilmington, DE 19801. BPC Health Corporation (BPC Health) and Borealis Power Holdings Inc. (Borealis Power) may be deemed, as a result of their ownership of 49.5% of the shares of Class A Common Stock of TTHC (Class A Shares) and 49.5% of the shares of Class B Common Stock of TTHC (Class B Shares), respectively, and certain provisions of TTHC’s Shareholders Agreement (which provide that BPC Health and Borealis Power, when acting together with Cheyne Walk Investment Pte Ltd (Cheyne Walk) or STIH, may direct TTHC in certain matters), to have beneficial ownership of the 125,412,500 LLC Units owned by Texas Transmission. OMERS Administration Corporation (OAC), acting through its infrastructure entity, BPC Penco Corporation, beneficially owns BPC Health and, therefore, OAC may also be deemed to have beneficial ownership of such LLC Units. Borealis Power is wholly owned by Borealis Infrastructure Corporation and Borealis Management Trust owns 70% of the voting shares of Borealis Infrastructure Corporation. The trustee of Borealis Management Trust is Borealis Infrastructure Holdings Corporation and, therefore, Borealis Infrastructure Holdings Corporation may also be deemed to have beneficial ownership of such LLC Units. The address of OAC is 900-100 Adelaide Street West, Toronto, Ontario, Canada M5H OE2. The address of Borealis Infrastructure Holdings Corporation is 333 Bay Street, Suite 2400, Toronto, Ontario, Canada M5H 2T6. Cheyne Walk may be deemed, as a result of its ownership of 49.5% of each of the Class A Shares and the Class B Shares of TTHC, and certain provisions of TTHC’s Shareholders Agreement (which provide that Cheyne Walk, when acting together with BPC Health and Borealis Power or STIH, may direct TTHC in certain matters), to have beneficial ownership of the 125,412,500 LLC Units owned by Texas Transmission. Cheyne Walk shares the power to vote and the power to dispose of 49.5% of each of the Class A Shares and the Class B Shares of TTHC with GIC Special Investments Pte Ltd (GICSI) and GIC Private Limited (GIC), both of which are private limited companies incorporated in Singapore. GICSI is wholly owned by GIC, and is the private equity and infrastructure investment arm of GIC. GIC is wholly owned by the Government of Singapore and was set up with the sole purpose of managing Singapore’s foreign reserves. The Government of Singapore disclaims beneficial ownership of the LLC Units held by Texas Transmission. The address of each of Cheyne Walk, GICSI and GIC is 168 Robinson Road, #37-01, Capital Tower, Singapore 068912. STIH may be deemed, as a result of its ownership of 1% of each of the Class A Shares and Class B Shares of TTHC, to have beneficial ownership of 1% (1,254,125 LLC Units) of the 125,412,500 LLC Units owned by Texas Transmission. STIH is wholly owned by STH, which is wholly owned by Sempra Energy.

(3) Mr. Martin is the Chairman and Chief Executive Officer of Sempra Energy. Mr. Martin does not have voting or investment power over, and disclaims beneficial ownership of, the LLC Units beneficially owned by Sempra Energy.

(4) Mr. Mihalik is the Executive Vice President and Chief Financial Officer of Sempra Energy. Mr. Mihalik does not have voting or investment power over, and disclaims beneficial ownership of, the LLC Units beneficially owned by Sempra Energy.

(5) Ms. Newell is a Senior Vice President – Infrastructure for GICSI and a member of the board of directors, Treasurer, and Senior Vice President of TTHC. Ms. Newell does not have voting or investment power over, and disclaims beneficial ownership of, the LLC Units held by Texas Transmission.

(6) Mr. Zucchet is a member of the board of directors and holds the office of Managing Director of OMERS Infrastructure Management Inc. and is a member of the board of directors and Senior Vice President of TTHC. Mr. Zucchet does not have voting or investment power over, and disclaims beneficial ownership of, the LLC Units held by Texas Transmission.

CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE

Our board of directors has adopted a written policy regarding related person transactions as part of our corporate governance guidelines. Under this policy, a related person transaction shall be consummated or shall continue only if:

1. the Audit Committee of our board of directors approves or ratifies such transaction in accordance with the policy and if the transaction is on terms comparable to those that could be obtained in arm’s length dealings with an unrelated third party;

2. the transaction is approved by the disinterested members of the board of directors; or

3. the transaction involves compensation approved by the O&C Committee of the board of directors.

For purposes of this policy, the term “related person” means any related person pursuant to Item 404 of Regulation S-K of the Securities Act, except (i) prior to the Sempra Acquisition, transactions with EFH Corp., its subsidiaries and certain entities owning or controlling more than 49% of Oncor’s equity interests, which were subject to restrictions set forth in our Limited Liability Company Agreement in effect at the time, and (ii) following the Sempra Acquisition, transactions with Sempra and its affiliates (other than the Oncor Ring-Fenced Entities), which transactions are subject to restrictions set forth in our current Limited Liability Company Agreement.

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A “related person transaction” is a transaction between us and a related person (including any transactions requiring disclosure under Item 404 of Regulation S-K under the Securities Act, if applicable), other than the types of transactions described below, which are deemed to be pre-approved by the Audit Committee:

1. any compensation paid to an executive officer or director if the compensation is reported (or would have been reported, in the case of executive officers that are not named executive officers) under Item 402 of Regulation S-K of the Securities Act, provided that such executive officer or director is not an immediate family member of an executive officer or director and provided that the board of directors or the O&C Committee has approved such compensation;

2. any transaction with another company at which a related person’s only relationship is as an employee (other than an executive officer), director or beneficial owner of less than 10% of that company’s ownership interests;

3. any charitable contribution, grant or endowment by us to a charitable organization, foundation or university at which a related person’s only relationship is as an employee (other than an executive officer) or director;

4. any transaction with a partnership in which a related person’s only relationship is as a limited partner, and the related person is not a general partner and does not hold another position in the partnership, and all related persons have an interest of less than 10% in the partnership;

5. transactions where the related person’s interest arises solely from the ownership of Oncor’s equity securities and all holders of that class of equity securities received the same benefit on a pro rata basis;

6. transactions involving a related party where the rates or charges involved are determined by competitive bids;

7. any transaction with a related party involving the rendering of services as a common or contract carrier, or public utility, as rates or charges fixed in conformity with law or governmental authority;

8. any transaction with a related party involving services as a bank depositary of funds, transfer agent, registrar, trustee under a trust indenture, or similar service;

9. transactions available to all employees or customers generally (unless required to be disclosed under Item 404 of Regulation S-K of the Securities Act, if applicable);

10. transactions involving less than $100,000 when aggregated with all similar transactions;

11. transactions between Oncor and its subsidiaries or between subsidiaries of Oncor;

12. transactions not required to be disclosed under Item 404 of Regulation S-K of the Securities Act; and

13. open market purchases of Oncor or its subsidiaries’ debt or equity securities and interest payments on such debt securities.

Our board of directors has determined that it is appropriate for its Audit Committee to review and approve or ratify related person transactions. In unusual circumstances, we may enter into related person transactions in advance of receiving approval, provided that such related person transactions are reviewed and ratified as soon as reasonably practicable by the Audit Committee of the board of directors. If the Audit Committee determines not to ratify such transactions, we shall make all reasonable efforts to cancel or otherwise terminate such transactions.

The related person transactions policy described above also does not apply to Sempra and its subsidiaries and affiliates (other than the Oncor Ring-Fenced Entities), which are subject to restrictions set forth in our Limited Liability Company Agreement. Our Limited Liability Company Agreement requires that we maintain an arm’s-length relationship with the Sempra and its affiliates (other than the Oncor Ring-Fenced Entities) or any other direct or indirect equity holders of Oncor or Oncor Holdings, consistent with the PUCT’s rules applicable to Oncor, and only enter into transactions with Sempra and its affiliates (other than the Oncor Ring-Fenced Entities) that are both (i) on a commercially reasonable basis, and (ii) if such transaction is material, approved by (a) a majority of the members of our board of directors, and (b) prior to a Trigger Event (as defined in our Limited Liability Company Agreement), the directors appointed by Texas Transmission, at least one of whom must be present and voting in order to approve the transaction.

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Related Party Transactions

The Sponsor Group and the Texas Holdings Group were previously related parties. As a result of the Sempra Acquisition, Sempra became a related party and the Sponsor Group and the Texas Holdings Group ceased to be related parties as of March 9, 2018.

InfraREIT Acquisition and Operation Agreement With Sharyland

In May 2019, we completed the InfraREIT Acquisition. To fund the cash consideration and certain related fees and expenses we received capital contributions of $1,330 million from Sempra and certain indirect equity holders of Texas Transmission. As a condition to the InfraREIT Acquisition, InfraREIT’s subsidiary, SDTS, and SDTS’s tenant, SU, completed the SDTS-SU Asset Exchange immediately prior to the closing of the InfraREIT Acquisition, pursuant to which SDTS exchanged certain of its south Texas assets for certain assets owned by SU. In addition, as a condition to the closing of the SDTS-SU Asset Exchange, Sempra acquired an indirect 50 percent interest in Sharyland Holdings, the parent of Sharyland. As a result, Sharyland became our affiliate for purposes of PUCT rules. In connection with the SDTS-SU Asset Exchange, we and SU entered into an operation agreement, which provides that we will provide certain operations services with respect to the SU assets in south Texas to SU at cost without a markup or profit. We provided Sharyland with approximately $300,000 worth of services pursuant to this agreement in 2019.

Our Limited Liability Company Agreement requires that any material transactions with Sempra and its subsidiaries and affiliates (other than the Oncor Ring-Fenced Entities) be approved by a majority of our board of directors and the directors appointed by Texas Transmission present and voting, provided that at least one director appointed by Texas Transmission must be present and voting. The InfraREIT Acquisition and the related operation agreement were approved by our board of directors, including the directors appointed by Texas Transmission, who were both present and voting.

For more information on the InfraREIT Acquisition, see Note 2 to Annual Financial Statements.

Tax-Sharing Arrangements

We are not a member of another entity’s consolidated tax group, but our owners’ federal income tax returns include their portion of our results. Under the terms of a tax sharing agreement among us, Oncor Holdings, Texas Transmission, STH (as successor to EFH Corp.), and Investment LLC, we are generally obligated to make payments to our owners, 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. STH will file a combined Texas Margin tax return which includes our results and our share of 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 Annual Financial Statements under “Provision in Lieu of Income Taxes.” Under the “in lieu of” tax concept, all in lieu of tax assets and tax liabilities represent amounts that will eventually be settled with our members. In the unlikely event such amounts are not paid under the tax sharing agreement, it is probable that they would be reimbursed to rate payers.

At March 31, 2020, we had a total of $32 million in net payables to members under the tax sharing agreement. It consisted of a current Texas margin tax payable to Sempra totaling $28 million and a federal income tax payable totaling $4 million ($3 million due to Sempra and $1 million due to Texas Transmission). At December 31, 2019, we had a total of $19 million in net payables to members under the agreement. It consisted of a current Texas margin tax payable to Sempra totaling $22 million, partially offset by federal income tax receivables totaling $3 million ($2 million due from Sempra and $1 million due from Texas Transmission). At December 31, 2018, we had payables to members under the agreement related to federal income taxes totaling $5 million ($4 million due to Sempra and $1 million due to Texas Transmission) and a current Texas margin tax payable to Sempra totaling $21 million. At December 31, 2017, we had receivables from members under the agreement related to federal income taxes totaling $26 million ($21 million due from EFH Corp. and $5 million due from Texas Transmission and Investment LLC) and a current Texas margin tax payable to EFH Corp. totaling $21 million.

We made a net in lieu of income tax payment of $78 million (including $45 million and $11 million in federal income tax-related payments to Sempra and Texas Transmission, respectively and $22 million in Texas margin tax-related payment to Sempra) in the year ended December 31, 2019.

We made a net in lieu of income tax payment of $71 million (including $80 million and $10 million in federal income tax-related payments to Sempra and Texas Transmission, respectively, partially offset by a $19 million receipt from EFH Corp.) in the year ended December 31, 2018.

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We received a net in lieu of income tax refund of $94 million (including $12 million in federal income tax-related refunds from members other than EFH Corp) in the year ended December 31, 2017.

Third Amended and Restated Limited Liability Company Agreement of Oncor

On March 9, 2018, in connection with the closing of the Sempra Acquisition, Oncor’s Limited Liability Company Agreement was amended and restated in its entirety as set forth in the Limited Liability Company Agreement. The Limited Liability Company Agreement of Oncor among other things, sets out the members’ respective governance rights in respect of their ownership interests in Oncor. Among other things, the Limited Liability Company Agreement provides for the management of Oncor by a board of directors consisting of 13 members, including seven Disinterested Directors, two directors designated by Texas Transmission (subject to certain conditions), two directors designated indirectly by Sempra and two directors that are current or former officers of Oncor. Texas Transmission also has the right to designate one non-voting observer to the board of directors, who is entitled to attend all meetings of the board of directors (subject to certain exceptions) and receive copies of all notices and materials provided to the board of directors.

The Limited Liability Company Agreement prohibits Oncor and its subsidiaries from taking certain material actions outside the ordinary course of business without prior approvals by the members, some or all of the Disinterested Directors and/or the directors designated by one or more of the members. The Limited Liability Company Agreement also sets forth certain separateness undertakings to ensure Oncor’s separateness from Sempra and its direct and indirect subsidiaries (other than the Oncor Ring-Fenced Entities). Additionally, the Limited Liability Company Agreement contains provisions regulating capital accounts of members, allocations of profits and losses and tax allocation and withholding.

The Limited Liability Company Agreement describes Oncor’s procedures and limitations on declaring and paying distributions to members. Pursuant to the Limited Liability Company Agreement, we cannot make any distributions to members (other than contractual tax payments) that would cause us to be out of compliance with the PUCT’s approved debt-to-equity ratio, which is currently 57.5% debt to 42.5% equity. The distribution restrictions also include the ability of our board, a majority of the Disinterested Directors, or any director designated to serve on our board of directors by Texas Transmission to limit distributions (other than contractual tax payments) to the extent each determines it is necessary to meet expected future requirements of Oncor (including continuing compliance with the PUCT debt-to-equity ratio commitment). In addition, the Limited Liability Company Agreement provides that if Oncor’s senior secured debt credit rating by any one of S&P, Moody’s or Fitch falls below BBB (Baa2) we must suspend distributions (other than contractual tax payments) until otherwise permitted to do so by the PUCT, and requires that Oncor notify the PUCT if either the credit rating of either Sempra or Oncor falls below its then current level. Distributions also cannot be made to the extent they would violate any applicable laws or regulations. Our Limited Liability Company Agreement requires that any changes to such procedures and limitations be approved by Oncor Holdings and Texas Transmission and a majority of our board of directors present and voting, which must include (i) a majority of the Disinterested Directors, (ii) both directors appointed to serve on our board of directors by Sempra (through Oncor Holdings), (iii) both directors that are current or former officers of Oncor, and (iv) the directors designated to serve on our board of directors by Texas Transmission who are present and voting, provided that at least one such director must be present and voting in order to approve such matter.

In addition, any annual or multi-year budget with an aggregate amount of capital or operating and maintenance expenditures that are greater than or less than 10% of the capital or operating and maintenance expenditures in the annual budget for the immediately prior fiscal year or multi-year period, as applicable, must be approved by (i) a majority of the Disinterested Directors and (ii) the Texas Transmission director(s) present and voting, provided that at least one Texas Transmission director must be present and voting in order to approve such action. Also, any acquisition of or investment in any third party which involves the purchase of or investment in assets located outside the State of Texas for consideration in an amount greater than $1.5 billion must be approved by (a) a majority of the Disinterested Directors and (b) the Texas Transmission director(s) present and voting, provided that at least one Texas Transmission director must be present and voting in order to approve such action.

Registration Rights Agreement

In November 2008, we entered into a registration rights agreement (Registration Rights Agreement) by and among us, Oncor Holdings, Texas Transmission and STH (formerly EFH Corp.). The Registration Rights Agreement grants customary registration rights to certain of our members. Subject to certain limitations set forth in the Registration Rights Agreement, these rights include, without limitation, the following: (i) the right of Oncor Holdings at any time, and after ten years from the date of the Registration Rights Agreement, the right of Texas Transmission, to demand that we register a specified amount of membership interests in accordance with the Securities Act; (ii) the right of both Oncor Holdings and Texas Transmission to

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demand registration of a specified amount of membership interests following an initial public offering; and (iii) the right of all members that are parties to the Registration Rights Agreement to have their membership interests registered if we propose to file a registration statement relating to an offering of membership interests (with certain exceptions).

Subject to certain exceptions, whenever we are required to effect the registration of any membership interests pursuant to the Registration Rights Agreement, we have agreed to use our best efforts to cause the applicable registration statement to become effective, and to keep each such registration statement effective until the earlier of (a) at least 180 days (or two years for a shelf registration statement) or (b) the time at which all securities registered under such registration statement have been sold.

Investor Rights Agreement

The investor rights agreement dated as of November 5, 2008, by and among Oncor, Oncor Holdings, Texas Transmission, STH (formerly EFH Corp.) and any other persons that subsequently become a party thereto (Investor Rights Agreement) governs certain rights of certain members of Oncor and STH arising out of their direct or indirect ownership of Oncor membership interests, including, without limitation, transfers of Oncor membership interests and restrictions thereon. Texas Transmission may transfer its Oncor membership interests under a registration statement or pursuant to applicable securities laws. The Investor Rights Agreement also grants Texas Transmission certain “tag-along” rights in relation to certain sales of Oncor membership interests by Oncor Holdings. Subject to certain conditions, these “tag-along” rights allow Texas Transmission to sell a pro-rata portion of its Oncor membership interests in the event of a sale of Oncor membership interests by Oncor Holdings on the same terms as Oncor Holdings would receive for its Oncor membership interests. The agreement further provides that under certain offerings of equity securities occurring before an initial public offering of Oncor, Texas Transmission and Oncor Holdings will receive preemptive rights to purchase their pro-rata share of the equity securities to be sold pursuant to such offerings. The Investor Rights Agreement also provides STH and Sempra with a right of first refusal to purchase any Oncor membership interests to be sold in a permitted sale by Texas Transmission or its permitted transferees.

Additionally, STH, Sempra, certain of Sempra’s subsidiaries and Oncor Holdings have certain “drag-along” rights in relation to offers from third-parties to purchase their directly or indirectly owned membership interests in Oncor, where the resulting sale would constitute a change of control of Oncor. These “drag-along” rights compel Texas Transmission and all other members of Oncor to sell or otherwise transfer their membership interests in Oncor on substantially the same terms as STH, Sempra or Oncor Holdings (as applicable). Pursuant to the Investor Rights Agreement, all members of Oncor that have entered into such agreement must cooperate with Oncor in connection with an initial public offering of Oncor.

Transactions with Affiliates and Portfolio Companies of Certain of our Beneficial Owners

The beneficial owners of Texas Transmission include various entities and funds who make equity investments in various companies (Portfolio Companies) in the ordinary course of their business. We have in the past entered into, and may continue to enter into, transactions with Portfolio Companies or their affiliates in the ordinary course of business on an arm’s-length basis, which may result in revenues to the beneficial owners of Texas Transmission.

Transactions with Officers and Directors

In 2008 and 2009, we established stock appreciation rights (SARs) plans under which certain of our executive officers, key employees and non-employee members of our board of directors were granted SARs payable in cash, or in some circumstances, Oncor membership interests. In November 2012, we accepted the early exercise for cash payments of all outstanding SARs (both vested and unvested) issued pursuant to both SARs plans. As part of the 2012 early exercise of SARs, we began accruing interest on dividends declared with respect to the SARs. Under both SARs plans, dividends that were paid in respect of Oncor membership interests while the SARs were outstanding were credited to the SARs holder’s account as if the SARs were units and were payable upon the earliest to occur of death, disability, separation from service, unforeseeable emergency, a change in control, or the occurrence of an event triggering SAR exercisability. The SARs plans dividends and interest became payable as a result of the Sempra Acquisition, and we distributed the amounts on April 30, 2018, of which an aggregate of $11,731,862 was distributed to individuals who participated in the applicable SARs plan and served as executive officers in 2018, and $53,370 was distributed to the then current disinterested directors who participated in the applicable SARs plan.

On March 9, 2018, Oncor entered into an Interest Transfer Agreement (OMI Agreement) with Investment LLC, Oncor Holdings and Sempra. Pursuant to the 2008 Equity Interests Plan for Key Employees of Oncor Electric Delivery Company LLC and its affiliates, certain members of Oncor’s management, including Oncor’s executive officers and independent

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directors on Oncor’s board of directors, were granted the opportunity to purchase Class B equity interests (Class B Interests) in Investment LLC, an entity whose only assets consist of equity interests in Oncor. Investment LLC held 1,396,008 of the outstanding limited liability company interests in Oncor (the OMI Interests), which represented 0.22% of the then outstanding membership interests in Oncor.

Pursuant to the OMI Agreement, concurrent with the closing of the Sempra Acquisition, Investment LLC transferred to Oncor Holdings (which became a wholly owned indirect subsidiary of Sempra upon closing of the Sempra Acquisition) all of the OMI Interests in exchange for $26 million in cash, which represents approximately $18.60 for each OMI Interest. Oncor Holdings paid the purchase price with funds received from Sempra via a capital contribution. Investment LLC retained approximately $34,000 of the purchase price for future expected tax liabilities and distributed the remainder of the proceeds, representing $18.57 per Class B equity interest held, to holders of Class B equity interests in proportion to the amount of Class B equity interests they held. Executives and members of our board of directors beneficially owned the following amounts of Class B Interests as of March 9, 2018: Robert S. Shapard: 300,000; E. Allen Nye Jr.:18,368; Mark Carpenter: 25,000; Don J. Clevenger: 50,000; Deborah L. Dennis: 50,000; James Greer: 75,000; Thomas M. Dunning: 20,000; Robert A. Estrada: 5,000; and Richard W. Wortham: 10,000.

Each participating executive officer entered into a management stockholder’s agreement and sale participation agreement with us. Each director that purchased Class B equity interests of Investment LLC in 2009 entered into a director stockholder’s agreement and a sale participation agreement with us. These agreements contained, among other things, restrictions on transferring Class B equity interests and certain drag-along and piggyback sale rights.

The certain letter agreements entered into with each of Sempra and certain of our executive officers in connection with the Sempra Acquisition provided for the payment of certain benefits, including change in control benefits, in the event of the executive’s retirement or termination from service within a specified time period following the Sempra Acquisition. These agreements provided that Sempra would bear responsibility for these payments. In 2018, Sempra reimbursed Oncor approximately $9.9 million (net of a tax deduction) for certain executive change in control expenses accrued by Oncor in connection with the Sempra Acquisition pursuant to such letter agreements.

Transactions with the Sponsor Group

The Sponsor Group was an affiliate of ours until closing of the Sempra Acquisition on March 9, 2018. Affiliates of the Sponsor Group have (1) sold, acquired or participated in the offerings of our debt or debt securities in open market transactions or through loan syndications, and (2) performed various financial advisory, dealer, commercial banking and investment banking services for us and certain of our affiliates for which they have received customary fees and expenses.

The beneficial owners of the Sponsor Group include various entities and funds who make equity investments in various companies in the ordinary course of their business. Prior to March 9, 2018, we entered into transactions with certain of these companies or their affiliates in the ordinary course of business on an arm’s-length basis, which may have resulted in revenues to the beneficial owners of the Sponsor Group.

Director Independence

Our Limited Liability Company Agreement provides that seven members of our board of directors must be Disinterested Directors. For a director to be deemed a Disinterested Director, our board of directors must affirmatively determine that (i) such director has not had within the previous ten years, or currently does not have, a material relationship with Sempra or its subsidiaries or affiliated entities or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings and (ii) that such director meets the independence standards in Section 303A of the New York Stock Exchange Manual in all material respects in relation to Sempra or its subsidiaries and affiliated entities or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings.

Our board of directors has determined that Messrs. Adams, Dunning, Estrada, Gary, Hill, Mack and Wortham are Disinterested Directors under the standards in our Limited Liability Company Agreement.

Mr. Shapard is our Chairman of the Board and presides at all meetings of our board of directors. Mr. Shapard was appointed Chairman of the Board effective upon the closing of the Sempra Acquisition in March 2018. Mr. Shapard served as our Chief Executive until the closing of the Sempra Acquisition and retired from Oncor effective April 1, 2018. Mr. Dunning is the Lead Disinterested Director of our board of directors and has served in such role since July 2010. The Lead Disinterested Director performs such duties and responsibilities as may be specified by the board.

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Our board of directors has designated an Audit Committee, Nominating and Governance Committee and O&C Committee to exercise certain powers and authorities of the board of the directors. Members of these committees are not required by our Limited Liability Company Agreement or board of directors to meet any independence standards. Mr. Zucchet, who was designated to serve on our board of directors by Texas Transmission in November 2008, has served on the O&C Committee since May 2010 and was also appointed to the Nominating and Governance Committee effective February 2011. Mr. Evenden, who was designated to serve on our board of directors by Texas Transmission in October 2014, was appointed to the Audit Committee effective October 2014 and served on our board of directors until July 2019. Ms. Newell, who was designated to serve on our board of directors by Texas Transmission in July 2019, was appointed to the Audit Committee effective July 2019. Mr. Martin, who was designated to serve on our board of directors by Sempra (through Oncor Holdings) on March 9, 2018 upon closing of the Sempra Acquisition, was appointed to the Audit Committee effective April 2018. Mr. Martin served on the Audit Committee until April 2020 when he was appointed to the O&C Committee. Ms. Ortiz, who was designated to serve on our board of directors by Sempra (through Oncor Holdings) in July 2018, was appointed to the O&C Committee effective July 2018. Ms. Ortiz served on our board of directors until August 2019. Mr. Bilicic, who was designated to serve on our board of directors by Sempra (through Oncor Holdings) in August 2019, was appointed to the O&C Committee effective September 2019. Mr. Bilicic served on our board of directors until March 2020. Mr. Mihalik, who was designated to serve on our board of directors by Sempra (through Oncor Holdings) in March 2020, was appointed to the Audit Committee and the Nominating and Governance Committee effective in April 2020. None of Messrs. Bilicic, Evenden, Martin, Mihalik, or Zucchet or Mses. Ortiz or Newell qualifies as a Disinterested Director for purposes of our Limited Liability Company Agreement.

For information on the structure of our board of directors, see “Directors, Executive Officers and Corporate Governance – Director Appointments.”

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THE EXCHANGE OFFERS

Purpose and Effect of the Exchange Offers

The outstanding 2030 notes and the outstanding 2050 notes were sold to the initial purchasers on March 20, 2020 pursuant to a purchase agreement. The respective initial purchasers subsequently sold the outstanding notes to qualified institutional buyers (as defined in Rule 144A under the Securities Act) in reliance on Rule 144A, and to persons in offshore transactions in reliance on Regulation S under the Securities Act.

In connection with the issuance of the outstanding notes, we entered into a registration rights agreement with the initial purchasers of such private offering in which we agreed, under certain circumstances, to file a registration statement relating to offers to exchange the outstanding notes for exchange notes and to use commercially reasonable efforts to cause such registration statement to be declared effective under the Securities Act no later than 270 days after the issue date of the applicable outstanding notes and to consummate the exchange offers no later than 315 days after the issue dates of the applicable outstanding notes. The exchange notes will have terms identical in all material respects to the outstanding notes, except that the exchange notes will not contain terms with respect to transfer restrictions, registration rights and additional interest for failure to observe certain obligations in the registration rights agreement.

Under the circumstances set forth below, we will use commercially reasonable efforts to cause the SEC to declare effective a shelf registration statement with respect to the resale of the outstanding notes within the time periods specified in the registration rights agreement and keep the statement effective for two years after the effective date of the shelf registration statement, subject to extension under the terms of the registration rights agreement, or such shorter period terminating when all of the notes cease to be Registrable Securities (as defined in the registration rights agreement). These circumstances include:

• if because of any changes in law, SEC rules or regulations or applicable interpretations thereof by the SEC, the exchange notes received by holders, other than certain specified holders, are not or would not be transferable by such holders without restriction under the Securities Act;

• if the exchange offers are not consummated within 315 days after the dates of issuance of the applicable outstanding notes;

• if any holder of notes notifies us prior to the 20^th business day following the completion of the exchange offers that (a) it is prohibited by law or SEC policy from participating in the exchange offers, (b) it may not resell the exchange notes to the public without delivering a prospectus (other than the prospectus in the registration statement relating to the exchange offers), or (c) it is a broker-dealer and owns notes acquired directly from us or an affiliate; or

• if we elect to file a shelf registration statement covering resales of the notes in lieu of (or in case of the immediately preceding circumstance, in addition to) conducting the exchange offers.

Except for certain circumstances specified in the registration rights agreement, if (1) a registration statement relating to the exchange offers or a shelf registration statement has not become or been declared effective by the deadlines discussed above, (2) the exchange offers have not been consummated by the deadlines discussed above, or (3) a registration statement relating to the notes has been declared effective and such registration statement ceases to be effective at any time during the applicable registration period (subject to certain exceptions) (each of (1), (2) and (3) above, a Registration Default; each period during which a Registration Default has occurred and is continuing, a Registration Default Period), then, as liquidated damages for the Registration Default, additional interest shall accrue on the principal amount of the affected notes at a rate of 0.50% per annum with respect to the outstanding notes over the interest rate otherwise provided for under the outstanding notes for the remaining period during which a Registration Default continues, but not later than the second anniversary of the issue date of the outstanding notes. If we cure all Registration Defaults, the interest rate on the notes will revert to the original level.

If you wish to exchange your outstanding notes for exchange notes in either of the exchange offers, you will be required to make the following written representations:

• you are not our affiliate within the meaning of Rule 405 of the Securities Act;

• you have no arrangement or understanding with any person to participate in a distribution (within the meaning of the Securities Act) of the exchange notes in violation of the provisions of the Securities Act;

• you are not engaged in, and do not intend to engage in, a distribution of the exchange notes; and

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• you are acquiring the exchange notes in the ordinary course of your business.

Each broker-dealer that receives exchange notes for its own account in exchange for outstanding notes, where the broker-dealer acquired the outstanding notes as a result of market-making activities or other trading activities, must acknowledge that it will deliver a prospectus in connection with any resale of such exchange notes and that it did not purchase its outstanding notes from us or any of our affiliates. See “Plan of Distribution.”

Resale of Exchange Notes

Based on interpretations by the SEC set forth in no-action letters issued to third parties, we believe that you may resell or otherwise transfer exchange notes issued in the exchange offers without complying with the registration and prospectus delivery provisions of the Securities Act if:

• you are not our affiliate within the meaning of Rule 405 under the Securities Act;

• you do not have an arrangement or understanding with any person to participate in a distribution of the exchange notes;

• you are not engaged in, and do not intend to engage in, a distribution of the exchange notes; and

• you are acquiring the exchange notes in the ordinary course of your business.

If you are our affiliate, or are engaging in, or intend to engage in, or have any arrangement or understanding with any person to participate in, a distribution of the exchange notes, or are not acquiring the exchange notes in the ordinary course of your business:

• you cannot rely on the position of the SEC set forth in Morgan Stanley & Co. Incorporated (available June 5, 1991) and Exxon Capital Holdings Corporation (available May 13, 1988), as interpreted in the SEC’s letter to Shearman & Sterling, dated July 2, 1993, or similar no-action letters; and

• in the absence of an exception from the position stated immediately above, you must comply with the registration and prospectus delivery requirements of the Securities Act in connection with any resale of the exchange notes.

This prospectus may be used for an offer to resell, resale or other transfer of exchange notes only as specifically set forth in this prospectus. With regard to broker-dealers, only broker-dealers that acquired the outstanding notes as a result of market-making activities or other trading activities may participate in the exchange offers. Each broker-dealer that receives exchange notes for its own account in exchange for outstanding notes, where such outstanding notes were acquired by such broker-dealer as a result of market-making activities or other trading activities, must acknowledge that it will deliver a prospectus in connection with any resale of the exchange notes. Read “Plan of Distribution” for more details regarding the transfer of exchange notes.

Our belief that the exchange notes may be offered for resale without compliance with the registration or prospectus delivery provisions of the Securities Act is based on interpretations of the SEC for other exchange offers that the SEC expressed in some of its no-action letters to other issuers in exchange offers like ours. We cannot guarantee that the SEC would make a similar decision about our exchange offers. If our belief is wrong, or if you cannot truthfully make the representations mentioned above, and you transfer any exchange note issued to you in the exchange offers without meeting the registration and prospectus delivery requirements of the Securities Act, or without an exemption from such requirements, you could incur liability under the Securities Act. We are not indemnifying you for any such liability.

Terms of the Exchange Offers

On the terms and subject to the conditions set forth in this prospectus and in the accompanying letter of transmittal, we will accept for exchange in the exchange offers any outstanding notes that are validly tendered and not validly withdrawn prior to the expiration date. Outstanding notes may only be tendered in minimum denominations of $2,000 and integral multiples of $1,000 in excess of $2,000. We will issue exchange notes in principal amount identical to outstanding notes surrendered in the exchange offers.

The form and terms of the exchange notes will be identical in all material respects to the form and terms of the outstanding notes except the exchange notes will be registered under the Securities Act, will not bear legends restricting their transfer and will not provide for any additional interest upon our failure to fulfill our obligations under the registration rights agreement to complete the exchange offers, or file, and cause to be effective, a shelf registration statement, if required thereby, within the specified time period. The exchange notes will evidence the same debt as the outstanding notes. The exchange notes will be issued under and entitled to the benefits of the Indenture. For a description of the Indenture, see “Description of the Notes.”

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The exchange offers are not conditioned upon any minimum aggregate principal amount of outstanding notes being tendered for exchange.

This prospectus and the letter of transmittal are being sent to all registered holders of outstanding notes. There will be no fixed record date for determining registered holders of outstanding notes entitled to participate in the exchange offers. We intend to conduct the exchange offers in accordance with the provisions of the registration rights agreement, the applicable requirements of the Securities Act and the Exchange Act, and the rules and regulations of the SEC. Outstanding notes that are not tendered for exchange in the exchange offers will remain outstanding and continue to accrue interest and will be entitled to the rights and benefits such holders have under the Indenture relating to such holders’ series of outstanding notes, except we will not have any further obligation to you to provide for the registration of the outstanding notes under the registration rights agreement.

We will be deemed to have accepted for exchange properly tendered outstanding notes when we have given written notice of the acceptance to the exchange agent. The exchange agent will act as agent for the tendering holders for the purposes of receiving the exchange notes from us and delivering exchange notes to holders. Subject to the terms of the registration rights agreement, we expressly reserve the right to amend or terminate the exchange offers and to refuse to accept the occurrence of any of the conditions specified below under “—Conditions to the Exchange Offers.”

If you tender your outstanding notes in the exchange offers, you will not be required to pay brokerage commissions or fees or, subject to the instructions in the letter of transmittal, transfer taxes with respect to the exchange of outstanding notes. We will pay all charges and expenses, other than certain applicable taxes described below in connection with the exchange offers. It is important that you read “—Fees and Expenses” below for more details regarding fees and expenses incurred in the exchange offers.

If you are a broker-dealer and receive exchange notes for your own account in exchange for outstanding notes that you acquired as a result of market-making activities or other trading activities, you must acknowledge that you will deliver this prospectus in connection with any resale of the exchange notes and that you did not purchase your outstanding notes from us or any of our affiliates. Read “Plan of Distribution” for more details regarding the transfer of exchange notes.

We make no recommendation to you as to whether you should tender or refrain from tendering all or any portion of your outstanding notes into the exchange offers. In addition, no one has been authorized to make this recommendation. You must make your own decision whether to tender into the exchange offers and, if so, the aggregate amount of outstanding notes to tender after reading this prospectus and the letter of transmittal and consulting with your advisors, if any, based on your financial position and requirements.

Expiration Date, Extensions and Amendments

The exchange offers expire at 5:00 p.m., New York City time, on August 11, 2020, which we refer to as the “expiration date”. However, if we, in our sole discretion, extend the period of time for which the exchange offers are open, the term “expiration date” will mean the latest date to which we shall have extended the expiration of the exchange offers.

To extend the period of time during which the exchange offers are open, we will notify the exchange agent of any extension by written notice, followed by notification by press release or other public announcement to the registered holders of the outstanding notes no later than 9:00 a.m., New York City time, on the next business day after the previously scheduled expiration date.

We reserve the right, in our sole discretion:

• to delay accepting for exchange any outstanding notes (only in the case that we amend or extend the exchange offers);

• to extend the expiration date and retain all outstanding notes tendered in the exchange offers, subject to your right to withdraw your tendered outstanding notes as described under “—Withdrawal Rights”;

• to terminate the exchange offers if we determine that any of the conditions set forth below under “—Conditions to the Exchange Offers” have not been satisfied; and

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• subject to the terms of the registration rights agreement, to amend the terms of the exchange offers in any manner or waive any condition to the exchange offers. In the event of a material change in the exchange offers, including the waiver of a material condition, we will extend the offer period, if necessary, so that at least five business days remain in such offer period following notice of the material change.

Any delay in acceptance, extension, termination or amendment will be followed as promptly as practicable by written notice (which may take the form of a press release or other public announcement) to the registered holders of the outstanding notes. If we amend either of the exchange offers in a manner that we determine to constitute a material change, or if we waive a material condition to the exchange offers, we will promptly disclose the amendment in a manner reasonably calculated to inform the holders of applicable outstanding notes of that amendment.

In the event we terminate the exchange offers, all outstanding notes previously tendered and not accepted for payment will be returned promptly to the tendering holders.

Conditions to the Exchange Offers

Despite any other term of the exchange offers, we will not be required to accept for exchange, or to issue exchange notes in exchange for, any outstanding notes, and we may terminate or amend either of the exchange offers as provided in this prospectus prior to the expiration date if in our reasonable judgment:

• the exchange offers or the making of any exchange by a holder violates any applicable law or interpretation of the SEC; or

• any action or proceeding has been instituted or threatened in writing in any court or by or before any governmental agency with respect to the exchange offers that, in our judgment, would reasonably be expected to impair our ability to proceed with the exchange offers.

In addition, we will not be obligated to accept for exchange the outstanding notes of any holder that has not made to us:

• the representations described under “—Purpose and Effect of the Exchange Offers;” or

• any other representations as may be reasonably necessary under applicable SEC rules, regulations or interpretations to make available to us an appropriate form for registration of the exchange notes under the Securities Act.

We expressly reserve the right at any time or at various times to extend the period of time during which the exchange offers are open. Consequently, we may delay acceptance of any outstanding notes by giving written notice of such extension to the holders. We will return any outstanding notes that we do not accept for exchange for any reason without expense to the tendering holder promptly after the expiration or termination of the exchange offers. We also expressly reserve the right to amend or terminate either of the exchange offers and to reject for exchange any outstanding notes not previously accepted for exchange if we determine that any of the conditions of the exchange offers specified above have not been satisfied. We will give written notice of any extension, amendment, non-acceptance or termination to the holders of the outstanding notes as promptly as practicable. In the case of any extension, such notice will be issued no later than 9:00 a.m., New York City time, on the next business day after the previously scheduled expiration date. Written notice to the holders may take the form of a press release or other public announcement.

We reserve the right to waive any defects, irregularities or conditions to the exchange as to particular outstanding notes. These conditions are for our sole benefit, and we may assert them regardless of the circumstances that may give rise to them or waive them in whole or in part at any time or at various times prior to the expiration of the exchange offers in our sole discretion. If we fail at any time to exercise any of the foregoing rights, this failure will not constitute a waiver of such right. Each such right will be deemed an ongoing right that we may assert at any time or at various times prior to the expiration of the exchange offers.

In addition, we will not accept for exchange any outstanding notes tendered, and will not issue exchange notes in exchange for any such outstanding notes, if at such time any stop order is threatened or in effect with respect to the registration statement of which this prospectus constitutes a part or the qualification of the Indenture under the Trust Indenture Act of 1939, as amended (TIA).

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Procedures for Tendering Outstanding Notes

To tender your outstanding notes in the exchange offers, you must comply with either of the following:

• complete, sign and date the letter of transmittal, or a facsimile of the letter of transmittal, have the signature(s) on the letter of transmittal guaranteed if required by the letter of transmittal and mail or deliver such letter of transmittal or facsimile thereof to the exchange agent at the address set forth below under “—Exchange Agent” prior to the expiration date; or

• comply with DTC’s Automated Tender Offer Program procedures described below.

In addition:

• the exchange agent must receive certificates for outstanding notes along with the letter of transmittal prior to the expiration of the exchange offers;

• the exchange agent must receive a timely confirmation of book-entry transfer of outstanding notes into the exchange agent’s account at DTC according to the procedures for book-entry transfer described below or a properly transmitted agent’s message prior to the expiration of the exchange offers; or

• you must comply with the guaranteed delivery procedures described below.

The term “agent’s message” means a message transmitted by DTC, received by the exchange agent and forming part of the book-entry confirmation, which states that:

• DTC has received an express acknowledgment from a participant in its Automated Tender Offer Program that is tendering outstanding notes that are the subject of the book-entry confirmation;

• the participant has received and agrees to be bound by the terms of the letter of transmittal or, in the case of an agent’s message relating to guaranteed delivery, that such participant has received and agrees to be bound by the notice of guaranteed delivery; and

• we may enforce that agreement against such participant.

DTC is referred to herein as a “book-entry transfer facility.”

Your tender, if not withdrawn prior to the expiration of the exchange offers, constitutes an agreement between us and you upon the terms and subject to the conditions described in this prospectus and in the letter of transmittal.

The method of delivery of outstanding notes, letters of transmittal and all other required documents to the exchange agent is at your election and risk. Delivery of such documents will be deemed made only when actually received by the exchange agent. We recommend that instead of delivery by mail, you use an overnight or hand delivery service, properly insured. If you determine to make delivery by mail, we suggest that you use properly insured, registered mail with return receipt requested. In all cases, you should allow sufficient time to assure timely delivery to the exchange agent before the expiration of the exchange offers. Letters of transmittal and certificates representing outstanding notes should be sent only to the exchange agent, and not to us or to any book-entry transfer facility. No alternative, conditional or contingent tenders of outstanding notes will be accepted. You may request that your broker, dealer, commercial bank, trust company or nominee effect the above transactions for you.

If you are a beneficial owner whose outstanding notes are registered in the name of a broker, dealer, commercial bank, trust company or other nominee and you wish to tender your outstanding notes, you should promptly contact the registered holder and instruct the registered holder to tender on your behalf. If you wish to tender the outstanding notes yourself, you must, prior to completing and executing the letter of transmittal and delivering your outstanding notes, either:

• make appropriate arrangements to register ownership of the outstanding notes in your name; or

• obtain a properly completed bond power from the registered holder of outstanding notes.

The transfer of registered ownership may take considerable time and may not be able to be completed prior to the expiration of the exchange offers. Signatures on the letter of transmittal or a notice of withdrawal (as described below in “–Withdrawal Rights”), as the case may be, must be guaranteed by a member firm of a registered national securities exchange or of the Financial Industry Regulatory Authority (FINRA), a commercial bank or trust company having an office or correspondent in the U.S. or another “eligible guarantor institution” within the meaning of Rule 17A(d)-15 under the Exchange Act unless the outstanding notes surrendered for exchange are tendered:

• by a registered holder of the outstanding notes who has not completed the box entitled “Special Registration Instructions” or “Special Delivery Instructions” on the letter of transmittal; or

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• for the account of an eligible guarantor institution.

If the letter of transmittal is signed by a person other than the registered holder of any outstanding notes listed on the outstanding notes, such outstanding notes must be endorsed or accompanied by a properly completed bond power. The bond power must be signed by the registered holder as the registered holder’s name appears on the outstanding notes, and an eligible guarantor institution must guarantee the signature on the bond power.

If the letter of transmittal, any certificates representing outstanding notes or bond powers are signed by trustees, executors, administrators, guardians, attorneys-in-fact, officers of corporations or others acting in a fiduciary or representative capacity, those persons should also indicate when signing and, unless waived by us, they should also submit evidence satisfactory to us of their authority to so act.

The exchange agent and DTC have confirmed that any financial institution that is a participant in DTC’s system may use DTC’s Automated Tender Offer Program to tender outstanding notes. Participants in the program may, instead of physically completing and signing the letter of transmittal and delivering it to the exchange agent, electronically transmit their acceptance of outstanding notes for exchange by causing DTC to transfer the outstanding notes to the exchange agent in accordance with DTC’s Automated Tender Offer Program procedures for transfer. DTC will then send an agent’s message to the exchange agent.

Book-Entry Delivery Procedures

Promptly after the date of this prospectus, the exchange agent will establish an account with respect to the outstanding notes at DTC, as the book-entry transfer facility, for purposes of the exchange offers. Any financial institution that is a participant in the book-entry transfer facility’s system may make book-entry delivery of the outstanding notes by causing the book-entry transfer facility to transfer those outstanding notes into the exchange agent’s account at the facility in accordance with the facility’s procedures for such transfer. To be timely, book-entry delivery of outstanding notes requires receipt of a confirmation of a book-entry transfer, or a “book-entry confirmation,” prior to the expiration date.

In addition, in order to receive exchange notes for tendered outstanding notes, an agent’s message in connection with a book-entry transfer into the exchange agent’s account at the book-entry transfer facility or the letter of transmittal or a manually signed facsimile thereof, together with any required signature guarantees and any other required documents must be delivered or transmitted to and received by the exchange agent at its address set forth on the cover page of the letter of transmittal prior to the expiration of the exchange offers. Holders of outstanding notes who are unable to deliver confirmation of the book-entry tender of their outstanding notes into the exchange agent’s account at the book-entry transfer facility or all other documents required by the letter of transmittal to the exchange agent prior to the expiration of the exchange offers must tender their outstanding notes according to the guaranteed delivery procedures described below. Tender will not be deemed made until such documents are received by the exchange agent. Delivery of documents to the book-entry transfer facility does not constitute delivery to the exchange agent.

Guaranteed Delivery Procedures

If you wish to tender your outstanding notes, but your outstanding notes are not immediately available or you cannot deliver your outstanding notes, the letter of transmittal or any other required documents to the exchange agent or comply with the procedures under DTC’s Automatic Tender Offer Program in the case of outstanding notes, prior to the expiration date, you may still tender if:

• the tender is made through an eligible guarantor institution;

• prior to the expiration date of the exchange offers, the exchange agent receives from such eligible guarantor institution either a properly completed and duly executed notice of guaranteed delivery, by facsimile transmission, mail, or hand delivery or a properly transmitted agent’s message and notice of guaranteed delivery, that (1) sets forth your name and address, the certificate number(s) of such outstanding notes and the principal amount of outstanding notes tendered; (2) states that the tender is being made thereby; and (3) guarantees that, within three New York Stock Exchange trading days after the expiration date, the letter of transmittal, or facsimile thereof, together with the outstanding notes or a book-entry confirmation, and any other documents required by the letter of transmittal, will be deposited by the eligible guarantor institution with the exchange agent; and

• the exchange agent receives the properly completed and executed letter of transmittal or facsimile thereof, with any required signature guarantees or a properly transmitted agent’s message, as well as certificate(s) representing all

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tendered outstanding notes in proper form for transfer or a book-entry confirmation of transfer of the outstanding notes into the exchange agent’s account at DTC and all other documents required by the letter of transmittal within three New York Stock Exchange trading days after the expiration date.

Upon request, the exchange agent will send to you a notice of guaranteed delivery if you wish to tender your outstanding notes according to the guaranteed delivery procedures.

Acceptance of Outstanding Notes for Exchange

In all cases, we will promptly issue exchange notes for outstanding notes that we have accepted for exchange under the exchange offers only after the exchange agent timely receives:

• outstanding notes or a timely book-entry confirmation of such outstanding notes into the exchange agent’s account at the book-entry transfer facility; and

• a properly completed and duly executed letter of transmittal and all other required documents or a properly transmitted agent’s message.

In addition, each broker-dealer that is to receive exchange notes for its own account in exchange for outstanding notes must represent that such outstanding notes were acquired by that broker-dealer as a result of market-making activities or other trading activities and must acknowledge that it will deliver a prospectus that meets the requirements of the Securities Act in connection with any resale of the exchange notes. The letter of transmittal states that by so acknowledging and by delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act. See “Plan of Distribution.”

We will interpret the terms and conditions of the exchange offers, including the letter of transmittal and the instructions to the letter of transmittal, and will resolve all questions as to the validity, form, eligibility, including time of receipt, and acceptance of outstanding notes tendered for exchange. Our determinations in this regard will be final and binding on all parties. We reserve the absolute right to reject any and all tenders of any particular outstanding notes not properly tendered or to not accept any particular outstanding notes if the acceptance might, in our or our counsel’s judgment, be unlawful. We also reserve the absolute right to waive any defects or irregularities as to any particular outstanding notes prior to the expiration of the exchange offers.

Unless waived, any defects or irregularities in connection with tenders of outstanding notes for exchange must be cured within such reasonable period of time as we determine. None of Oncor, the exchange agent or any other person will be under any duty to give notification of any defect or irregularity with respect to any tender of outstanding notes for exchange, nor will any of them incur any liability for any failure to give notification. Any certificates representing outstanding notes received by the exchange agent that are not properly tendered and as to which the irregularities have not been cured or waived will be returned by the exchange agent to the tendering holder, unless otherwise provided in the letter of transmittal, promptly after the expiration of the exchange offers or termination of the exchange offers.

Withdrawal Rights

Except as otherwise provided in this prospectus, you may withdraw your tender of outstanding notes at any time prior to 5:00 p.m., New York City time, on the expiration date.

For a withdrawal to be effective:

• the exchange agent must receive a written notice, which may be by facsimile or letter, of withdrawal at its address set forth below under “—Exchange Agent”; or

• you must comply with the appropriate procedures of DTC’s Automated Tender Offer Program system.

Any notice of withdrawal must:

• specify the name of the person who tendered the outstanding notes to be withdrawn;

• identify the outstanding notes to be withdrawn, including the certificate numbers and principal amount of the outstanding notes; and

• where certificates for outstanding notes have been transmitted, specify the name in which such outstanding notes were registered, if different from that of the withdrawing holder.

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If certificates for outstanding notes have been delivered or otherwise identified to the exchange agent, then, prior to the release of such certificates, you must also submit:

• the serial numbers of the particular certificates to be withdrawn; and

• a signed notice of withdrawal with signatures guaranteed by an eligible institution unless you are an eligible guarantor institution.

If outstanding notes have been tendered pursuant to the procedures for book-entry transfer described above, any notice of withdrawal must specify the name and number of the account at the book-entry transfer facility to be credited with the withdrawn outstanding notes and otherwise comply with the procedures of the facility. We will determine all questions as to the validity, form and eligibility, including time of receipt of notices of withdrawal, and our determination will be final and binding on all parties. Any outstanding notes so withdrawn will be deemed not to have been validly tendered for exchange for purposes of the exchange offers. Any outstanding notes that have been tendered for exchange but that are not exchanged for any reason will be returned to their holder, without cost to the holder, or, in the case of book-entry transfer, the outstanding notes will be credited to an account at the book-entry transfer facility, promptly after withdrawal, rejection of tender or termination of the exchange offers. Properly withdrawn outstanding notes may be retendered by following the procedures described under “— Procedures for Tendering Outstanding Notes” above at any time prior to the expiration of the exchange offers.

Exchange Agent

The Bank of New York Mellon Trust Company, N.A. has been appointed as the exchange agent for the exchange offers. The Bank of New York Mellon Trust Company, N.A also acts as trustee under the Indenture. You should direct all executed letters of transmittal and all questions and requests for assistance, requests for additional copies of this prospectus or of the letter of transmittal and requests for notices of guaranteed delivery to the exchange agent addressed as follows:

By Mail, Overnight Courier or Hand Delivery	By Facsimile Transmission (eligible institutions only):
The Bank of New York Mellon Trust Company, N.A. 111 Sanders Creek East Syracuse, New York 13057 Attn: Corporate Trust Reorg Operations – Eric Herr	(732) 667-9408 To Confirm by Telephone: (315) 414-3362

If you deliver the letter of transmittal to an address other than the one set forth above or transmit instructions via facsimile to a number other than the one set forth above, that delivery or those instructions will not be effective.

Fees and Expenses

The registration rights agreement provides that we will bear all expenses in connection with the performance of our obligations relating to the registration of the exchange notes and the conduct of the exchange offers. These expenses include registration and filing fees, accounting and legal fees and printing costs, among others. We will pay the exchange agent reasonable and customary fees for its services and reasonable out-of-pocket expenses. We will also reimburse brokerage houses and other custodians, nominees and fiduciaries for customary mailing and handling expenses incurred by them in forwarding this prospectus and related documents to their clients that are holders of outstanding notes and for handling or tendering for such clients.

We have not retained any dealer-manager in connection with the exchange offers and will not pay any fee or commission to any broker, dealer, nominee or other person, other than the exchange agent, for soliciting tenders of outstanding notes pursuant to the exchange offers.

Accounting Treatment

We will record the exchange notes in our accounting records at the same carrying value as the outstanding notes, which is the aggregate principal amount as reflected in our accounting records on the date of exchanges. Accordingly, we will not recognize any gain or loss for accounting purposes upon the consummation of the exchange offers. We will record the expenses of the exchange offers as incurred.

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Transfer Taxes

We will pay all transfer taxes, if any, applicable to the exchanges of outstanding notes under the exchange offers. The tendering holder, however, will be required to pay any transfer taxes, whether imposed on the registered holder or any other person, if:

• certificates representing outstanding notes for principal amounts not tendered or accepted for exchange are to be delivered to, or are to be issued in the name of, any person other than the registered holder of outstanding notes tendered;

• tendered outstanding notes are registered in the name of any person other than the person signing the letter of transmittal; or

• a transfer tax is imposed for any reason other than the exchange of outstanding notes under the exchange offers.

If satisfactory evidence of payment of such taxes is not submitted with the letter of transmittal, the amount of such transfer taxes will be billed to that tendering holder.

Holders who tender their outstanding notes for exchange will not be required to pay any transfer taxes. However, holders who instruct us to register exchange notes in the name of, or request that outstanding notes not tendered or not accepted in the exchange offers be returned to, a person other than the registered tendering holder will be required to pay any applicable transfer tax.

Consequences of Failure to Exchange

If you do not exchange your outstanding notes for exchange notes under the exchange offers, your outstanding notes will remain subject to the restrictions on transfer of such outstanding notes:

• as set forth in the legend printed on the outstanding notes as a consequence of the issuance of the outstanding notes pursuant to the exemptions from, or in transactions not subject to, the registration requirements of the Securities Act and applicable state securities laws; and

• as otherwise set forth in the offering memorandum dated on or around March 20, 2020 distributed in connection with the private offering of the outstanding 2030 notes and the outstanding 2050 notes.

In general, you may not offer or sell your outstanding notes unless they are registered under the Securities Act or if the offer or sale is exempt from registration under the Securities Act and applicable state securities laws. Except as required by the registration rights agreement, we do not intend to register resales of the outstanding notes under the Securities Act.

Other

Participating in the exchange offers is voluntary, and you should carefully consider whether to accept. You are urged to consult your financial and tax advisors in making your own decision on what action to take.

We may in the future seek to acquire untendered outstanding notes in open market or privately negotiated transactions, through subsequent exchange offers or otherwise. We have no present plans to acquire any outstanding notes that are not tendered in the exchange offers or to file a registration statement to permit resales of any untendered outstanding notes.

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DESCRIPTION OF THE NOTES

General

On March 20, 2020, we issued $400,000,000 aggregate principal amount of outstanding 2030 notes and $400,000,000 aggregate principal amount of outstanding 2050 notes in a private offering.

The Indenture and an officer’s certificate relating to the notes (the Officer’s Certificate) establish the terms of the notes. The notes are a series of debt securities that we may issue under the Indenture. The notes and all other debt securities issued under the Indenture are collectively referred to herein as Debt Securities. The Indenture permits us to issue an unlimited amount of Debt Securities from time to time, subject to certain limitations under the Indenture and the Deed of Trust. See “— Securing Additional Obligations” and “— Limitation on Secured Debt” below. All Debt Securities of any one series need not be issued at the same time, and a series may be reopened for issuances of additional Debt Securities of such series. This means that we may from time to time, without the consent of the existing holders of the notes of any series, create and issue further Debt Securities having the same terms and conditions as the notes in all respects, except for issue date, issue price and, if applicable, the initial interest payment on such Debt Securities. Additional Debt Securities issued in this manner will be consolidated with, and will form a single series with, the applicable series of notes.

The Indenture, the Officer’s Certificate and the Deed of Trust contain the full legal text of the matters described in this section. Because this section is a summary, it does not describe every aspect of the notes, the Indenture or the Deed of Trust. This summary is subject to and qualified in its entirety by reference to all the provisions of the Indenture, the Officer’s Certificate and the Deed of Trust, including definitions of certain terms used therein. We also include references in parentheses to certain sections of the Indenture and Deed of Trust. Whenever we refer to particular sections or defined terms of the Indenture or the Deed of Trust in this prospectus, those sections or defined terms are incorporated by reference herein.

The notes and other Debt Securities issued under the Indenture will rank equally with all of our other senior indebtedness that is secured by the Collateral. The exchange notes will be senior in right of payment to all subordinated indebtedness. At March 31, 2020 we had $9.019 billion principal amount of senior secured debt outstanding, which is secured by the Collateral.

The exchange notes will be issuable in the form of fully registered notes in denominations of $2,000 and integral multiples of $1,000 in excess thereof. Exchange notes will be represented by one or more global certificates, will be issued only in fully registered form and, when issued, will be registered in the name of Cede & Co., as registered owner and as nominee for DTC. Exchange notes sold pursuant to Regulation S will be evidenced by one or more separate global certificates and will be registered in the name of Cede & Co., as registered owner and as nominee for DTC for the accounts of Euroclear and Clearstream Banking. DTC will act as securities depository for the exchange notes, with certain exceptions. Purchases of beneficial interests in these global certificates will be made in book-entry form. See “—Book-Entry” below.

The notes may be transferred without charge, other than for applicable taxes or other governmental charges, at The Bank of New York Mellon, New York, New York.

Maturity and Interest

The 2030 exchange notes will mature on May 15, 2030 and the 2050 exchange notes will mature on May 15, 2050. Interest on the exchange notes will:

• be payable in U.S. dollars on the 2030 exchange notes and the 2050 exchange notes at the rate of 2.75% and 3.70%, respectively;

• be computed for each interest period on the basis of a 360-day year consisting of twelve 30-day months and, with respect to any period less than a full month, on the basis of the actual number of days elapsed during the period;

• be payable semi-annually in arrears on May 15 and November 15 of each year, and at maturity, beginning on November 15, 2020;

• accrue from, and including, the date of original issuance (March 20, 2020); and

• be paid to the persons in whose names the exchange notes are registered at the close of business on the 15th calendar day before each interest payment date for the exchange notes. We will not be required to make transfers or exchanges of the exchange notes for a period of 15 calendar days before an interest payment date.

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If any interest payment date, maturity date or redemption date falls on a day that is not a business day, such interest payment date will be postponed to the next succeeding business day, and no interest on such payment will accrue for the period from and after the interest payment date, maturity date or redemption date to such next succeeding business day. The term “business day” means, with respect to any note, any day, other than a Saturday or Sunday, which is not a day on which banking institutions or trust companies in The City of New York are generally authorized or required by law, regulation or executive order to remain closed.

Optional Redemption

We may redeem the 2030 exchange notes, at our option, in whole at any time or in part from time to time. If we redeem all or any part of the 2030 exchange notes prior to February 15, 2030, we will pay a “make whole” redemption price equal to the greater of:

• 100% of the principal amount of the 2030 exchange notes being redeemed, or

• (i) the sum of the present values of the remaining scheduled payments of principal and interest (including the portion of any such interest accrued to the redemption date) on the 2030 exchange notes being redeemed that would be due if the 2030 exchange notes matured on February 15, 2030, discounted to the redemption date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate plus 0.30% less (ii) the interest accrued to the redemption date on the 2030 exchange notes being redeemed,

plus, in each case, accrued interest to, but not including, the redemption date of the 2030 exchange notes being redeemed.

On or after February 15, 2030, in the case of the 2030 exchange notes, we may redeem the 2030 exchange notes, at our option, in whole at any time or in part from time to time at a redemption price equal to 100% of the principal amount of such 2030 exchange notes, plus accrued and unpaid interest to, but not including, the redemption date of the 2030 exchange notes.

We may redeem the 2050 exchange notes, at our option, in whole at any time or in part from time to time. If we redeem all or any part of the 2050 exchange notes prior to November 15, 2049, we will pay a “make whole” redemption price equal to the greater of:

• 100% of the principal amount of the 2050 exchange notes being redeemed, or

• (i) the sum of the present values of the remaining scheduled payments of principal and interest (including the portion of any such interest accrued to the redemption date) on the 2050 exchange notes being redeemed that would be due if the 2050 exchange notes matured on November 15, 2049, discounted to the redemption date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Treasury Rate plus 0.30% less (ii) the interest accrued to the redemption date on the 2050 exchange notes being redeemed,

plus, in each case, accrued interest to, but not including, the redemption date of the 2050 exchange notes being redeemed.

On or after November 15, 2049, in the case of the 2050 exchange notes, we may redeem the 2050 exchange notes, at our option, in whole at any time or in part from time to time at a redemption price equal to 100% of the principal amount of such 2050 exchange notes, plus accrued and unpaid interest to, but not including, the redemption date of the 2050 exchange notes.

We will give notice of our intent to redeem the exchange notes at least 15 days prior to the redemption date.

For purposes of the foregoing, the following terms shall have the definitions as set forth below:

“Treasury Rate” means, with respect to any redemption date, the rate per annum equal to: (1) the weekly average yield to maturity representing the average of the daily yields appearing at 5:00 p.m., New York City time, on the relevant calculation date in the most recently published Data Download Program designated “H.15” or any successor publication which is published weekly by the Board of Governors of the Federal Reserve System and which establishes yields on actively traded United States Treasury securities adjusted to constant maturity under the caption “Treasury Constant Maturities,” for the maturity corresponding to the period from the redemption date of the exchange notes to be redeemed to February 15, 2030 (rounded to the nearest month), in the case of the 2030 exchange notes, or November 15, 2049 (rounded to the nearest month), in the case of the 2050 exchange notes (in each case, the “Remaining Term”); provided that, if no maturity is within three months before or after the Remaining Term of the exchange notes to be redeemed or more than one maturity is within three months before or after the Remaining Term of the exchange notes to be redeemed and no maturity exactly corresponds to the Remaining

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Term, the weekly average yield for (A) the published maturity closest to but shorter than the Remaining Term and (B) the published maturity closest to but longer than the Remaining Term, both to be determined as described above, and the Treasury Rate will be interpolated or extrapolated from those yields on a straight line basis; or (2) if such release (or any successor release) is not published during the week preceding the calculation date or does not contain such yields, the rate per annum equal to the semi-annual equivalent yield to maturity of the applicable Comparable Treasury Issue, calculated using a price for the applicable Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the related Comparable Treasury Price for such redemption date. The Treasury Rate will be calculated by Oncor on the third business day preceding the redemption date.

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

“Comparable Treasury Price” means, with respect to any redemption date, the Reference Treasury Dealer Quotation.

“Reference Treasury Dealer” means any primary U.S. Government securities dealer in New York City appointed by Oncor.

“Reference Treasury Dealer Quotation” means, with respect to any redemption date, the average, as calculated by the Reference Treasury Dealer, of the bid and asked prices for the applicable Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to Oncor by such Reference Treasury Dealer at 3:30 p.m., New York City time, on the third business day preceding such redemption date.

If, at the time notice of optional redemption is given, the redemption moneys are not held by the Trustee, the redemption may be made subject to their receipt on or before the date fixed for redemption and such notice will be of no effect unless such moneys are so received.

Upon payment of the redemption price, on and after the redemption date interest will cease to accrue on the applicable exchange notes or portions thereof called for redemption.

Payment and Paying Agents

Interest on each note payable on any interest payment date will be paid to the person in whose name that note is registered at the close of business on the regular record date for that interest. However, interest payable at maturity will be paid to the person to whom the principal is paid. If there has been a default in the payment of interest on any note, the defaulted interest may be paid to the holder of that note as of the close of business on a date between 10 and 15 days before the date proposed by us for payment of such defaulted interest or in any other lawful manner permitted by any securities exchange on which that note may be listed, if the Trustee finds it workable. (Indenture, Section 307.)

Principal, premium, if any, and interest on the notes at maturity will be payable upon presentation of the notes at the corporate trust office of The Bank of New York Mellon in the City of New York, as agent of The Bank of New York Mellon Trust Company, as paying agent for Oncor. However, we may choose to make payment of interest by check mailed to the address of the persons entitled to such payment. We may change the place of payment on the notes, appoint one or more additional paying agents (including Oncor) and remove any paying agent, all at our discretion. (Indenture, Section 702.)

Registration and Transfer

The transfer of notes may be registered, and notes may be exchanged for other notes of the same series or tranche of authorized denominations and with the same terms and principal amount, at the offices or agency of the Trustee in New York, New York. (Indenture, Section 305.) We may designate one or more additional places, or change the place or places previously designated, for the registration of the transfer and the exchange of the notes. (Indenture, Section 702.) No service charge will be made for any registration of transfer or exchange of the notes. However, we may require payment to cover any tax or other governmental charge that may be imposed in connection with such registration of transfer or exchange. We will not be required to execute or to provide for the registration of transfer or the exchange of:

• any note during the 15 days before an interest payment date,

• any note during the 15 days before giving any notice of redemption, or

• any note selected for redemption in whole or in part except the unredeemed portion of any note being redeemed in part.

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(Indenture, Section 305.)

Security

Except as described below under this heading and under “— Securing Additional Obligations,” and subject to the exceptions discussed under “— Release of Collateral,” all Debt Securities and other secured indebtedness of Oncor issued under the Indenture while the lien under the Deed of Trust is in effect will be secured equally and ratably, by a lien on all of the Collateral, which consists of our right, title and interest in and to all property, real, personal and mixed, wherever located, including the following property (other than Excepted Property, as defined below):

• all real property owned in fee, easements and other interests in real property that are specifically described in the Deed of Trust;

• all facilities, machinery, equipment and fixtures for the transmission and distribution of electric energy, including, but not limited to, all switchyards, towers, substations, transformers, poles, lines, cables, conduits, ducts, conductors, meters, regulators and all other property used or to be used for any or all of those purposes;

• all buildings, offices, warehouses, structures or improvements in addition to those referred to or otherwise included in the previous two bullets;

• all computers, data processing, data storage, data transmission and/or telecommunications facilities, equipment and apparatus necessary for the operation or maintenance of any facilities, machinery, equipment or fixtures described or referred to in the second bullet point above; and

• all of the property listed above in the process of construction.

“Excepted Property” means among other things, the following types of property: (1) cash and securities; (2) contracts, leases and other agreements of all kinds, contract rights, bills, notes and other instruments and chattel paper; (3) all revenues, income and earnings, all accounts, accounts receivable, rights to payment, payment intangibles and unbilled revenues, transition property, and all rents, tolls, issues, product and profits, claims, credits, demands and judgments; (4) governmental and other licenses, permits, franchises, consents and allowances; (5) intellectual property rights and other general intangibles; (6) vehicles, movable equipment, aircraft and vessels; (7) all goods, stock in trade, wares, merchandise and inventory held for sale or lease in the ordinary course of business; (8) materials, supplies, inventory and other personal property consumable in the operation of the Collateral; (9) fuel; (10) tools and equipment; (11) furniture and furnishings; (12) computers and data processing, data storage, data transmission, telecommunications and other facilities, equipment and apparatus, which, in any case, are used primarily for administrative or clerical purposes or are otherwise not necessary for the operation or maintenance of the facilities, machinery, equipment or fixtures that are part of the Collateral; (13) coal, lignite, ore, gas, oil and other minerals and timber rights; (14) electric energy, gas, steam, water and other products generated, produced, manufactured, purchased or otherwise acquired; (15) real property and facilities used primarily for the production or gathering of natural gas; (16) leasehold interests; (17) all property which is or has been released from the Deed of Trust; (18) all property located outside of the State of Texas; (19) all property and plants used by us in the generation of electricity; and (20) all property not acquired or constructed by us for use in our electric transmission and distribution business. (Deed of Trust, Section 1.)

The Deed of Trust provides that, in general, after-acquired property, other than Excepted Property, will constitute Collateral. (Deed of Trust, Section 1.)

As described above, the notes are secured by liens on the Collateral. At March 31, 2020, the net book value of the Collateral, after taking into account retirements, was approximately $16,600 million. The exchange notes will be secured obligations of Oncor that will rank equally with all Debt Securities and Oncor’s other outstanding secured indebtedness. At March 31, 2020, we had $9.019 billion aggregate principal amount of secured debt outstanding, which includes the aggregate principal amount of our senior secured notes and debentures, all of which are secured by the Collateral.

Permitted Liens

The lien granted pursuant to the Deed of Trust is subject to permitted liens described in the Indenture and the Indenture and Deed of Trust dated as of May 1, 2002 between Oncor and The Bank of New York Mellon Trust Company, N.A. (as successor to The Bank of New York Mellon, formerly the Bank of New York) (May 2002 Indenture). These permitted liens include (1) liens existing at the date of the May 2002 Indenture; (2) liens on property at the time we acquire the property; (3) tax liens and other governmental charges which are not delinquent or which are being contested in good faith; (4) liens incurred or created in connection with or to secure the performance of bids, tenders, contracts, leases, statutory obligations, surety bonds or appeal bonds; (5) liens securing indebtedness, neither assumed nor guaranteed by us nor on which we

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customarily pay interest, existing upon real estate or rights in or relating to real estate acquired by us for any substation, transmission line, transportation line, distribution line, right of way or similar purpose; (6) mechanics’ and materialmen’s liens; (7) certain leases and leasehold interests; (8) rights reserved to or vested in government authorities; (9) rights of others to take minerals, timber, electric energy or capacity, gas, water, steam or other products produced by us or by others on our property, rights and interests of persons other than us arising out of agreements relating to the common ownership or joint use of the property; (10) liens on the interests of persons other than us in our property; (11) liens which have been bonded or for which other security arrangements have been made; (12) purchase money liens and liens related to the acquisition of property; (13) liens which secure obligations under the Indenture and the May 2002 Indenture equally and ratably with other secured obligations of ours; (14) liens on our property to secure debt for borrowed money in an aggregate principal amount not exceeding the greater of 10% of our net tangible assets or 10% of our capitalization; (15) rights reserved to or vested in any municipality or public authority by the terms of any right, power, franchise, grant, license or permit, or by any provision of law, to terminate such right, power, franchise, grant, license or permit or to purchase or recapture or to designate a purchaser of any of our property; (16) rights reserved to or vested in any municipality or public authority to use, control or regulate any of our property; (17) any obligations or duties to any municipality or public authority with respect to any franchise, grant, license or permit; (18) any controls, liens, restrictions, regulations, easements, exceptions or reservations of any municipality or public authority applying particularly to space satellites or nuclear fuel; (19) certain judgment liens; (20) any lien arising by reason of deposits with or giving of any form of security to any governmental entity as a condition to the transaction of any business or the exercise of any privilege or license; (21) and any landlords’ lien on fixtures or movable property so long as the rent secured thereby is not in default and (22) certain easements, licenses, restrictions, defects, irregularities and certain deficiencies in titles.

Excepted Property

The Collateral does not include Excepted Property. The Deed of Trust provides that, in general, after-acquired property, other than Excepted Property, will constitute Collateral. (Deed of Trust, Section 1.) However, property that is released from the Deed of Trust will not become subject to the lien of the Deed of Trust unless and until we execute an amendment to the Deed of Trust subjecting that property to such lien.

Release of Collateral

Unless an event of default under the Indenture, the May 2002 Indenture or any other indebtedness secured by the Deed of Trust, has occurred and is continuing, we may obtain the release from the lien of the Deed of Trust of any part of the Collateral, or any interest in the Collateral, other than cash held by the Collateral Agent under the Deed of Trust (Collateral Agent), upon delivery to the Collateral Agent of an amount in cash equal to the amount, if any, by which the fair value (as determined under the Deed of Trust) of the Collateral exceeds the aggregate of:

• an amount equal to the aggregate principal amount of any obligations secured by a purchase money lien delivered to the Collateral Agent, to be held as part of the Collateral, subject to the limitations in the Deed of Trust;

• an amount equal to the cost (as determined under the Deed of Trust) or fair value (whichever is less), after making any deductions and any Property Additions (as defined in the Deed of Trust) not constituting Funded Property (as defined in the Deed of Trust), except that such deductions and additions need not be made if the Property Additions were acquired or made within the 90-day period preceding the release;

• an amount equal to 23/20 of an aggregate principal amount of additional obligations that we elect to secure under the Deed of Trust; provided that we waive the right to secure the additional obligations and any Available Bond Credits (as defined below) which were the basis of the right to secure such amount of those additional obligations will be deemed to have been made the basis of such release of property;

• an amount in cash and/or an amount equal to the aggregate principal amount of any obligations secured by purchase money lien that, in either case, is evidenced to the Collateral Agent by a certificate of the trustee or other holder of a lien prior to the lien of the Deed of Trust to have been received by such trustee or other holder in accordance with the provisions of the lien in consideration for the release of such property or any part thereof from such lien, all subject to the limitations set forth in the Deed of Trust; and

• any taxes and expenses incidental to any sale, exchange, dedication or other disposition of the property to be released. (Deed of Trust, Section 20.2.)

Unless an event of default under the Indenture, the May 2002 Indenture or any other indebtedness secured by the Deed of Trust, has occurred and is continuing, Collateral which is not Funded Property may generally be released from the lien of the Deed of Trust without depositing any cash or property with the Collateral Agent as long as (1) the aggregate amount of cost

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or fair value to Oncor (whichever is less) of all property which does not constitute Funded Property (excluding the property to be released) after certain deductions and additions, including adjustments to offset property retirements, is not less than zero or (2) the cost or fair value (whichever is less) of property to be released does not exceed the aggregate amount of the cost or fair value to Oncor (whichever is less) of property additions acquired or made within the 90-day period preceding the release. (Deed of Trust, Section 20.3.)

The Deed of Trust provides simplified procedures for the release of minor properties and property taken by eminent domain, and provides for dispositions of certain obsolete property without any release or consent by the Collateral Agent. Under the Deed of Trust, a property is considered minor if the aggregate fair value of such property on any date in a given calendar year, together with all other minor properties released in the calendar year, does not exceed the greater of (1) $10 million, or (2) 3% of the then outstanding aggregate principal amount of the obligations secured by the Deed of Trust. (Deed of Trust, Sections 20.1, 20.4 and 20.5.)

If we retain an interest in any property released from the lien granted under the Deed of Trust, the Deed of Trust will not become a lien on the property or an interest in the property or any improvements, extensions or additions to the property or renewals, replacements or substitutions of or for the property or any part or parts thereof unless we execute and deliver to the Collateral Agent an amendment of the Deed of Trust containing a grant, conveyance, transfer and mortgage thereof. (Deed of Trust, Section 20.9.)

Withdrawal or Other Application of Funded Cash; Purchase Money Obligations

Except as otherwise provided in the Deed of Trust, unless an event of default under the Indenture, the May 2002 Indenture or any other indebtedness secured by the Deed of Trust, has occurred and is continuing, any Funded Cash (as defined in the Deed of Trust) held by the Collateral Agent, and any other cash which is required to be withdrawn, used or applied as provided below, may (1) be withdrawn by us (i) to the extent of the cost or fair value to us (whichever is less) of Property Additions not constituting Funded Property, after certain deductions and additions, including adjustments to offset retirements (except that such adjustments need not be made if such property additions were acquired or made within the 90-day period preceding the withdrawal); (ii) in an amount equal to the aggregate principal amount of additional obligations we would be entitled to secure; and (iii) in an amount equal to the aggregate principal amount of outstanding obligations delivered to the Collateral Agent; (2) upon our request, be used by the Collateral Agent for the purchase or payment of obligations as directed or approved by us; and (3) be applied by the Collateral Agent to the payment at maturity or redemption of obligations. (Deed of Trust, Section 21.)

Securing Additional Obligations

The Collateral Agent will permit securing with Collateral additional obligations that we elect to secure under the Deed of Trust, at one time or from time to time in accordance with the following:

• Additional obligations may be secured on the basis of Property Additions (which do not constitute Funded Property) in a principal amount not exceeding 85% of the cost or the fair value of the Property Additions (whichever is less) after making certain deductions and additions described in the Deed of Trust;

• Additional obligations may be secured on the basis of, and in an aggregate principal amount not exceeding the aggregate principal amount of, Available Bond Credits; and

• Additional obligations may be secured on the basis of, and in an aggregate principal not exceeding the amount of, any cash deposited with the Collateral Agent for such purpose.

Any withdrawal of cash under the last bullet above will operate as a waiver by us of our right to secure the obligations on which it is based, and those obligations may not be secured by the Deed of Trust. Any Property Additions which have been made the basis of any such right to secure additional obligations that we elect to secure under the Deed of Trust will be deemed to have been made the basis of the withdrawal of such cash. Any Available Bond Credits which have been made the basis of any such right to secure additional obligations that we elect to secure under the Deed of Trust will be deemed to have been made the basis of the withdrawal of such cash. (Deed of Trust, Section 22.)

“Available Bond Credits” equaled $1.973 billion as of March 31, 2020. Available Bond Credits will be (1) increased by the principal amount of obligations (other than certain fees, expenses and other obligations payable under the Deed of Trust) paid, retired or cancelled or for the payment of which money has been deposited with the applicable secured party representative, and (2) decreased by the principal amount of additional obligations that Oncor elects to secure under the Deed of Trust pursuant to provisions described under this heading for Available Bond Credits.

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The amount of future indebtedness that could be secured by Property Additions, subject to appraisal and a certification process of such Property Additions, was approximately $2.602 billion as of March 31, 2020.

Defeasance

Our indebtedness in respect of the notes will be satisfied and discharged if we irrevocably deposit with the Trustee or any paying agent, other than Oncor, sufficient cash or U.S. government securities to pay the principal, interest and any premium when due on the stated maturity date or a redemption date of that series of notes, subject to the other conditions of the Indenture. (Indenture, Section 801.)

Limitation on Secured Debt

So long as any of the Debt Securities remain outstanding, subject to the limitations described under “— Securing Additional Obligations,” we will not issue any Secured Debt other than Permitted Secured Debt without the consent of the holders of a majority in principal amount of the outstanding Debt Securities of all series with respect to which this covenant is made, considered as one class; provided, however, that this covenant will not prohibit the creation or existence of any Secured Debt if either:

• we make effective provision whereby all notes and other affected Debt Securities then outstanding will be secured at least equally and ratably with such Secured Debt; or

• we deliver to the Trustee bonds, notes or other evidences of indebtedness secured by the lien which secures such Secured Debt in an aggregate principal amount equal to the aggregate principal amount of the notes and other affected Debt Securities then outstanding and meeting certain other requirements set forth in the Indenture.

The covenants contained in the Indenture will not afford the holders of the notes protection in the event we incur significant additional debt.

Definitions

For purposes of this subsection — “Limitation on Secured Debt,” the following terms have the meanings given below:

“Capitalization” means the total of all the following items appearing on, or included in, our unconsolidated balance sheet: (1) liabilities for indebtedness maturing more than 12 months from the date of determination and (2) common stock, common stock expense, accumulated other comprehensive income or loss, preferred stock, preference stock, premium on common stock and retained earnings (however the foregoing may be designated), less, to the extent not otherwise deducted, the cost of shares of our capital stock held in our treasury, if any. Capitalization will be determined in accordance with GAAP and practices applicable to the type of business in which we are engaged, and may be determined as of the date not more than 60 days prior to the happening of the event for which the determination is being made.

“Capitalized Lease Liabilities” means the amount, if any, shown as liabilities on our unconsolidated balance sheet for capitalized leases of electric transmission and distribution property not owned by us, which amount will be determined in accordance with GAAP and practices applicable to the type of business in which we are engaged.

“Debt” means:

• our indebtedness for borrowed money evidenced by a bond, debenture, note or other written instrument or agreement by which we are obligated to repay such borrowed money;

• any guaranty by us of any such indebtedness of another person; and

• any Capitalized Lease Liabilities of Oncor.

“Debt” does not include, among other things:

• indebtedness under any installment sale or conditional sale agreement or any other agreement relating to indebtedness for the deferred purchase price of property or services;

• any trade obligations (including any obligations under power or other commodity purchase agreements and any associated hedges or derivatives) or other obligations in the ordinary course of business;

• obligations under any lease agreement that are not Capitalized Lease Liabilities; or

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• any liens securing indebtedness, neither assumed nor guaranteed by us nor on which we customarily pay interest, existing upon real estate or rights in or relating to real estate acquired by us for substation, transmission line, transportation line, distribution line or right of way purposes.

“Net Tangible Assets” means the amount shown as total assets on our unconsolidated balance sheet, less (1) intangible assets including, but without limitation, such items as goodwill, trademarks, trade names, patents, unamortized debt discount and expense and other regulatory assets carried as assets on our unconsolidated balance sheet and (2) appropriate adjustments, if any, on account of minority interests. Net Tangible Assets will be determined in accordance with GAAP and practices applicable to the type of business in which we are engaged.

“Permitted Secured Debt” means, as of any particular time:

• Secured Debt which matures less than one year from the date of the issuance or incurrence and is not extendible at the option of the issuer; and any refundings, refinancings and/or replacements of any such Secured Debt by or with similar Secured Debt that matures less than one year from the date of such refunding, refinancing and/or replacement and is not extendible at the option of the issuer;

• Secured Debt secured by Purchase Money Liens (as defined in the Indenture) or any other liens existing or placed upon property at the time of, or within one hundred eighty (180) days after, the acquisition thereof by us, and any refundings, refinancings and/or replacements of any such Secured Debt; provided, however, that no such Purchase Money Lien or other lien will extend to or cover any of our property other than (1) the property so acquired and improvements, extensions and additions to such property and renewals, replacements and substitutions of or for the property or any part or parts of the property and (2) with respect to Purchase Money Liens, other property subsequently acquired by us;

• Secured Debt relating to governmental obligations the interest on which is not included in gross income for purposes of federal income taxation pursuant to Section 103 of the Code (or any successor provision of law), for the purpose of financing or refinancing, in whole or in part, costs of acquisition or construction of property to be used by us, to the extent that the lien which secures the Secured Debt is required either by applicable law or by the issuer of such governmental obligations or is otherwise necessary in order to establish or maintain the exclusion from gross income; and any refundings, refinancings and/or replacements of any Secured Debt by or with similar Secured Debt;

• Secured Debt (1) which is related to the construction or acquisition of property not previously owned by us or (2) which is related to the financing of a project involving the development or expansion of our property and (3) in either case, the obligee in respect of which has no recourse to us or any of our property other than the property constructed or acquired with the proceeds of such transaction or the project financed with the proceeds of such transaction (or the proceeds of such property or such project); and any refundings, refinancings and/or replacements of any such Secured Debt by or with Secured Debt described in (3) above; and

• in addition to the Permitted Secured Debt described above, Secured Debt not otherwise so permitted in an aggregate principal amount not exceeding the greater of 10% of Oncor’s Net Tangible Assets or 10% of Oncor’s Capitalization.

“Secured Debt” means Debt created, issued, incurred or assumed by us which is secured by a lien upon any of our property (other than Excepted Property). For purposes of this covenant, any Capitalized Lease Liabilities of ours will be deemed to be Debt secured by a lien on our property.

(Indenture, Section 707.)

Consolidation, Merger and Sale of Assets

Under the terms of the Indenture, we may not consolidate with or merge into any other entity or convey, transfer or lease our Electric Utility Property (as defined below) as an entirety or substantially as an entirety to any entity, unless:

• the surviving or successor entity, or an entity which acquires by conveyance or transfer or which leases our Electric Utility Property as an entirety or substantially as an entirety is organized and existing under the laws of any domestic jurisdiction and it expressly assumes our obligations on all Debt Securities then outstanding under the Indenture;

• in the case of a lease, such lease is made expressly subject to termination by us or by the Trustee and by the purchaser of the property so leased at any sale thereof at any time during the continuance of an event of default under the Indenture;

• we will have delivered to the Trustee an officer’s certificate and an opinion of counsel as provided in the Indenture; and

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• immediately after giving effect to the transaction, no event of default under the Indenture, or event which, after notice or lapse of time or both, would become an event of default under the Indenture, has occurred and is continuing.

(Indenture, Section 1201.) In the case of the conveyance or other transfer of the Electric Utility Property as or substantially as an entirety to any other entity, upon the satisfaction of all the conditions described above, Oncor would be released and discharged from all obligations and covenants under the Indenture and on the Debt Securities then outstanding unless we elect to waive such release and discharge. (Indenture, Section 1203.)

The Indenture does not prevent or restrict:

• any conveyance or other transfer, or lease, of any part of our Electric Utility Property which does not constitute the entirety, or substantially the entirety, thereof; or

• any conveyance, transfer or lease of any of our properties where we retain Electric Utility Property with a fair value in excess of 143% of the aggregate principal amount of all outstanding Debt Securities, and any other outstanding debt securities that rank equally with, or senior to, the Debt Securities with respect to such Electric Utility Property. This fair value will be determined within 90 days of the conveyance, transfer or lease by an independent expert that is approved by the Trustee.

(Indenture, Section 1205.)

“Electric Utility Property” means property of Oncor which is comprised of substantially all of our tangible properties in Texas used or useful or to be used in connection with the transmission and distribution of electric energy, exclusive of certain excepted property. (Indenture, Section 101.)

The terms of the Indenture do not restrict Oncor in a merger in which Oncor is the surviving entity. (Indenture, Section 1204.)

Events of Default

“Event of default,” when used in the Indenture with respect to Debt Securities, means any of the following:

• failure to pay interest on any Debt Security for 30 days after it is due and payable;

• failure to pay the principal of or any premium on any Debt Security when due and payable;

• failure to perform or breach of any other covenant or warranty in the Indenture that continues for 90 days after we receive written notice from the Trustee, or we and the Trustee receive a written notice from the holders of at least 33% in aggregate principal amount of the outstanding Debt Securities;

• events of bankruptcy, insolvency or reorganization of Oncor specified in the Indenture;

• sale or transfer of all or any part of the Collateral in a foreclosure of the lien on the Collateral which secures the Debt Securities and other Secured Debt (other than Permitted Secured Debt); or

• any other event of default included in any supplemental indenture for a particular series of Debt Securities.

(Indenture, Sections 901, 1301 and 1307.)

Remedies

If an event of default under the Indenture occurs and is continuing, then the Trustee or the holders of at least 33% in aggregate principal amount of the outstanding Debt Securities may declare the principal amount of all of the Debt Securities to be due and payable immediately.

At any time after a declaration of acceleration has been made and before a judgment or decree for payment of the money due has been obtained by the Trustee, the event or events of default under the Indenture giving rise to the declaration of acceleration will be considered cured, and the declaration and its consequences will be considered rescinded and annulled, if:

• we have paid or deposited with the Trustee a sum sufficient to pay:

• all overdue interest on all outstanding Debt Securities;

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• the principal of and premium, if any, on the outstanding Debt Securities that have become due otherwise than by such declaration of acceleration and overdue interest thereon;

• interest on overdue interest to the extent lawful; and

• all amounts due to the Trustee under the Indenture; and

• any other event of default under the Indenture with respect to the Debt Securities of a particular series has been cured or waived as provided in the Indenture.

(Indenture, Section 902.)

There is no automatic acceleration, even in the event of bankruptcy, insolvency or reorganization of Oncor.

If an event of default under the Deed of Trust occurs and is continuing, the Collateral Agent will, at the direction of the applicable secured party, proceed to protect and enforce its rights and the rights of the secured parties by such judicial proceedings as the applicable secured party designates to protect and enforce any such rights. Upon the occurrence and during the continuance of any event of default under the Deed of Trust and subject to any applicable grace, notice and cure provision of the Indenture or the May 2002 Indenture, on the direction of the applicable secured party, the Collateral Agent will, at the direction of the applicable secured party, sell all, but not less than all of the Collateral in accordance with the procedures set forth in the Deed of Trust. In the event of any breach of the covenants, agreements, terms or conditions of the Deed of Trust, the Collateral Agent, to the extent permitted by applicable law and principles of equity, will be entitled to enjoin such breach and obtain specific performance of any such covenant, agreement, term or condition and the Collateral Agent will have the right to invoke any equitable right or remedy as though other remedies were not provided for in the Deed of Trust. (Deed of Trust, Section 23.)

If an event of default under the Deed of Trust has occurred and, during the continuance of such event of default, the Collateral Agent has commenced judicial proceedings to enforce any right under the Deed of Trust, then the Collateral Agent will, to the extent permitted by law, be entitled, as against Oncor, to the appointment of a receiver of the Collateral and subject to the rights, if any, of others to receive collections from former, present or future customers of the rents, issues, profits, revenues and other income thereof, and whether or not any receiver is appointed, the Collateral Agent will be entitled to possession and control of, and to collect and receive the income from cash, securities and other personal property held by the Collateral Agent under the Deed of Trust and to all other remedies available to mortgagees and secured parties under the Uniform Commercial Code or any other applicable law. (Deed of Trust, Section 24.)

Upon the occurrence and continuance of an event of default under the Indenture after the termination of the lien granted by the Deed of Trust, the remedies of the Trustee and holders of notes under the Indenture would be limited to the rights of unsecured creditors.

Except as otherwise required by the TIA, the Trustee is not obligated to exercise any of its rights or powers under the Indenture at the request, order or direction of any of the holders, unless the holders offer the Trustee a reasonable indemnity. (Indenture, Section 1003.) If they provide this reasonable indemnity, the holders of a majority in principal amount of the outstanding Debt Securities will have the right to direct the time, method and place of conducting any proceeding for any remedy available to the Trustee, or exercising any power conferred upon the Trustee with respect to such Debt Securities. The Trustee is not obligated to comply with directions that conflict with law or other provisions of the Indenture. (Indenture, Section 912.)

No holder of Debt Securities will have any right to institute any proceeding under the Indenture, for the appointment of a receiver or trustee, or for any other remedy under the Indenture, unless:

• the holder has previously given to the Trustee written notice of a continuing event of default under the Indenture;

• the holders of a majority in aggregate principal amount of the outstanding Debt Securities have made a written request to the Trustee to institute proceedings in respect of the event of default under the Indenture in its own name as Trustee under the Indenture;

• such holder or holders have offered reasonable indemnity to the Trustee to institute proceedings;

• the Trustee has failed to institute any proceeding for 60 days after notice, request and offer of indemnity; and

• the Trustee has not received during such period any direction from the holders of a majority in aggregate principal amount of the outstanding Debt Securities inconsistent with the written request of the holders referred to above. (Indenture, Section 907.) However, these limitations do not apply to a suit by a holder of a Debt Security for payment of the principal, premium, if any, or interest on the Debt Security on or after the applicable due date. (Indenture, Section 908.)

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We will provide to the Trustee an annual statement by an appropriate officer as to our compliance with all conditions and covenants under the Indenture. (Indenture, Section 705.)

Trustee Lien

The Indenture provides that the Trustee will have a lien, prior to the lien on behalf of the holders of the Debt Securities, upon certain of our property and funds held or collected by the Trustee for the payment of Trustee’s reasonable compensation and expenses and for indemnity against certain liabilities. (Indenture, Section 1007.)

Modification and Waiver

Without the consent of any holder of Debt Securities, we and the Trustee may enter into one or more supplemental indentures for any of the following purposes:

• to evidence the assumption by any permitted successor of the covenants of Oncor in the Indenture and in the Debt Securities;

• to add one or more covenants of Oncor or other provisions for the benefit of the holders of all or any series or tranche of Debt Securities, or to surrender any right or power conferred upon Oncor;

• to add additional events of default under the Indenture for all or any series of outstanding Debt Securities;

• to change or eliminate or add any provision to the Indenture; provided, however, that if the change, elimination or addition will adversely affect the interests of the holders of outstanding Debt Securities of any series or tranche in any material respect, it will become effective only:

• o when the consent of the holders of Debt Securities of such series has been obtained in accordance with the Indenture; or

• o when no Debt Securities of the affected series remain outstanding under the Indenture;

• to provide additional security for any Debt Securities;

• to establish the form or terms of Debt Securities of any other series or tranche as permitted by the Indenture;

• to provide for the authentication and delivery of bearer securities with or without coupons;

• to evidence and provide for the acceptance of appointment by a separate or successor Trustee;

• to provide for the procedures required for use of a non-certificated system of registration for the Debt Securities of all or any series or tranche;

• to change any place where principal, premium, if any, and interest will be payable, Debt Securities may be surrendered for registration of transfer or exchange, and notices to us may be served;

• to amend and restate the Indenture, as originally executed and as amended from time to time, with such additions, deletions and other changes that do not adversely affect the interests of the holders of Debt Securities in any material respect; or

• to cure any ambiguity or inconsistency.

(Indenture, Section 1301.)

The holders of at least a majority in aggregate principal amount of the Debt Securities of all series and tranches then outstanding may waive compliance by us with some restrictive provisions of the Indenture. (Indenture, Section 706.) The holders of not less than a majority in principal amount of the outstanding Debt Securities may waive any past default under the Indenture, except a default in the payment of principal, premium, if any, or interest, if any, and certain covenants and provisions of the Indenture that cannot be modified or be amended without the consent of the holder of each outstanding Debt Security of any series or tranche affected. (Indenture, Section 913.)

If the Trust Indenture Act is amended after the date of the Indenture or the Deed of Trust, as applicable, in such a way as to require changes to the Indenture or the Deed of Trust, the Indenture or the Deed of Trust, as applicable, will be deemed to be amended so as to conform to that amendment to the Trust Indenture Act. Oncor and the Trustee may, without the consent of any holders, enter into one or more supplemental indentures to evidence the amendment. (Indenture, Section 1301; Deed of Trust, Section 7.1(f).)

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The consent of the holders of a majority in aggregate principal amount of the Debt Securities of all series then outstanding, considered as one class, is required for all other modifications to the Indenture. However, if less than all of the series of Debt Securities outstanding are directly affected by a proposed supplemental indenture, then the consent only of the holders of a majority in aggregate principal amount of the outstanding Debt Securities of all series that are directly affected, considered as one class, will be required. If less than all of the tranches of Debt Securities outstanding are directly affected by a proposed supplemental indenture, then the consent only of the holders of a majority in aggregate principal amount of the outstanding Debt Securities of all tranches that are directly affected, considered as one class, will be required. No such amendment or modification may, without the consent of the holder of each outstanding Debt Security of each series or tranche so directly affected:

• change the stated maturity of the principal of, or any installment of principal of or interest on, any Debt Security, or reduce the principal amount of any Debt Security or its rate of interest or change the method of calculating that interest rate or reduce any premium payable upon redemption, or change the currency in which payments are made, or impair the right to institute suit for the enforcement of any payment on or after the stated maturity of any Debt Security;

• reduce the percentage in principal amount of the outstanding Debt Securities of any series or tranche the consent of the holders of which is required for any supplemental indenture or any waiver of compliance with a provision of the Indenture or any default thereunder and its consequences, or reduce the requirements for quorum or voting; or

• modify some of the provisions of the Indenture relating to supplemental indentures, waivers of some covenants and waivers of past defaults with respect to the Debt Securities of any series or tranche.

(Indenture, Section 1302.)

A supplemental indenture that changes or eliminates any covenant or other provision of the Indenture which has expressly been included solely for the benefit of the holders of, or which is to remain in effect only so long as there will be outstanding, Debt Securities of one or more particular series, or one or more tranches thereof, or modifies the rights of the holders of Debt Securities of such series or tranches with respect to such covenant or other provision, will be deemed not to affect the rights under the Indenture of the holders of Securities of any other series or tranche. (Indenture, Section 1302.)

The Indenture provides that Debt Securities owned by us or anyone else required to make payment on the Debt Securities or their respective affiliates will be disregarded and considered not to be outstanding in determining whether the required holders have given a request or consent. (Indenture, Section 101.)

We may fix in advance a record date to determine the holders entitled to give any request, demand, authorization, direction, notice, consent, waiver or other such act of the holders, but we will have no obligation to do so. If we fix a record date, that request, demand, authorization, direction, notice, consent, waiver or other such act of the holders may be given before or after that record date, but only the holders of record at the close of business on that record date will be considered holders for the purposes of determining whether holders of the required percentage of the outstanding notes have authorized or agreed or consented to the request, demand, authorization, direction, notice, consent, waiver or other such act of the holders. For that purpose, the outstanding notes will be computed as of the record date. Any request, demand, authorization, direction, notice, consent, election, waiver or other such act of a holder of any Debt Security will bind every future holder of that Debt Security and the holder of every Debt Security issued upon the registration of transfer of or in exchange for that Debt Security. A transferee will also be bound by acts of the Trustee or us in reliance thereon, whether or not notation of that action is made upon the Debt Security. (Indenture, Section 104.)

Resignation of a Trustee

The Trustee may resign at any time by giving written notice to us or may be removed at any time by act of the holders of a majority in principal amount of all series of Debt Securities then outstanding delivered to the Trustee and us. No resignation or removal of the Trustee and no appointment of a successor trustee will be effective until the acceptance of appointment by a successor trustee. So long as no event which is, or after notice or lapse of time, or both, would become, an event of default has occurred and is continuing and except with respect to a trustee appointed by act of the holders, if we have delivered to the Trustee a resolution of our board of directors appointing a successor trustee and such successor has accepted the appointment in accordance with the terms of the Indenture, the Trustee will be deemed to have resigned and the successor will be deemed to have been appointed as trustee in accordance with the Indenture. (Indenture, Section 1010.)

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Notices

Notices to holders of the notes will be given by mail to the addresses of such holders as they may appear in the security register for the notes of that series, subject to the applicable procedures of DTC. (Indenture, Section 106.)

Title

Prior to due presentment of a note for registration of transfer, Oncor, the Trustee, and any agent of Oncor or the Trustee, may treat the person in whose name any note is registered as the absolute owner of that note, whether or not such note may be overdue, for the purpose of making payments and for all other purposes irrespective of notice to the contrary. (Indenture, Section 308.)

Governing Law

The Indenture and the notes provide that they will be governed by, and construed in accordance with, the laws of the State of New York, except to the extent that the Trust Indenture Act is applicable and except to the extent that the law of the State of Texas mandatorily governs. (Indenture, Section 112.)

Information About the Trustee

The Trustee under the Indenture is The Bank of New York Mellon Trust Company, N.A. The Bank of New York Mellon Trust Company, N.A acts, and may act, as trustee under various other indentures, trusts and guarantees of us and our affiliates. We and our affiliates maintain deposit accounts and credit and liquidity facilities and conduct other commercial and investment banking transactions with the Trustee and its affiliates in the ordinary course of their businesses.

Book-Entry

The certificates representing the exchange notes will be issued in fully registered form, without coupons. The exchange notes will be deposited with, or on behalf of, DTC, and registered in the name of Cede & Co., as DTC’s nominee in the form of one or more global certificates or will remain in the custody of the Trustee pursuant to a FAST Balance Certificate Agreement between DTC and the Trustee. Upon the issuance of the global certificates, DTC or its nominee will credit, on its internal system, the respective principal amount of the individual beneficial interests represented by such global certificates to the accounts of persons who have accounts with such depository. Ownership of beneficial interests in a global certificate will be limited to persons who have accounts with DTC (participants) or persons who hold interests through participants. Ownership of beneficial interests in a global certificate will be shown on, and the transfer of that ownership will be effected only through, records maintained by DTC or its nominee (with respect to interests of participants) and the records of participants (with respect to interests of persons other than participants).

Investors that exchange outstanding notes for exchange notes may also hold their interests directly through Clearstream Banking or Euroclear, if they are participants in such systems, or indirectly through organizations that are participants in such systems. Investors may also hold such interests through organizations other than Clearstream Banking or Euroclear that are participants in the DTC system. Clearstream Banking and Euroclear will hold interests in the global certificate representing exchange notes on behalf of their participants through DTC.

So long as DTC, or its nominee, is the registered owner or holder of a global certificate, DTC or such nominee, as the case may be, will be considered the sole owner or holder of the exchange notes represented by such global certificate for all purposes under the Indenture and the exchange notes. No beneficial owner of an interest in a global certificate will be able to transfer the interest except in accordance with DTC’s applicable procedures, in addition to those provided for under the Indenture and, if applicable, those of Euroclear and Clearstream Banking.

Payments of the principal of and interest on a global certificate will be made to DTC or its nominee, as the case may be, as the registered owner thereof. Neither Oncor, the Trustee nor any paying agent will have any responsibility or liability for any aspect of the records relating to or payments made on account of beneficial ownership interests in a global certificate or for maintaining, supervising or reviewing any records relating to such beneficial ownership interests. DTC or its nominee, upon receipt of any payment of principal or interest in respect of a global certificate, will credit participants’ accounts with payments in amounts proportionate to their respective beneficial interests in the principal amount of such global certificate as shown on the records of DTC or its nominee. Oncor also expects that payments by participants to owners of beneficial interests in such global certificate held through such participants will be governed by standing instructions and customary practices, as is now the case with securities held for the accounts of customers registered in the names of nominees for such customers. Such payments will be the responsibility of such participants.

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Transfers between participants in DTC will be effected in the ordinary way in accordance with DTC rules. If a holder requires physical delivery of a certificated exchange note for any reason, including to sell exchange notes to persons in jurisdictions which require such delivery of such exchange notes or to pledge such exchange notes, such holder must transfer its interest in a global certificate in accordance with DTC’s applicable procedures and the procedures set forth in the Indenture and, if applicable, those of Euroclear and Clearstream Banking. Because DTC can act only on behalf of participants in DTC, which in turn act on behalf of indirect participants, the ability of a person having beneficial interests in a global certificate to pledge such interests to persons that do not participate in the DTC system, or otherwise take actions in respect of such interests, may be affected by the lack of a physical certificate evidencing such interests.

DTC will take any action permitted to be taken by a holder of exchange notes (including the presentation of exchange notes for exchange as described below) only at the direction of one or more participants to whose account the DTC interests in a global certificate is credited and only in respect of such portion of the aggregate principal amount of the exchange notes as to which such participant or participants has or have given such direction. However, if there is an event of default under the exchange notes, DTC will exchange a global certificate for certificated exchange notes, which it will distribute to its participants.

DTC is a limited purpose trust company organized under the laws of the State of New York, a member of the Federal Reserve System, a “clearing corporation” within the meaning of the Uniform Commercial Code and a “Clearing Agency” registered pursuant to the provisions of Section 17A of the Exchange Act. DTC was created to hold securities for its participants and facilitate the clearance and settlement of securities transactions between participants through electronic book-entry changes in accounts of its participants, thereby eliminating the need for physical movement of certificates. Participants include securities brokers and dealers, banks, trust companies and clearing corporations and may include certain other organizations. Indirect access to the DTC system is available to others such as banks, brokers, dealers and trust companies that clear through or maintain a custodial relationship with a participant, either directly or indirectly (indirect participants). The rules applicable to DTC and its participants are on file with the SEC.

Although DTC, Euroclear and Clearstream Banking are expected to follow the foregoing procedures in order to facilitate transfers of interests in the exchange notes represented by global certificates among their respective participants, they are under no obligation to perform or continue to perform such procedures, and such procedures may be discontinued at any time. Neither Oncor nor the Trustee will have any responsibility for the performance by DTC, Euroclear or Clearstream Banking or their respective participants or indirect participants of their respective obligations under the rules and procedures governing their operations.

If DTC is at any time unwilling or unable to continue as a depository for a global certificate and a successor depository is not appointed by us within 90 days, we will issue certificated exchange notes in exchange for a global certificate.

We will make all payments of principal and interest in immediately available funds.

Secondary trading in long-term bonds and notes of corporate issuers is generally settled in clearing-house or next-day funds. In contrast, beneficial interests in the exchange notes that are not certificated exchange notes will trade in DTC’s Same-Day Funds Settlement System until maturity. Therefore, the secondary market trading activity in such interests will settle in immediately available funds. No assurance can be given as to the effect, if any, of settlement in immediately available funds on trading activity in the exchange notes.

The information in this subsection, “— Book-Entry,” concerning DTC and DTC’s book-entry system has been obtained from sources that Oncor believes to be reliable, but Oncor does not take any responsibility for the accuracy of this information.

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SUMMARY OF MATERIAL UNITED STATES FEDERAL INCOME TAX CONSEQUENCES

The following discussion summarizes certain material U.S. federal income tax consequences relating to the exchange of outstanding notes for exchange notes in the exchange offers. This summary addresses only the U.S. federal income tax consequences of the exchange of outstanding notes originally acquired at their initial offering for an amount of cash equal to their issue price and held as “capital assets” within the meaning of section 1221 of the Code. This discussion does not address the issuance of any additional securities by us because no additional securities are contemplated by this prospectus. This discussion is based upon the Code and the U.S. Treasury regulations, rulings, administrative pronouncements and judicial decisions thereunder, all as of the date hereof and all of which are subject to change or differing interpretations at any time, possibly with retroactive effect. We cannot assure you that the U.S. Internal Revenue Service (IRS) will not challenge one or more of the tax consequences described herein. We have not obtained, nor do we intend to obtain, a ruling from the IRS with respect to the U.S. federal income tax consequences of the exchange of outstanding notes for exchange notes in the exchange offers.

This discussion does not address all U.S. federal income tax considerations that may be relevant to a particular holder in light of the holder’s circumstances or to certain categories of investors that may be subject to special treatment, such as, for example, banks and other financial institutions, regulated investment companies, real estate investment trusts, insurance companies, tax-exempt organizations, dealers in securities, brokers, traders in securities that elect to mark-to-market their securities, persons who hold the notes through partnerships or other pass-through entities, controlled foreign corporations, passive foreign investment companies, persons subject to special tax accounting rules under section 451(b) of the Code, persons that acquired the notes in connection with employment or other performance of services, persons who have ceased to be U.S. citizens or to be taxed as resident aliens, U.S. holders whose “functional currency” for U.S. federal income tax purposes is not the U.S. dollar or persons who hold the notes as part of a hedge, conversion, constructive sale, straddle or other integrated transaction. In addition, this discussion does not address any U.S. federal gift tax, estate tax or alternative minimum tax consequences or any state, local, foreign or other tax consequences or any applicable tax treaties.

If a partnership (including an entity taxable as a partnership for U.S. federal income tax purposes) holds the outstanding notes or the exchange notes, as the case may be, the tax treatment of the partnership and a partner in such partnership generally will depend upon the status of the partner and upon the activities of the partnership. A beneficial owner of outstanding notes or exchange notes that is a partnership for U.S. federal income tax purposes and partners in such a partnership are not included in the discussion below. If you are a partnership holding outstanding notes or exchange notes, as the case may be, or a partner in such a partnership, you should consult your own tax advisor regarding the tax consequences associated with an investment in the outstanding notes or the exchange notes.

The exchange of outstanding notes for exchange notes in the exchange offers will not constitute a taxable exchange or other taxable event for U.S. federal income tax purposes. Consequently, you will not recognize gain or loss upon receipt of an exchange note, your holding period for the exchange note should include your holding period for the outstanding note exchanged therefor and your adjusted tax basis in the exchange note should be the same as your adjusted tax basis in the outstanding note immediately before the exchange.

This discussion is for general purposes only. Each holder of outstanding notes is urged to consult such holder’s own tax advisor regarding the potential U.S. federal income tax consequences of the exchange of the outstanding notes for the exchange notes in the exchange offers including the extent to which such holder’s particular circumstances may affect the general results outlined herein, as well as the consequences of the tax laws of any state, local or foreign jurisdiction or under any applicable tax treaties.

SUMMARY OF MATERIAL ERISA CONSIDERATIONS

The following is a summary of material considerations associated with the exchange of outstanding notes for exchange notes by employee benefit plans that are subject to the Employee Retirement Income Security Act of 1974, as amended (ERISA), plans, individual retirement accounts and other arrangements that are subject to Section 4975 of the Code; or plans that are subject to provisions under any other federal, state, local, non-U.S. or other laws, rules or regulations that are similar to such provisions of ERISA or the Code (collectively, Similar Laws); and entities whose underlying assets are considered to include “plan assets” of such employee benefit plans, plans, accounts or arrangements (each, a Plan).

General Fiduciary Matters

ERISA and the Code impose certain duties on persons who are fiduciaries of a Plan subject to Title I of ERISA and prohibit certain transactions involving the assets of a Plan subject to Title I of ERISA or Section 4975 of the Code (an ERISA Plan) and its fiduciaries or other interested parties.

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In considering an exchange of outstanding notes that are assets of any Plan for exchange notes, a fiduciary or trustee should determine whether the exchange and the investment in exchange notes is in accordance with the documents and instruments governing the Plan and the applicable provisions of ERISA, the Code or any Similar Laws relating to a person’s duties to the Plan including, without limitation, the prudence, diversification, delegation of control and prohibited transaction provisions of ERISA, the Code and any other applicable Similar Laws.

Prohibited Transaction Issues

Section 406 of ERISA and Section 4975 of the Code prohibit ERISA Plans from engaging in specified transactions involving plan assets with persons or entities who are “parties in interest,” within the meaning of ERISA, or “disqualified persons,” within the meaning of Section 4975 of the Code, unless an exemption is available. A party in interest or disqualified person who engages in a nonexempt prohibited transaction may be subject to excise taxes under the Code and other penalties and liabilities under ERISA. In addition, the fiduciary of the ERISA Plan that engages in such a nonexempt prohibited transaction may be subject to penalties and liabilities under ERISA and/or the Code. The exchange of outstanding notes for exchange notes and the acquisition and/or holding of exchange notes by an ERISA Plan with respect to which we are considered a party in interest or disqualified person may constitute or result in a direct or indirect prohibited transaction under Section 406 of ERISA and/or Section 4975 of the Code, unless the exchange is made and the investment is acquired and is held in accordance with an applicable statutory, class or individual prohibited transaction exemption. Included among the exemptions that may apply to the exchange and to the acquisition and holding of the exchange notes are the U.S. Department of Labor prohibited transaction class exemption (PTCE) 84-14, respecting transactions determined by independent qualified professional asset managers, PTCE 90-1, respecting transactions involving insurance company pooled separate accounts, PTCE 91-38, respecting transactions involving bank collective investment funds, PTCE 95-60, respecting transactions involving life insurance company general accounts and PTCE 96-23, respecting transactions determined by in-house asset managers. In addition, Section 408(b)(17) of ERISA and Section 4975(d)(20) of the Code provide limited relief from the prohibited transaction provisions of ERISA and Section 4975 of the Code for certain transactions between an ERISA Plan and a person that is a party in interest or disqualified person solely by reason of providing services to the ERISA Plan, or a relationship to such a service provider, provided that neither the party in interest/disqualified person nor any of its affiliates (directly or indirectly) have or exercise any discretionary authority or control or render any investment advice with respect to the assets of the ERISA Plan involved in the transaction and provided further that the ERISA Plan pays no more than (or, if applicable, receives no less than) adequate consideration in connection with the transaction. There can be no assurance that all of the conditions of any such exemption will be satisfied.

Because of the foregoing, the exchange notes should not be acquired or held by any person investing “plan assets” of any Plan, unless such acquisition and holding (and the exchange of outstanding notes for exchange notes) will not constitute a non-exempt prohibited transaction under ERISA or the Code or a violation of any applicable Similar Laws.

Representation

By acceptance of an exchange note, each acquirer and subsequent transferee will be deemed to have represented and warranted that either (i) no portion of the assets used by such acquirer or transferee to acquire and hold the exchange notes or any interest therein constitutes assets of any Plan or (ii) the acquisition and holding of the exchange notes or any interest therein (and the exchange of outstanding notes for exchange notes) by such acquirer or transferee will not constitute a non-exempt prohibited transaction under Section 406 of ERISA or Section 4975 of the Code or a violation of any applicable Similar Laws.

The foregoing discussion is general in nature and is not intended to be all-inclusive. Due to the complexity of these rules and the penalties that may be imposed upon persons involved in non-exempt prohibited transactions, it is particularly important that fiduciaries or other persons considering exchanging outstanding notes for exchange notes (and holding the exchange notes) on behalf of, or with the assets of, any Plan, consult with their counsel regarding the potential applicability of ERISA, Section 4975 of the Code or any Similar Laws to such transactions and whether an exemption from any restrictions thereunder would be applicable to the exchange of outstanding notes for exchange notes and the acquisition and holding of the exchange notes.

PLAN OF DISTRIBUTION

Each broker-dealer that receives exchange notes for its own account pursuant to the exchange offers must acknowledge that it will deliver a prospectus in connection with any resale of such exchange notes. This prospectus, as it may be amended or supplemented from time to time, may be used by a broker-dealer in connection with resales of exchange notes received in exchange for outstanding notes where such outstanding notes were acquired as a result of market-making activities or other trading activities. We have agreed to keep effective the registration statement of which this prospectus is a part until the earlier of 90 days after the completion of the exchange offers or such time as broker-dealers no longer own any notes. In addition, all dealers effecting transactions in the exchange notes may be required to deliver a prospectus.

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We will not receive any proceeds from any sale of exchange notes by broker-dealers. Exchange notes received by broker-dealers for their own account pursuant to the exchange offers may be sold from time to time in one or more transactions in the over-the-counter market, in negotiated transactions, through the writing of options on the exchange notes or a combination of such methods of resale, at market prices prevailing at the time of resale, at prices related to such prevailing market prices or at negotiated prices. Any such resale may be made directly to purchasers or through brokers or dealers who may receive compensation in the form of commissions or concessions from any such broker-dealer and/or the purchasers of any such exchange notes. Any broker-dealer that resells exchange notes that were received by it for its own account pursuant to the exchange offers and any broker or dealer that participates in a distribution of such exchange notes may be deemed to be an “underwriter” within the meaning of the Securities Act, and any profit of any such resale of exchange notes and any commission or concessions received by any such persons may be deemed to be underwriting compensation under the Securities Act. The letter of transmittal states that, by acknowledging that it will deliver and by delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act.

Subject to certain limitations set forth in the registration rights agreement, we have agreed to pay all expenses incident to our performance of or compliance with our obligations under the registration rights agreement with respect to the exchange offers (including the reasonable expenses of one counsel for the holders of the outstanding notes) other than commissions or concessions of any broker-dealers and will indemnify you (including any broker-dealers) against certain liabilities, including liabilities under the Securities Act.

LEGAL MATTERS

The validity and enforceability of the exchange notes will be passed upon for us by Baker & McKenzie LLP.

EXPERTS

The consolidated financial statements of Oncor Electric Delivery Company LLC as of December 31, 2019 and 2018 and for each of the three years in the period ended December 31, 2019, included in this prospectus have been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their report, appearing herein. Such consolidated financial statements have been so included in reliance upon the report of such firm given upon their authority as experts in accounting and auditing.

AVAILABLE INFORMATION

We have filed with the SEC a registration statement on Form S-4 under the Securities Act with respect to the exchange notes. This prospectus, which forms a part of the registration statement, does not contain all of the information set forth in the registration statement. For further information with respect to us and the exchange notes, reference is made to the registration statement. Statements contained in this prospectus as to the contents of any contract or other document are not necessarily complete.

We file annual, quarterly and current reports and other information with the SEC. You may read and copy any document we have or will file with the SEC at the SEC’s public website (www.sec.gov). This information is also available free of charge on our website (http://www.oncor.com) as soon as reasonably practicable after we electronically file such material with, or furnish it to, the SEC. Information on our website or available by hyperlink from our website does not constitute part of this prospectus.

You should rely only upon the information provided in this prospectus. We have not authorized anyone to provide you with different information. You should not assume that the information in this prospectus is accurate as of any date other than the date of this prospectus.

SEC POSITION ON INDEMNIFICATION FOR SECURITIES ACT LIABILITIES

Insofar as indemnification for liabilities arising under the Securities Act may be permitted to directors, officers or persons controlling the registrant pursuant to the foregoing provisions, the registrant has been informed that in the opinion of the SEC, such indemnification is against public policy as expressed in the Securities Act and is therefore unenforceable.

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GLOSSARY

When the following terms and abbreviations appear in the text of this prospectus, they have the meanings indicated below.

AMS	advanced metering system
Annual Financial Statements	Refers to our audited consolidated financial statements, including the notes to those statements, included in this prospectus beginning on page F-25
ASU	Accounting Standards Update
Code	The Internal Revenue Code of 1986, as amended
COVID-19	Coronavirus Disease 2019, the disease caused by the novel strain of coronavirus reported to have surfaced in late 2019
CP Notes	Unsecured commercial paper notes issued under our CP Program
CP Program	Commercial paper program
Credit Facility	Revolving Credit Agreement, dated as of November 17, 2017, among Oncor, as borrower, the lenders from time to time party thereto, JPMorgan Chase Bank, N.A., as administrative agent and swingline lender, and the fronting banks from time to time party thereto
DCRF	Distribution cost recovery factor
Deed of Trust	Deed of Trust, Security Agreement and Fixture Filing, dated as of May 15, 2008, made by Oncor to and for the benefit of The Bank of New York Mellon Trust Company, N.A. (as successor to The Bank of New York Mellon, formerly The Bank of New York), as collateral agent, as amended
Disinterested Director	Refers to a member of our board of directors who is a “disinterested director” pursuant to our Limited Liability Company Agreement. Our Limited Liability Company Agreement requires that seven of the thirteen members of our board of directors be “disinterested directors” who (i) shall be independent directors in all material respects under the rules of the New York Stock Exchange in relation to Sempra or its subsidiaries and affiliated entities and any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, and (ii) shall have no material relationship with Sempra or its subsidiaries or affiliated entities or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, currently or within the previous ten years
EECRF	Energy efficiency cost recovery factor
EFH Bankruptcy Proceedings	Refers to voluntary petitions for relief under Chapter 11 of the U.S. Bankruptcy Code filed in U.S. Bankruptcy Court for the District of Delaware on April 29, 2014 by EFH Corp. and the substantial majority of its direct and indirect subsidiaries. The Oncor Ring-Fenced Entities were not parties to the EFH Bankruptcy Proceedings
EFH Corp.	Refers to Energy Future Holdings Corp., a holding company, and/or its subsidiaries, depending on context. Renamed Sempra Texas Holdings Corp. upon closing of the Sempra Acquisition
EFIH	Refers to Energy Future Intermediate Holding Company LLC, a direct, wholly owned subsidiary of EFH Corp. and the direct parent of Oncor Holdings. Renamed Sempra Texas Intermediate Holding Company LLC upon closing of the Sempra Acquisition
EPA	U.S. Environmental Protection Agency
ERCOT	Electric Reliability Council of Texas, Inc., the independent system operator and the regional coordinator of various electricity systems within Texas
ERISA	Employee Retirement Income Security Act of 1974, as amended
FASB	Financial Accounting Standards Board
FERC	U.S. Federal Energy Regulatory Commission
Fitch	Fitch Ratings, Ltd. (a credit rating agency)
GAAP	Generally accepted accounting principles of the U.S.
InfraREIT	InfraREIT, Inc., which was merged with and into a wholly owned subsidiary of Oncor on May 16, 2019 in the InfraREIT Acquisition, with the surviving entity being a wholly owned subsidiary of Oncor renamed Oncor NTU Holdings Company LLC

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InfraREIT Acquisition	Refers to Oncor’s acquisition of all of the equity interests of InfraREIT and InfraREIT Partners on May 16, 2019 pursuant to the transactions contemplated by the InfraREIT Merger Agreement and the SDTS-SU Asset Exchange
InfraREIT Merger Agreement	Refers to the Agreement and Plan of Merger, dated as of October 18, 2018, among Oncor, 1912 Merger Sub LLC (a wholly owned, subsidiary of Oncor), Oncor T&D Partners, LP (a wholly owned indirect subsidiary of Oncor), InfraREIT and InfraREIT Partners, which was completed on May 16, 2019
InfraREIT Partners	InfraREIT Partners, LP, a subsidiary of InfraREIT, which, as a result of the InfraREIT Acquisition, became an indirect wholly owned subsidiary of Oncor and was renamed Oncor NTU Partnership LP
Interim Financial Statements	Refers to our unaudited consolidated financial statements, including the notes to those statements, included in this prospectus beginning on page F-2 and ending on page F-23
Investment LLC	Refers to Oncor Management Investment LLC, a limited liability company and former minority membership interest owner (approximately 0.22%) of Oncor, whose managing member is Oncor and whose Class B equity interests are owned by certain current or former members of the management team and independent directors of Oncor
IRS	U.S. Internal Revenue Service
Kv	Kilovolts
KWh	Kilowatt-hours
LIBOR	London Interbank Offered Rate, an interest rate at which banks can borrow funds, in marketable size, from other banks in the London interbank market
Limited Liability Company Agreement	The Third Amended and Restated Limited Liability Company Agreement of Oncor, dated as of March 9, 2018, by and among Oncor Holdings and Texas Transmission, as amended
LP&L	Lubbock Power & Light
Moody’s	Moody’s Investors Service, Inc. (a credit rating agency)
MW	Megawatts
NERC	North American Electric Reliability Corporation
Note Purchase Agreements	Refers to (i) the Note Purchase Agreement, dated May 3, 2019, pursuant to which Oncor issued its 6.47% Senior Notes, Series A, due September 30, 2030, 7.25% Senior Notes, Series B, due December 30, 2029, and 8.50% Senior Notes, Series C, due December 30, 2020 and (ii) the Note Purchase Agreement, dated May 6, 2019, pursuant to which Oncor issued its 3.86% Senior Notes, Series A, due December 3, 2025 and 3.86% Senior Notes, Series B, due January 14, 2026
NTU	Oncor Electric Delivery Company NTU LLC (formerly SDTS until the closing of the InfraREIT Acquisition), a wholly owned, indirect subsidiary of Oncor
Oncor	Oncor Electric Delivery Company LLC, a direct, majority-owned subsidiary of Oncor Holdings
Oncor Holdings	Oncor Electric Delivery Holdings Company LLC, the direct majority owner (80.25% equity interest) of Oncor. Oncor Holdings is wholly owned by STIH
Oncor OPEB Plans	Refers to plans sponsored by Oncor that offer certain postretirement health care and life insurance benefits to eligible current and former Oncor employees, certain eligible current and former EFH Corp. and Vistra employees, and their eligible dependents
Oncor Retirement Plan	Refers to a defined benefit pension plan sponsored by Oncor
Oncor Ring-Fenced Entities	Refers to Oncor Holdings and its direct and indirect subsidiaries, including Oncor and Oncor’s direct and indirect subsidiaries
OPEB	Other postretirement employee benefits
PUCT	Public Utility Commission of Texas
PURA	Texas Public Utility Regulatory Act
REP	Retail electric provider
ROU	Right-of-use
S&P	S&P Global Ratings, a division of S&P Global Inc. (a credit rating agency)
SDTS	Sharyland Distribution & Transmission Services, L.L.C., an indirect subsidiary of InfraREIT, which was renamed Oncor Electric Delivery Company NTU LLC in connection with the InfraREIT Acquisition

147

SDTS-SU Asset Exchange	Refers to the transactions contemplated by the Agreement and Plan of Merger, dated as of October 18, 2018, by and among SU, SDTS and Oncor pursuant to which SU and SDTS exchanged certain assets as a condition to the closing of the transactions contemplated by the InfraREIT Merger Agreement
SEC	U.S. Securities and Exchange Commission
Securities Act	The Securities Act of 1933, as amended
Sempra	Sempra Energy
Sempra Acquisition	Refers to the transactions contemplated by the plan of reorganization confirmed in the EFH Bankruptcy Proceedings and that certain Agreement and Plan of Merger, dated as of August 21, 2017, by and among EFH Corp., EFIH, Sempra and one of Sempra’s wholly owned subsidiaries, pursuant to which Sempra indirectly acquired the 80.03% of Oncor’s membership interests owned indirectly by EFH Corp. and EFIH. The transactions closed March 9, 2018
Sempra Order	Refers to the final order issued by the PUCT in PUCT Docket No. 47675 approving the Sempra Acquisition
Sempra-Sharyland Transaction	Refers to Sempra’s May 16, 2019 acquisition of an indirect 50% ownership interest in Sharyland Holdings
Sharyland	Refers to Sharyland Utilities, L.L.C. (formerly SU), a subsidiary of Sharyland Holdings
Sharyland 2017 Agreement	Refers to that certain Agreement and Plan of Merger, dated as of July 21, 2017, by and among the Sharyland Entities, Oncor, and Oncor AssetCo LLC, a wholly owned subsidiary of Oncor
Sharyland 2017 Asset Exchange	Refers to the asset swap consummated on November 9, 2017 pursuant to which Oncor received substantially all of the distribution assets and certain transmission assets of SDTS and SU in exchange for certain of Oncor’s transmission assets and cash. The asset swap was completed pursuant to PUCT Docket No. 47469 and the Sharyland 2017 Agreement
Sharyland Entities	Refers to SDTS, SU, SU AssetCo, L.L.C., a wholly owned subsidiary of SU, and SDTS AssetCo, L.L.C., a wholly owned subsidiary of SDTS, each of which was a party to the Sharyland 2017 Agreement
Sharyland Holdings	Refers to Sharyland Holdings, L.P., an entity in which Sempra acquired an indirect 50% ownership interest in the Sempra-Sharyland Transaction. Sharyland Holdings is the parent of Sharyland
Sponsor Group	Refers collectively to certain investment funds affiliated with Kohlberg Kravis Roberts & Co. L.P., TPG Global, LLC and GS Capital Partners, an affiliate of Goldman, Sachs & Co., that controlled Texas Holdings
STH	Refers to Sempra Texas Holdings Corp., a Texas corporation (formerly EFH Corp. prior to the closing of the Sempra Acquisition), which is wholly owned by Sempra and the direct parent of STIH
STIH	Refers to Sempra Texas Intermediate Holding Company LLC., a Delaware limited liability company (formerly EFIH prior to the closing of the Sempra Acquisition), and the sole member of Oncor Holdings following the Sempra Acquisition
SU	Refers to Sharyland Utilities, L.P., which was converted into Sharyland on May 16, 2019 in connection with the Sempra-Sharyland Transaction
Supplemental Retirement Plan	Refers to the Oncor Supplemental Retirement Plan
TCEQ	Texas Commission on Environmental Quality
TCJA	“Tax Cuts and Jobs Act,” enacted on December 22, 2017
TCOS	Transmission cost of service
TCRF	Transmission cost recovery factor
Texas Holdings	Refers to Texas Energy Future Holdings Limited Partnership, a limited partnership controlled by the Sponsor Group that owned substantially all of the common stock of EFH Corp. prior to the closing of the Sempra Acquisition
Texas Holdings Group	Refers to Texas Holdings and its direct and indirect subsidiaries other than the Oncor Ring-Fenced Entities
Texas margin tax	A privilege tax imposed on taxable entities chartered/organized or doing business in the State of Texas that, for accounting purposes, is reported as an income tax

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Texas RE	Refers to Texas Reliability Entity, Inc., an independent organization that develops reliability standards for the ERCOT region and monitors and enforces compliance with NERC standards and ERCOT protocols
Texas Transmission	Refers to Texas Transmission Investment LLC, a limited liability company that owns a 19.75% equity interest in Oncor. Texas Transmission is an entity indirectly owned by a private investment group led by OMERS Administration Corporation (acting through its infrastructure investment entity, OMERS Infrastructure Management Inc.) and Cheyne Walk Investment Pte. Ltd. Sempra (through STIH) owns an indirect 1% ownership interest in Texas Transmission
U.S.	United States of America
Vistra	Refers to Vistra Energy Corp., and/or its subsidiaries, depending on context, formerly a subsidiary of EFH Corp. until October 2016
Vistra Retirement Plan	Refers to a defined benefit pension plan sponsored by an affiliate of Vistra, in which Oncor participates (formerly EFH Retirement Plan)

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INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

ONCOR ELECTRIC DELIVERY COMPANY LLC

Unaudited Interim Financial Statements for the Three Months Ended March 31, 2020 and 2019
Statements of Consolidated Income for the three months ended March  31, 2020 and 2019	F-2
Statements of Consolidated Comprehensive Income for the three months ended March 31, 2020 and 2019	F-2
Statements of Consolidated Cash Flows for the three months March  31, 2020 and 2019	F-3
Consolidated Balance Sheets, as of March 31, 2020 and December  31, 2019	F-4
Notes to Unaudited Interim Financial Statements	F-5
Audited Financial Statements for the Three Fiscal Years Ended December 31, 2019
Report of Independent Registered Public Accounting Firm	F-24
Statements of Consolidated Income for each of the three fiscal years in the period ended December 31, 2019	F-25
Statements of Consolidated Comprehensive Income for each of the three fiscal years in the period ended December 31, 2019	F-25
Statements of Consolidated Cash Flows for each of the three fiscal years in the period ended December 31, 2019	F-26
Consolidated Balance Sheets, as of December 31, 2019 and 2018	F-27
Statements of Consolidated Membership Interests for each of the three fiscal years in the period ended December 31, 2019	F-28
Notes to Audited Financial Statements	F-29

F-1

ONCOR ELECTRIC DELIVERY COMPANY LLC

CONDENSED STATEMENTS OF CONSOLIDATED INCOME

(Unaudited)

	Three Months Ended March 31,
	2020			2019
	(millions of dollars)
Operating revenues (Note 3)	$	1,072		$	1,016
Operating expenses:
Wholesale transmission service		245			260
Operation and maintenance		232			221
Depreciation and amortization		193			172
Provision in lieu of income taxes (Note 9)		29			25
Taxes other than amounts related to income taxes		131			122
Total operating expenses		830			800
Operating income		242			216
Other deductions and (income) — net (Note 10)		13			17
Nonoperating benefit in lieu of income taxes		(3	)		(3	)
Interest expense and related charges (Note 10)		101			86
Net income	$	131		$	116

See Notes to Financial Statements.

CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(Unaudited)

	Three Months Ended March 31,
	2020			2019
	(millions of dollars)
Net income	$	131		$	116
Other comprehensive income (loss):
Net effects of cash flow hedges (net of tax) (Note 5)		(23	)		(4	)
Defined benefit pension plans (net of tax)		1			1
Total other comprehensive income (loss)		(22	)		(3	)
Comprehensive income	$	109		$	113

See Notes to Financial Statements.

F-2

ONCOR ELECTRIC DELIVERY COMPANY LLC

CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS

(Unaudited)

	Three Months Ended March 31,
	2020			2019
	(millions of dollars)
Cash flows — operating activities:
Net income	$	131		$	116
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization, including regulatory amortization		213			192
Provision in lieu of deferred income taxes—net		13			8
Other – net		—			(2	)
Changes in operating assets and liabilities:
Regulatory accounts related to reconcilable tariffs (Note 2)		(3	)		(20	)
Other operating assets and liabilities		(152	)		(108	)
Cash provided by operating activities		202			186
Cash flows — financing activities:
Issuances of long-term debt (Note 5)		1,250			—
Repayment of long-term debt (Note 5)		(462	)		—
Net change in short-term borrowings (Note 4)		(46	)		328
Capital contributions from members (Note 7)		87			70
Distributions to members (Note 7)		(91	)		(71	)
Debt discount and financing costs – net		(34	)		—
Cash provided by financing activities		704			327
Cash flows — investing activities:
Capital expenditures		(628	)		(523	)
Other – net		8			12
Cash used in investing activities		(620	)		(511	)
Net change in cash and cash equivalents		286			2
Cash and cash equivalents — beginning balance		4			3
Cash and cash equivalents — ending balance	$	290		$	5

See Notes to Financial Statements.

F-3

ONCOR ELECTRIC DELIVERY COMPANY LLC

CONDENSED CONSOLIDATED BALANCE SHEETS

(Unaudited)

	At March 31, 2020			At December 31, 2019
	(millions of dollars)
ASSETS
Current assets:
Cash and cash equivalents	$	290		$	4
Trade accounts receivable – net (Note 10)		656			661
Amounts receivable from members related to income taxes (Note 9)		—			3
Materials and supplies inventories — at average cost		159			148
Prepayments and other current assets		106			96
Total current assets		1,211			912
Investments and other property (Note 10)		126			133
Property, plant and equipment – net (Note 10)		19,816			19,370
Goodwill (Notes 1 and 11)		4,740			4,740
Regulatory assets (Note 2)		1,720			1,775
Operating lease ROU and other assets (Note 6)		141			106
Total assets	$	27,754		$	27,036
LIABILITIES AND MEMBERSHIP INTERESTS
Current liabilities:
Short-term borrowings (Note 4)	$	—		$	46
Long-term debt due currently (Note 5)		148			608
Trade accounts payable		393			394
Amounts payable to members related to income taxes (Note 9)		32			22
Accrued taxes other than amounts related to income taxes		92			236
Accrued interest		94			83
Operating lease and other current liabilities (Note 6)		205			237
Total current liabilities		964			1,626
Long-term debt, less amounts due currently (Note 5)		9,256			8,017
Liability in lieu of deferred income taxes (Note 9)		1,846			1,821
Regulatory liabilities (Note 2)		2,786			2,793
Employee benefit, operating lease and other obligations (Notes 6, 8 and 10)		1,998			1,980
Total liabilities		16,850			16,237
Commitments and contingencies (Note 6)
Membership interests (Note 7):
Capital account — number of units outstanding 2020 and 2019 – 635,000,000		11,065			10,938
Accumulated other comprehensive loss		(161	)		(139	)
Total membership interests		10,904			10,799
Total liabilities and membership interests	$	27,754		$	27,036

See Notes to Financial Statements.

F-4

ONCOR ELECTRIC DELIVERY COMPANY LLC

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

1. BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES

Description of Business

References in this report to “we,” “our,” “us” and “the company” are to Oncor and/or its subsidiaries 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, western and panhandle regions of Texas. We are a direct, majority-owned subsidiary of Oncor Holdings, which is indirectly and wholly owned by Sempra. Oncor Holdings owns 80.25% of our outstanding membership interests and Texas Transmission owns 19.75% of our outstanding membership interests. We are managed as an integrated business; consequently, there is only one reportable segment.

Our condensed consolidated financial statements for the three months ended March 31, 2020, include the results of our wholly owned indirect subsidiary, NTU, which is a regulated utility that provides electricity transmission delivery service in the north-central, western and panhandle regions of Texas. We acquired NTU as part of the InfraREIT Acquisition that closed on May 16, 2019.

Ring-Fencing Measures

Since 2007, various ring-fencing measures have been taken to enhance our credit quality and the separateness between the Oncor Ring-Fenced Entities and entities with ownership interests in Oncor or Oncor Holdings. These ring-fencing measures serve to mitigate the Oncor Ring-Fenced Entities’ credit exposure to owners of Oncor and Oncor Holdings, and to reduce the risk that the assets and liabilities of Oncor Ring-Fenced Entities would be substantively consolidated with the assets and liabilities of any direct or indirect owners of Oncor and Oncor Holdings in connection with a bankruptcy of any such entities. These measures include the November 2008 sale of 19.75% of Oncor’s equity interests to Texas Transmission.

In March 2018, Sempra indirectly acquired Oncor Holdings through the Sempra Acquisition. The Sempra Acquisition was consummated after obtaining the approval of the bankruptcy court in the EFH Bankruptcy Proceedings and the PUCT. The PUCT approval was obtained in Docket No. 47675, and the final order issued in that docket (Sempra Order) outlines certain ring-fencing measures, governance mechanisms and restrictions that apply after the Sempra Acquisition. As a result of these ring-fencing measures, Sempra does not control Oncor, and the ring-fencing measures limit Sempra’s ability to direct the management, policies and operations of Oncor, including the deployment or disposition of Oncor’s assets, declarations of dividends, strategic planning and other important corporate issues and actions.

None of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or obligations of any Sempra entity or any other direct or indirect owner of Oncor or Oncor Holdings. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of any Sempra entities and any other direct or indirect owner of Oncor or Oncor Holdings. We do not bear any liability for debt or contractual obligations of Sempra and its affiliates or any other direct or indirect owner of Oncor or Oncor Holdings, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from Sempra and its affiliates and any other direct or indirect owner of Oncor or Oncor Holdings.

F-5

Oncor is a limited liability company governed by a board of directors, not its members. The Sempra Order and our Limited Liability Company Agreement require that the board of directors of Oncor consist of thirteen members, constituted as follows:

• seven Disinterested Directors, who (i) shall be independent directors in all material respects under the rules of the New York Stock Exchange in relation to Sempra or its subsidiaries and affiliated entities and any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, and (ii) shall have no material relationship with Sempra or its subsidiaries or affiliated entities or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, currently or within the previous ten years;

• two members designated by Sempra (through Oncor Holdings);

• two members designated by Texas Transmission; and

• two current or former officers of Oncor (the Oncor Officer Directors), currently Robert S. Shapard and E. Allen Nye, Jr., who are our Chairman of the Board and Chief Executive, respectively.

In order for a current or former officer of Oncor to be eligible to serve as an Oncor Officer Director, the officer cannot have worked for Sempra or any of its affiliates (excluding Oncor Holdings and Oncor) or any other entity with a direct or indirect ownership interest in Oncor or Oncor Holdings in the ten-year period prior to the officer being employed by Oncor. Oncor Holdings, at the direction of STIH, has the right to nominate and/or seek the removal of the Oncor Officer Directors, subject to approval by a majority of the Oncor board of directors. STIH is a wholly owned indirect subsidiary of, and controlled by, Sempra following the Sempra Acquisition.

In addition, the Sempra Order provides that Oncor’s board cannot be overruled by the board of Sempra or any of its subsidiaries on dividend policy, the issuance of dividends or other distributions (except for contractual tax payments), debt issuance, capital expenditures, operation and maintenance expenditures, management and service fees, and appointment or removal of board members, provided that certain actions may also require the additional approval of the Oncor Holdings board of directors. The Sempra Order also provides that any changes to the size, composition, structure or rights of the board must first be approved by the PUCT. In addition, if Sempra acquires Texas Transmission’s interest in Oncor, the two board positions on Oncor’s board of directors that Texas Transmission is entitled to appoint will be eliminated and the size of Oncor’s board of directors will be reduced by two.

Additional regulatory commitments, governance mechanisms and restrictions provided in the Sempra Order and our Limited Liability Company Agreement to ring-fence Oncor from its owners include, among others:

• A majority of the Disinterested Directors of Oncor must approve any annual or multi-year budget if the aggregate amount of capital expenditures or operating and maintenance expenditures in such budget is more than a 10% increase or decrease from the corresponding amounts of such expenditures in the budget for the preceding fiscal year or multi-year period, as applicable;

• Oncor may not pay any dividends or make any other distributions (except for contractual tax payments) if a majority of its Disinterested Directors determines that it is in the best interests of Oncor to retain such amounts to meet expected future requirements;

• At all times, Oncor will remain in compliance with the debt-to-equity ratio established by the PUCT from time to time for ratemaking purposes, and Oncor will not pay dividends or other distributions (except for contractual tax payments), if that payment would cause its debt-to-equity ratio to exceed the debt-to-equity ratio approved by the PUCT;

• If the credit rating on Oncor’s senior secured debt by any of the three major rating agencies falls below BBB (or the equivalent), Oncor will suspend dividends and other distributions (except for contractual tax payments), unless otherwise allowed by the PUCT;

• Without the prior approval of the PUCT, neither Sempra nor any of its affiliates (excluding Oncor) will incur, guaranty or pledge assets in respect of any indebtedness that is dependent on the revenues of Oncor in more than a proportionate degree than the other revenues of Sempra or on the stock of Oncor, and there will be no debt at STH or STIH at any time following the closing of the Sempra Acquisition;

F-6

• Neither Oncor nor Oncor Holdings will lend money to or borrow money from Sempra or any of its affiliates (other than Oncor subsidiaries), or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, and neither Oncor nor Oncor Holdings will share credit facilities with Sempra or any of its affiliates (other than Oncor subsidiaries), or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings;

• There must be maintained certain “separateness measures” that reinforce the financial separation of Oncor from its owners, including a requirement that dealings between Oncor, Oncor Holdings and their subsidiaries with Sempra, any of Sempra’s other affiliates or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, must be on an arm’s-length basis, limitations on affiliate transactions, separate recordkeeping requirements and a prohibition on Sempra or its affiliates pledging Oncor assets or stock for any entity other than Oncor; and

• Sempra will continue to hold indirectly at least 51% of the ownership interests in Oncor and Oncor Holdings for at least five years following the closing of the Sempra Acquisition, unless otherwise specifically authorized by the PUCT.

Basis of Presentation

These unaudited condensed consolidated financial statements should be read in conjunction with the audited financial statements and related notes included in our 2019 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. We have evaluated all subsequent events through the date the financial statements were issued. All appropriate 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 (see Note 13 to Financial Statements in our 2019 Form 10-K for additional information regarding quarterly results of operations).

Our consolidated financial statements have been prepared in accordance with GAAP governing rate-regulated operations. 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. No material adjustments were made to previous estimates or assumptions during the current period.

Interest Rate Derivatives and Hedge Accounting

We are exposed to interest rates primarily as a result of our current and expected use of financing. We may, from time to time, utilize interest rate derivative instruments typically designated as cash flow hedges, to lock in interest rates in anticipation of future financings. We may designate an interest rate derivative instrument as a cash flow hedge if it effectively converts anticipated cash flows associated with interest payments to a fixed dollar amount. In accounting for cash flow hedges, derivative assets and liabilities are recorded on the balance sheet at fair value with an offset to other comprehensive income. Amounts remain in accumulated other comprehensive income and are reclassified into net income as the interest expense on the related debt affects net income. See Note 5 for details on our interest rate hedging activity.

Impairment of Long-Lived Assets and Goodwill

We evaluate long-lived assets (including intangible assets with finite lives) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable.

F-7

We also evaluate goodwill for impairment annually on October 1 and whenever events or changes in circumstances indicate that an impairment may exist. The determination of the existence of these and other indications of impairment involves judgments that are subjective in nature and may require the use of estimates in forecasting future results and cash flows.

Changes in Accounting Standards

Topic 326, “Financial Instruments—Credit Losses” – In June 2016 the FASB issued ASU No. 2016-13, which changes how entities account for credit losses on receivables and certain other financial assets. The guidance requires use of a current expected credit loss model, which may result in earlier recognition of credit losses than under previous accounting standards. We adopted the new standard effective January 1, 2020. The adoption of the new standard did not have a material impact on our consolidated financial statements.

Topic 848, “Facilitation of the Effects of Reference Rate Reform on Financial Reporting” – In March 2020 the FASB issued ASU No. 2020-04, which provides optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other transactions that reference LIBOR or another reference rate expected to be discontinued because of reference rate reform. ASU No. 2020-04 is effective for all entities as of March 12, 2020 through December 31, 2022. The standard allows entities to account for contract modifications as an event that does not require reassessment or remeasurement (i.e., as a continuation of the existing contract). We are currently evaluating the optional expedients and exceptions under the standard.

F-8

2. REGULATORY MATTERS

Regulatory Assets and Liabilities

Recognition of regulatory assets and liabilities and the periods over which they are to be recovered or refunded through rate regulation reflect the decisions of the PUCT. Components of our regulatory assets and liabilities and their remaining recovery periods as of March 31, 2020 are provided in the table below. Amounts not currently earning a return through rate regulation are noted.

	Remaining Rate Recovery/ Amortization Period At March 31, 2020		At March 31, 2020			At December 31, 2019
Regulatory assets:
Employee retirement liability (a)(b)(c)		To be determined	$	615		$	623
Employee retirement costs being amortized		8 years		253			262
Employee retirement costs incurred since the last rate review period (b)		To be determined		76			79
Self-insurance reserve (primarily storm recovery costs) being amortized		8 years		298			309
Self-insurance reserve incurred since the last rate review period (primarily storm related) (b)		To be determined		221			238
Securities reacquisition costs		Lives of related debt		27			29
Deferred conventional meter and metering facilities depreciation		1 year		10			15
Under-recovered AMS costs		8 years		165			170
Energy efficiency performance bonus (a)		1 year or less		7			9
Wholesale distribution substation service		To be determined		39			34
Other regulatory assets (d)		Various		9			7
								��
Total regulatory assets				1,720			1,775
Regulatory liabilities:
Estimated net removal costs		Lives of related assets		1,199			1,178
Excess deferred taxes		Primarily over lives of related assets		1,557			1,574
Over-recovered wholesale transmission service expense (a)		1 year or less		14			30
Other regulatory liabilities		Various		16			11
Total regulatory liabilities				2,786			2,793
Net regulatory assets (liabilities)			$	(1,066	)	$	(1,018	)

(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 accordance with pension and OPEB accounting standards.

(d) Includes $1 million in regulatory assets established to track our incremental costs related to the impact of COVID-19, including costs relating to our pandemic response plan.

F-9

PUCT Project No. 50664 Issues Related to the State of Disaster for the Coronavirus Disease 2019

On March 26, 2020, the PUCT issued an order in PUCT Project No. 50664 Issues Related to the State of Disaster for the Coronavirus Disease 2019 creating the COVID-19 Electricity Relief Program (COVID-19 ERP) to aid certain eligible residential customers unable to pay their electricity bills as a result of COVID-19 impacts. To fund that program, the PUCT order also provided for an initial $0.33 per MWh surcharge to be collected by transmission and distribution utilities through rates and directed ERCOT to provide an aggregate amount of $15 million in loans to those transmission and distribution utilities for the initial funding of the COVID-19 ERP. As a result, we filed a tariff rider on April 1, 2020 implementing the surcharge. The PUCT order provides that we may request an increase of the surcharge amount if the collections appear insufficient to cover eligible costs of the COVID-19 ERP. Surcharge collections will be recorded as a regulatory liability until the funds are used. Surcharge collections may only be used to reimburse transmission and distribution utilities and REPs for eligible unpaid bills from residential customers enrolled in the COVID-19 ERP, to cover costs of a third-party administrator to administer the eligibility process, and to reimburse ERCOT for the initial funding of the program. Pursuant to an order issued April 17, 2020, the COVID-19 ERP will expire July 17, 2020 unless extended by the PUCT.

Pursuant to the PUCT order, we received an unsecured loan from ERCOT on April 9, 2020 in the amount of $7 million. Under the terms of the loan agreement, we must repay the amount of the loan prior to September 26, 2020, (the original expiration date of the COVID-19 ERP pursuant to the March 26, 2020 PUCT order) or such repayment date as may be set forth in a PUCT order.

The PUCT also authorized the transmission and distribution utilities to use a regulatory asset accounting mechanism and a subsequent process to seek future recovery of expenses resulting from the effects of COVID-19. Therefore, we are recording incremental costs incurred by Oncor resulting from the effects of COVID-19, including costs relating to the implementation of our pandemic response plan, as a regulatory asset.

3. REVENUES

General

Our revenue is billed monthly under tariffs approved by the PUCT and the majority of revenues are related to providing electric delivery service to consumers. Tariff rates are designed to recover the cost of providing electric delivery service to customers including a reasonable rate of return on invested capital. As the volumes delivered can be directly measured, our revenues are recognized when the underlying service has been provided in an amount prescribed by the related tariff. We recognize revenue in the amount that we have the right to invoice. Substantially all of our revenues are from contracts with customers except for alternative revenue program revenues discussed below.

Reconcilable Tariffs

The PUCT has designated certain tariffs (primarily TCRF and EECRF) 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.

Alternative Revenue Program

The PUCT has implemented an incentive program allowing us to earn performance bonuses by exceeding PUCT-approved energy efficiency program targets. This incentive program and the related performance bonus revenues are considered an “alternative revenue program” under GAAP. Annual performance bonuses are recognized as revenue when approved by the PUCT, typically in the third or fourth quarter each year.

F-10

Disaggregation of Revenues

The following table reflects electric delivery revenues disaggregated by tariff for the three months ended March 31, 2020 and 2019:

	Three Months Ended March 31,
	2020		2019
Operating revenues
Revenues contributing to earnings:
Distribution base revenues	$	496	$	499
Transmission base revenues (TCOS revenues):
Billed to third-party wholesale customers		196		143
Billed to REPs serving Oncor distribution customers, through TCRF		109		85
Total transmission base revenues		305		228
Other miscellaneous revenues		16		17
Total revenues contributing to earnings		817		744
Revenues collected for pass-through expenses:
TCRF — third-party wholesale transmission service		245		260
EECRF and other regulatory charges		10		12
Revenues collected for pass-through expenses		255		272
Total operating revenues	$	1,072	$	1,016

Customers

Our distribution customers consist of approximately 90 REPs and certain electric cooperatives in our certificated service area. The consumers of the electricity we deliver are free to choose their electricity supplier from REPs who compete for their business. Our transmission base revenues are collected from load serving entities benefiting from our transmission system. Our transmission customers consist of municipalities, electric cooperatives and other distribution companies. REP subsidiaries of our two largest counterparties represented 25% and 18% of our total operating revenues for the three months ended March 31, 2020. No other customer represented more than 10% of our total operating revenues.

Variability

Our revenues and cash flows are subject to seasonality, timing of customer billings, weather conditions and other electricity usage drivers, with revenues being highest in the summer. Payment is due 35 days after invoicing. Under a PUCT rule relating to the Certification of Retail Electric Providers, write-offs of uncollectible amounts owed by REPs are recoverable as a regulatory asset.

Pass-through Expenses

Expenses which are allowed to be passed-through to customers (primarily, third party wholesale transmission service and energy efficiency program costs) are generally recognized as revenue at the time the costs are incurred. Franchise taxes are assessed by local governmental bodies, based on kWh delivered and are not a “pass-through” item. The rates we charge customers are intended to recover the franchise taxes, but we are not acting as an agent to collect the taxes from customers; therefore, franchise taxes are reported as a principal component of “taxes other than amounts related to income taxes” instead of a reduction to “revenues” in the income statement.

F-11

4. SHORT-TERM BORROWINGS

At March 31, 2020 and December 31, 2019, outstanding short-term borrowings under our CP Program and Credit Facility consisted of the following:

	At March 31, 2020			At December 31, 2019
Total credit facility borrowing capacity	$	2,000		$	2,000
Commercial paper outstanding (a)		—			(46	)
Credit facility outstanding (b)		—			—
Letters of credit outstanding (c)		(9	)		(10	)
Available unused credit	$	1,991		$	1,944

a) The weighted average interest rate for commercial paper was 1.84% at December 31, 2019.

b) At March 31, 2020, the applicable interest rate for any outstanding borrowings was LIBOR plus 1.00%.

c) The interest rate on outstanding letters of credit at both March 31, 2020 and December 31, 2019 was 1.20% based on our credit ratings.

CP Program

In March 2018, we established the CP Program, under which we may issue CP Notes on a private placement basis up to a maximum aggregate face or principal amount outstanding at any time of $2.0 billion. The proceeds of CP Notes issued under the CP Program are used for working capital and general corporate purposes. The CP Program obtains liquidity support from our Credit Facility, which is discussed below. We may utilize either the CP Program or the Credit Facility, at our option, to meet our funding needs.

Credit Facility

In November 2017, we entered into a $2.0 billion unsecured Credit Facility to be used for working capital and general corporate purposes, issuances of letters of credit and support our CP Program. We may request increases in our borrowing capacity in increments of not less than $100 million, not to exceed $400 million in the aggregate provided certain conditions are met, including lender approvals. The Credit Facility’s five-year term expires in November 2022 and gives us the option of requesting up to two one-year extensions, with such extensions subject to certain conditions and lender approvals.

March 2020 Term Loan Agreement

On March 23, 2020, we entered into a short-term unsecured term loan credit agreement (March 2020 Term Loan Agreement) in an aggregate principal amount of $350 million, which may be increased, at our option and upon the agreement of one or more existing or additional lenders, by an aggregate principal amount of between $50 million and $100 million prior to our first borrowing under the March 2020 Term Loan Agreement. The March 2020 Term Loan Agreement has a maturity date of March 22, 2021, which may be extended once, in whole or part, at our option and upon the payment to the extending lenders of an extension fee to be agreed upon by such extending lenders, to a date not later than September 24, 2021. We may borrow up to $350 million in up to four borrowings which may be made, at our option, at any time between April 1, 2020 and July 21, 2020. Upon the earlier to occur of the fourth borrowing and July 21, 2020, the unused commitments of the lenders to make term loans shall terminate. Loans under the March 2020 Term Loan Agreement bear interest at per annum rates equal to, at our option, (i) LIBOR plus 0.675%, or (ii) an alternate base rate (the highest of (1) the prime rate of Wells Fargo Bank, National Association, the administrative agent and a lender under the agreement, (2) the federal funds effective rate plus 0.50%, and (3) daily one-month LIBOR plus 1%). No amounts were outstanding under the March 2020 Term Loan Agreement as of March 31, 2020.

F-12

5. LONG-TERM DEBT

Our senior notes are secured by a 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. At March 31, 2020 and December 31, 2019, our long-term debt consisted of the following:

	March 31, 2020			December 31, 2019
Fixed Rate Secured:
5.75% Senior Notes due September 30, 2020	$	126		$	126
8.50% Senior Notes, Series C, due December 30, 2020		13			14
4.10% Senior Notes, due June 1, 2022		400			400
7.00% Debentures due September 1, 2022		482			482
2.75% Senior Notes due June 1, 2024		500			500
2.95% Senior Notes due April 1, 2025		350			350
3.86% Senior Notes, Series A, due December 3, 2025		174			174
3.86% Senior Notes, Series B, due January 14, 2026		38			38
3.70% Senior Notes due November 15, 2028		650			650
5.75% Senior Notes due March 15, 2029		318			318
7.25% Senior Notes, Series B, due December 30, 2029		36			36
2.75% Senior Notes due May 15, 2030		400			—
6.47% Senior Notes, Series A, due September 30, 2030		82			83
7.00% Senior Notes due May 1, 2032		500			500
7.25% Senior Notes due January 15, 2033		350			350
7.50% Senior Notes due September 1, 2038		300			300
5.25% Senior Notes due September 30, 2040		475			475
4.55% Senior Notes due December 1, 2041		400			400
5.30% Senior Notes due June 1, 2042		500			500
3.75% Senior Notes due April 1, 2045		550			550
3.80% Senior Notes due September 30, 2047		325			325
4.10% Senior Notes due November 15, 2048		450			450
3.80% Senior Notes, due June 1, 2049		500			500
3.10% Senior Notes, due September 15, 2049		700			700
3.70% Senior Notes due May 15, 2050		400			—
Secured long-term debt		9,019			8,221
Unsecured:
Term loan credit agreement maturing October 6, 2020		—			460
Term loan credit agreement maturing June 1, 2021		450			—
Total long-term debt		9,469			8,681
Unamortized discount and debt issuance costs		(65	)		(56	)
Less amount due currently		(148	)		(608	)
Long-term debt, less amounts due currently	$	9,256		$	8,017

F-13

Long-Term Debt-Related Activity in 2020

Debt Issuances

On March 20, 2020, we completed a sale of $400 million aggregate principal amount of 2.75% Senior Secured Notes due 2030 (2030 Notes) and $400 million aggregate principal amount of 3.70% Senior Secured Notes due 2050 (2050 Notes and, together with the 2030 Notes, the Notes). We used the proceeds (net of the initial purchasers’ discount, fees and expenses) of approximately $790 million from the sale of the Notes for general corporate purposes, including the repayment of short-term and long-term debt.

The Notes were issued pursuant to the provisions of an Indenture, dated as of August 1, 2002, between Oncor and The Bank of New York Mellon Trust Company, N.A. (as successor to The Bank of New York Mellon, formerly The Bank of New York) (as amended and supplemented, the Indenture). The 2030 Notes and the 2050 Notes each constitute a separate series of notes under the Indenture, but will be treated together with Oncor’s other outstanding debt securities issued under the Indenture for amendments and waivers and for taking certain other actions.

The Notes were issued in separate private placements and were not registered under the Securities Act. We have agreed, subject to certain exceptions, to register with the SEC notes having substantially identical terms as the Notes (except for provisions relating to the transfer restriction and payment of additional interest) as part of our offers to exchange freely tradable exchange notes for the Notes. We have agreed to use commercially reasonable efforts to cause the exchange offers to be completed within 315 days after the applicable issue date of the Notes. If a registration statement for the exchange offers is not declared effective by the SEC within 270 days after the applicable issue date of the Notes or the exchange offers are not completed within 315 days after the applicable issue date of the Notes (an exchange default), then the annual interest rate on each series of the Notes will increase 50 basis points per annum until the earlier of the expiration of the exchange default or the second anniversary of the issue dates of the Notes.

January 2020 Term Loan Credit Agreement

On January 28, 2020, we executed a $450 million term loan credit agreement that matures on June 1, 2021 (January 2020 Term Loan Agreement). The January 2020 Term Loan Agreement provides that we can borrow the full amount in up to four borrowings by April 27, 2020. We borrowed $163 million on January 29, 2020, $55 million on February 28, 2020 and $232 million on March 17, 2020 under the January 2020 Term Loan Agreement. At March 31, 2020, borrowings under the January 2020 Term Loan Agreement totaled $450 million, the full amount available under the agreement.

The proceeds from each borrowing were used for general corporate purposes, including the repayment of notes outstanding under our CP Program. Loans under the January 2020 Term Loan Agreement bear interest at per annum rates equal to, at our option, (i) LIBOR plus 0.50% until June 1, 2021, or (ii) an alternate base rate (the highest of (1) the prime rate of Sumitomo Mitsui Banking Corporation, the administrative agent and a lender under the agreement, (2) the federal funds effective rate plus 0.50%, and (3) daily one-month LIBOR plus 1%).

Interest Rate Hedge Transactions

In February and March of 2020, we entered into interest rate hedge transactions hedging the variability of benchmark bond rates used to determine interest rates on anticipated issuances of ten-year and thirty-year senior secured notes. The hedges were terminated in March 2020 upon our issuance of the senior secured notes discussed in “Debt Issuances” above. We recognized a $29 million ($23 million after-tax) loss related to the fair value of the hedge transactions in accumulated other comprehensive loss. We expect approximately $4 million of the amount reported in accumulated other comprehensive loss at March 31, 2020 related to interest rate hedges to be reclassified into net income as an increase to interest expense within the next 12 months, including $2 million from the current period transactions.

F-14

Debt Repayments

Repayments of long-term debt in the three months ended March 31, 2020 included $460 million principal amount borrowed under a term loan agreement entered into in 2019 that was to mature in October 2020 (2019 Term Loan Agreement) and $2 million principal amount of the quarterly amortizing debt for senior secured notes issued under one of our Note Purchase Agreements. The $460 million repaid under the 2019 Term Loan Agreement constituted all amounts outstanding under that agreement, and as a result of that repayment the agreement is no longer in effect.

Deed of Trust

Our secured indebtedness 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 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 March 31, 2020, the amount of available bond credits was $1.973 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 $2.602 billion.

Borrowings under the CP Program, the Credit Facility, and our term loan credit agreements are not secured.

Maturities

Long-term maturities (including current maturities) at March 31, 2020, are as follows:

Year	Amount
2020 (excluding first three months of 2020)	$	148
2021		459
2022		891
2023		10
2024		510
Thereafter		7,451
Unamortized discount and debt issuance costs		(65	)
Total	$	9,404

Fair Value of Long-Term Debt

At March 31, 2020 and December 31, 2019, the estimated fair value of our long-term debt (including current maturities) totaled $10.734 billion and $10.003 billion, respectively, and the carrying amount totaled $9.404 billion and $8.625 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.

6. COMMITMENTS AND CONTINGENCIES

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 2 above and Note 8 to Financial Statements in our 2019 Form 10-K for additional information regarding our regulatory and legal proceedings, respectively.

F-15

Leases

As lessee, our leased assets primarily consist of our vehicle fleet and real estate leased for company offices and service centers. Our leases are accounted for as operating leases for both GAAP and rate-making purposes. We generally recognize operating lease costs on a straight-line basis over the lease term in operating expenses. We are not a lessor to any material lease contracts.

In December 2019, we entered into a 15 year lease agreement for replacement office space. The operating lease partially commenced in February 2020 and increased our lease obligation by $24 million.

The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities:

Year	Amount
2020 (remaining nine months)	$	23
2021		28
2022		24
2023		18
2024		12
Thereafter		28
Total undiscounted lease payments		133
Less imputed interest		(12	)
Total future minimum lease payments	$	121

See Note 8 to Financial Statements in our 2019 Form 10-K for additional information on leases.

7. MEMBERSHIP INTERESTS

Cash Contributions

We received cash capital contributions from our members on February 18, 2020 and April 27, 2020 each totaling $87 million.

Cash Distributions

The PUCT order issued in the Sempra Acquisition and our Limited Liability Company Agreement set forth various restrictions on distributions to our members. Among those restrictions is the commitment that we will make no distributions that would cause us to be out of compliance with the PUCT’s approved debt-to-equity ratio, which is currently 57.5% debt to 42.5% equity. The distribution restrictions also include the ability of our board, a majority of the Disinterested Directors, or either of the two member directors designated by Texas Transmission to limit distributions to the extent each determines it is necessary to meet expected future requirements of Oncor (including continuing compliance with the PUCT debt-to-equity ratio commitment). At March 31, 2020, we had $301 million available to distribute to our members as our regulatory capitalization ratio was 56.5% debt to 43.5% 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 including any finance leases 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 accumulated other comprehensive loss and the effects of acquisition accounting from a 2007 transaction.

On February 19, 2020, our board of directors declared a cash distribution of $91 million, which was paid to our members on February 20, 2020. On April 29, 2020, our board of directors declared a cash distribution of $91 million, which was paid to our members on April 30, 2020.

F-16

Membership Interests

The following tables present the changes to membership interests during the three months ended March 31, 2020 and 2019, net of tax:

	Capital Accounts			Accumulated Other Comprehensive Income (Loss)			Total Membership Interests
	Three Months Ended March 31, 2020
Balance at December 31, 2019	$	10,938		$	(139	)	$	10,799
Net income		131			—			131
Distributions		(91	)		—			(91	)
Capital contributions		87			—			87
Net effects of cash flow hedges (Note 5)		—			(23	)		(23	)
Defined benefit pension plans		—			1			1
Balance at March 31, 2020	$	11,065		$	(161	)	$	10,904

	Capital Accounts			Accumulated Other Comprehensive Income (Loss)			Total Membership Interests
	Three Months Ended March 31, 2019
Balance at December 31, 2018	$	8,624		$	(164	)	$	8,460
Net income		116			—			116
Distributions		(71	)		—			(71	)
Capital contributions		70			—			70
Net effects of cash flow hedges		4			(4	)		—
Defined benefit pension plans		—			1			1
Balance at March 31, 2019	$	8,743		$	(167	)	$	8,576

Accumulated Other Comprehensive Income (Loss) (AOCI)

The following table presents the changes to AOCI for the three months ended March 31, 2020 and 2019, net of tax:

	Cash Flow Hedges – Interest Rate Swaps			Defined Benefit Pension and OPEB Plans			Accumulated Other Comprehensive Income (Loss)
Balance at December 31, 2019	$	(18	)	$	(121	)	$	(139	)
Defined benefit pension plans		—			1			1
Cash flow hedges — net decrease in fair value of derivatives (net of tax benefit of $6) (Note 5)		(23	)		—			(23	)
Balance at March 31, 2020	$	(41	)	$	(120	)	$	(161	)
Balance at December 31, 2018	$	(16	)	$	(148	)	$	(164	)
Defined benefit pension plans		—			1			1
Amounts reclassified from accumulated other comprehensive income (loss) to capital account		(4	)		—			(4	)
Balance at March 31, 2019	$	(20	)	$	(147	)	$	(167	)

F-17

8. PENSION AND OPEB PLANS

Pension Plans

We sponsor the Oncor Retirement Plan and also have liabilities under the Vistra 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 Retirement Plan for certain employees whose retirement benefits cannot be fully earned under the qualified retirement plans. See Note 10 to Financial Statements in our 2019 Form 10-K for additional information regarding pension plans.

OPEB Plans

We currently sponsor two OPEB plans. One plan covers our eligible current and future retirees whose services are 100% attributed to the regulated business. Effective January 1, 2018, we established a second plan to cover EFH Corp./Vistra retirees and eligible current and future retirees whose employment services were assigned to both Oncor (or a predecessor regulated utility business) and the non-regulated business of EFH Corp./Vistra. Vistra is solely responsible for its portion of the liability for retiree benefits related to those retirees. See Note 10 to Financial Statements in our 2019 Form 10-K for additional information.

Pension and OPEB Costs

Our net costs related to pension plans and the Oncor OPEB Plans for the three months ended March 31, 2020 and 2019 were comprised of the following:

	Three Months Ended March 31,
	2020			2019
Components of net allocated pension costs:
Service cost	$	8		$	7
Interest cost		25			32
Expected return on assets		(27	)		(30	)
Amortization of net loss		12			7
Net pension costs		18			16
Components of net OPEB costs:
Service cost		1			2
Interest cost		8			11
Expected return on assets		(2	)		(2	)
Amortization of prior service cost		(5	)		(5	)
Amortization of net loss		3			4
Net OPEB costs		5			10
Total net pension and OPEB costs		23			26
Less amounts deferred principally as property or a regulatory asset		(4	)		(7	)
Net amounts recognized as operation and maintenance expense or other deductions	$	19		$	19

The discount rates reflected in net pension and OPEB costs in 2020 are 3.12%, 3.26% and 3.29% for the Oncor Retirement Plan, the Vistra Retirement Plan and the Oncor OPEB Plans, respectively. The expected return on pension and OPEB plan assets reflected in the 2020 cost amounts are 4.94%, 4.89% and 5.90% for the Oncor Retirement Plan, the Vistra Retirement Plan and the Oncor OPEB Plans, respectively.

F-18

Pension and OPEB Plans Cash Contributions

We made cash contributions to the pension plans and Oncor OPEB Plans of $13 million and $10 million, respectively, during the three months ended March 31, 2020. We expect to make additional cash contributions to the pension plans and Oncor OPEB Plans of $164 million and $25 million, respectively, during the remainder of 2020. Our aggregate pension plans and Oncor OPEB Plans funding is expected to total approximately $571 million and $176 million, respectively, in the five-year period 2020 to 2024 based on the latest actuarial projections.

9. RELATED-PARTY TRANSACTIONS

The following represent our significant related-party transactions. As a result of the Sempra-Sharyland Transaction, Sharyland became a related party as of May 16, 2019.

• We are not a member of another entity’s consolidated tax group, but our owners’ federal income tax returns include their portion of our results. Under the terms of a tax sharing agreement among us, Oncor Holdings, Texas Transmission and STH (as successor to EFH Corp.), we are generally obligated to make payments to our owners, 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. STH will file a combined Texas margin tax return that includes our results and our share of 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 2019 Form 10-K under “Provision in Lieu of 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 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 sheets consisted of the following:

	At March 31, 2020						At December 31, 2019
	STH		Texas Transmission		Total		STH			Texas Transmission			Total
Federal income taxes payable (receivable)	$	3	$	1	$	4	$	(2	)	$	(1	)	$	(3	)
Texas margin taxes payable		28		—		28		22			—			22
Net payable (receivable)	$	31	$	1	$	32	$	20		$	(1	)	$	19

There were no cash payments made to (received from) members related to income taxes for the three months ended March 31, 2020 and 2019.

See Note 7 for information regarding distributions to and capital contributions from members.

• Sharyland provided wholesale transmission service to us in the amount of $3 million and we provided Sharyland with substation monitoring and switching services of less than $1 million in the three months ended March 31, 2020.

F-19

10. SUPPLEMENTARY FINANCIAL INFORMATION

Other Deductions and (Income)

	Three Months Ended March 31,
	2020			2019
Professional fees	$	1		$	3
Recoverable pension and OPEB—non-service costs		14			14
AFUDC equity income		(5	)		—
Other, including interest income		3			—
Total other deductions and (income)—net	$	13		$	17

Interest Expense and Related Charges

	Three Months Ended March 31,
	2020			2019
Interest	$	101		$	88
Amortization of debt issuance costs and discounts		3			1
Less allowance for funds used during construction – capitalized interest portion		(3	)		(3	)
Total interest expense and related charges	$	101		$	86

Trade Accounts and Other Receivables

Trade accounts and other receivables reported on our balance sheets consisted of the following:

	At March 31, 2020			At December 31, 2019
Gross trade accounts and other receivables	$	662		$	666
Allowance for uncollectible accounts		(6	)		(5	)
Trade accounts receivable – net	$	656		$	661

At both March 31, 2020 and December 31, 2019, REP subsidiaries of our two largest customers represented 15% and 11% of the trade accounts receivable balance, 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.

F-20

Investments and Other Property

Investments and other property reported on our balance sheets consisted of the following:

	At March 31, 2020		At December 31, 2019
Assets related to employee benefit plans	$	112	$	119
Land		12		12
Other		2		2
Total investments and other property	$	126	$	133

Property, Plant and Equipment

Property, plant and equipment—net reported on our balance sheets consisted of the following.

	Composite Depreciation Rate/ Avg. Life at March 31, 2020		At March 31, 2020		At December 31, 2019
Assets in service:
Distribution		2.8% / 35.9 years	$	14,211	$	14,007
Transmission		2.9% / 35.0 years		11,201		11,094
Other assets		6.9% / 14.6 years		1,653		1,648
Total				27,065		26,749
Less accumulated depreciation				8,102		7,986
Net of accumulated depreciation				18,963		18,763
Construction work in progress				832		585
Held for future use				21		22
Property, plant and equipment – net			$	19,816	$	19,370

Intangible Assets

Intangible assets (other than goodwill) reported on our balance sheets as part of property, plant and equipment consisted of the following:

	At March 31, 2020						At December 31, 2019
	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
Identifiable intangible assets subject to amortization:
Land easements	$	576	$	108	$	468	$	575	$	107	$	468
Capitalized software		937		444		493		933		430		503
Total	$	1,513	$	552	$	961	$	1,508	$	537	$	971

F-21

Aggregate amortization expenses for intangible assets totaled $15 million and $13 million for the three months ended March 31, 2020 and 2019, respectively. The estimated aggregate amortization expense for each of the next five fiscal years is as follows:

Year	Amortization Expense
2020	$	61
2021		61
2022		61
2023		61
2024		60

Employee Benefit, Operating Lease and Other Obligations

Employee benefit, operating lease and other obligations reported on our balance sheets consisted of the following:

	At March 31, 2020		At December 31, 2019
Retirement plans and other employee benefits	$	1,810	$	1,834
Operating lease liabilities		94		66
Investment tax credits		6		6
Other		88		74
Total employee benefit, operating lease and other obligations	$	1,998	$	1,980

Supplemental Cash Flow Information

	Three Months Ended March 31,
	2020			2019
Cash payments (receipts) related to:
Interest	$	90		$	56
Less capitalized interest		(3	)		(3	)
Interest payments (net of amounts capitalized)	$	87		$	53
Noncash increase in operating lease obligations for ROU assets	$	37		$	88
Noncash construction expenditures (a)	$	221		$	168

(a) Represents end-of-period accruals.

F-22

11. INFRAREIT ACQUISITION

On May 16, 2019, we completed the InfraREIT Acquisition, pursuant to which we acquired all of the equity interests of InfraREIT and its subsidiary, InfraREIT Partners. In connection with and immediately following the closing of the InfraREIT Acquisition, on May 16, 2019, we extinguished all outstanding debt of InfraREIT and its subsidiaries through repaying $602 million principal amount of InfraREIT subsidiary debt and exchanging $351 million principal amount of InfraREIT subsidiary debt for new Oncor senior secured debt.

The assets we acquired include approximately 1,575 miles of transmission lines, including 1,235 circuit miles of 345kV transmission lines and approximately 340 circuit miles of 138kV transmission lines. The north, central, and west Texas transmission system acquired by us in the transaction is directly connected to approximately 20 operational generation facilities totaling approximately 3,900 MW and serves over 50 substations.

Business Combination Accounting

We accounted for the InfraREIT Acquisition as a business acquisition with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the closing date. The combined results of operations are reported in our condensed consolidated financial statements beginning as of the closing date.

The following table sets forth the final purchase price paid. In the three months ended March 31, 2020, we made no material purchase price allocation adjustments. The final purchase price allocation was completed as of March 31, 2020.

Purchase of outstanding InfraREIT shares and units	$	1,275
Certain transaction costs of InfraREIT paid by Oncor (a)		49
Total purchase price paid	$	1,324

(a) Represents certain transaction costs incurred by InfraREIT in connection with the transaction and paid by Oncor, including a $40 million management termination fee payable to an affiliate of Hunt Consolidated, Inc.

Unaudited Pro Forma Financial Information

The following unaudited pro forma financial information for the three months ended March 31, 2019 assumes that the InfraREIT Acquisition occurred on January 1, 2018. The unaudited pro forma financial information is provided for information purposes only and is not necessarily indicative of the results of operations that would have occurred had the InfraREIT Acquisition been completed on January 1, 2018, nor is the unaudited pro forma financial information indicative of future results of operations, which may differ materially from the pro forma financial information presented here.

	Three Months Ended March 31, 2019
Oncor Consolidated Pro Forma Revenues	$	1,072

The unaudited pro forma financial information above excludes pro forma earnings due to the impracticability of a calculation. The acquiree previously operated under a real estate investment trust structure with a unique cost structure and unique federal tax attributes. An accurate retrospective application cannot be objectively and reliably calculated as the new cost structure and new tax attributes would require a significant amount of estimates and judgments.

F-23

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Board of Directors and Members of

Oncor Electric Delivery Company LLC

Dallas, Texas

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of Oncor Electric Delivery Company LLC and subsidiaries (the “Company”) as of December 31, 2019 and 2018, the related consolidated statements of income, comprehensive income, cash flows, and membership interests, for each of the three years in the period ended December 31, 2019, and the related notes (collectively referred to as the “financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2019 and 2018, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2019, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2019, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 27, 2020 (not presented herein), expressed an unqualified opinion on the Company’s internal control over financial reporting.

Basis for Opinion

These financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB and in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

/s/ Deloitte & Touche LLP

Dallas, Texas

February 27, 2020

We have served as the Company’s auditor since 2002.

F-24

ONCOR ELECTRIC DELIVERY COMPANY LLC

STATEMENTS OF CONSOLIDATED INCOME

	Year Ended December 31,
	2019			2018			2017
	(millions of dollars)
Operating revenues (Note 4)	$	4,347		$	4,101		$	3,958
Operating expenses:
Wholesale transmission service		1,005			962			929
Operation and maintenance (Note 12)		899			875			731
Depreciation and amortization		723			671			762
Provision in lieu of income taxes (Notes 1, 5 and 12)		138			152			266
Taxes other than amounts related to income taxes		508			496			462
Total operating expenses		3,273			3,156			3,150
Operating income		1,074			945			808
Other deductions and (income)—net (Note 13)		63			84			46
Nonoperating provision (benefit) in lieu of income taxes (Note 5)		(15	)		(35	)		1
Interest expense and related charges (Note 13)		375			351			342
Net income	$	651		$	545		$	419

See Notes to Financial Statements.

ONCOR ELECTRIC DELIVERY COMPANY LLC

STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

	Year Ended December 31,
	2019		2018			2017
	(millions of dollars)
Net income	$	651	$	545		$	419
Other comprehensive income (loss):
Cash flow hedges – derivative value net loss recognized in net income (net of tax expense of $-, $1 and $1) (Note 1)		2		2			2
Defined benefit pension plans (net of tax expense of $-, $45 and $4) (Note 10)		27		(65	)		8
Total other comprehensive income (loss)		29		(63	)		10
Comprehensive income	$	680	$	482		$	429

See Notes to Financial Statements.

F-25

ONCOR ELECTRIC DELIVERY COMPANY LLC

STATEMENTS OF CONSOLIDATED CASH FLOWS

	Year Ended December 31,
	2019			2018			2017
	(millions of dollars)
Cash flows — operating activities:
Net income	$	651		$	545		$	419
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation and amortization, including regulatory amortization		806			777			815
Provision in lieu of deferred income taxes – net		55			18			309
Other – net		(3	)		(3	)		(2	)
Changes in operating assets and liabilities:
Accounts receivable — trade		(53	)		68			(76	)
Inventories		(30	)		(25	)		(1	)
Accounts payable — trade		21			30			(11	)
Regulatory accounts related to reconcilable tariffs (Note 3)		(44	)		66			29
Other — assets		(204	)		33			54
Other — liabilities		76			(27	)		(77	)
Cash provided by operating activities		1,275			1,482			1,459
Cash flows — financing activities:
Issuances of long-term debt (Note 7)		2,460			1,150			600
Repayments of long-term debt (Note 7)		(1,094	)		(825	)		(324	)
Proceeds of business acquisition bridge loan (Note 6)		600			—			—
Repayment of business acquisition bridge loan (Note 6)		(600	)		—			—
Net (decrease) increase in short-term borrowings (Note 6)		(882	)		(137	)		161
Capital contributions from members (Note 9)		1,978			284			—
Distributions to members (Note 9)		(319	)		(209	)		(237	)
Debt discount, premium, financing and reacquisition costs – net		(39	)		(14	)		(10	)
Cash provided by financing activities		2,104			249			190
Cash flows — investing activities:
Capital expenditures (Note 12)		(2,097	)		(1,767	)		(1,631	)
Business acquisition (Note 2)		(1,324	)		—			(25	)
Other – net		43			18			12
Cash used in investing activities		(3,378	)		(1,749	)		(1,644	)
Net change in cash and cash equivalents		1			(18	)		5
Cash and cash equivalents — beginning balance		3			21			16
Cash and cash equivalents — ending balance	$	4		$	3		$	21

See Notes to Financial Statements.

F-26

ONCOR ELECTRIC DELIVERY COMPANY LLC

CONSOLIDATED BALANCE SHEETS

	At December 31,
	2019			2018
	(millions of dollars)
ASSETS
Current assets:
Cash and cash equivalents	$	4		$	3
Trade accounts receivable – net (Note 13)		661			559
Amounts receivable from members related to income taxes (Note 12)		3			—
Materials and supplies inventories — at average cost		148			116
Prepayments and other current assets		96			94
Total current assets		912			772
Investments and other property (Note 13)		133			120
Property, plant and equipment – net (Note 13)		19,370			16,090
Goodwill (Notes 1 and 13)		4,740			4,064
Regulatory assets (Note 3)		1,775			1,691
Operating lease ROU and other assets (Note 1)		106			15
Total assets	$	27,036		$	22,752
LIABILITIES AND MEMBERSHIP INTERESTS
Current liabilities:
Short-term borrowings (Note 6)	$	46		$	813
Long-term debt due currently (Note 7)		608			600
Trade accounts payable (Note 12)		394			300
Amounts payable to members related to income taxes (Note 12)		22			26
Accrued taxes other than amounts related to income		236			199
Accrued interest		83			68
Operating lease and other current liabilities (Note 8)		237			209
Total current liabilities		1,626			2,215
Long-term debt, less amounts due currently (Note 7)		8,017			5,835
Liability in lieu of deferred income taxes (Notes 1, 5 and 12)		1,821			1,602
Regulatory liabilities (Note 3)		2,793			2,697
Employee benefit, operating lease and other obligations (Notes 10 and 13)		1,980			1,943
Total liabilities		16,237			14,292
Commitments and contingencies (Note 8)
Membership interests (Note 9):
Capital account — number of units outstanding 2019 and 2018 – 635,000,000		10,938			8,624
Accumulated other comprehensive loss		(139	)		(164	)
Total membership interests		10,799			8,460
Total liabilities and membership interests	$	27,036		$	22,752

See Notes to Financial Statements.

F-27

ONCOR ELECTRIC DELIVERY COMPANY LLC

STATEMENTS OF CONSOLIDATED MEMBERSHIP INTERESTS

	Year Ended December 31,
	2019			2018			2017
	(millions of dollars)
Capital account:
Balance at beginning of period	$	8,624		$	8,004		$	7,822
Net income		651			545			419
Capital contributions from members (Note 9)		1,978			284			—
Distributions to members (Note 9)		(319	)		(209	)		(237	)
ASU 2018-02 stranded tax effects (Note 1)		4			—			—
Balance at end of period (number of units outstanding: 2019, 2018 and 2017 – 635,000,000)		10,938			8,624			8,004
Accumulated other comprehensive income (loss), net of tax effects (Note 9):
Balance at beginning of period		(164	)		(101	)		(111	)
Net effects of cash flow hedges (net of tax expense of $-, $1 and $1)		2			2			2
Defined benefit pension plans (net of tax expense of $-, $45 and $4) (Note 10)		27			(65	)		8
ASU 2018-02 stranded tax effects (Note 1)		(4	)		—			—
Balance at end of period		(139	)		(164	)		(101	)
Total membership interests at end of period	$	10,799		$	8,460		$	7,903

See Notes to Financial Statements.

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ONCOR ELECTRIC DELIVERY COMPANY LLC

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1. DESCRIPTION OF BUSINESS AND SIGNIFICANT ACCOUNTING POLICIES

Description of Business

References in this report to “we,” “our,” “us” and “the company” are to Oncor and/or its subsidiaries 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, western and panhandle regions of Texas. We are a direct, majority-owned subsidiary of Oncor Holdings, which is indirectly and wholly owned by Sempra. Oncor Holdings owns 80.25% of our membership interests and Texas Transmission owns 19.75% of our membership interests. We are managed as an integrated business; consequently, there are no separate reportable business segments.

Our consolidated financial statements for the fiscal year ended December 31, 2019, include the results of our wholly owned indirect subsidiary, NTU, which is a regulated utility that provides electricity transmission delivery service in the north-central, western and panhandle regions of Texas. We acquired NTU as part of the InfraREIT Acquisition that closed on May 16, 2019.

Ring-Fencing Measures

Since 2007, various ring-fencing measures have been taken to enhance our credit quality and the separateness between the Oncor Ring-Fenced Entities and entities with ownership interests in Oncor or Oncor Holdings. These ring-fencing measures serve to mitigate the Oncor Ring-Fenced Entities’ credit exposure to owners of Oncor and Oncor Holdings, and to reduce the risk that the assets and liabilities of Oncor Ring-Fenced Entities would be substantively consolidated with the assets and liabilities of any direct or indirect owners of Oncor and Oncor Holdings in connection with a bankruptcy of any such entities. These measures include the November 2008 sale of 19.75% of Oncor’s equity interests to Texas Transmission.

In March 2018, Sempra indirectly acquired Oncor Holdings through the Sempra Acquisition. The Sempra Acquisition was consummated after obtaining the approval of the bankruptcy court in the EFH Bankruptcy Proceedings and the PUCT. The PUCT approval was obtained in Docket No. 47675, and the final order issued in that docket (Sempra Order) outlines certain ring-fencing measures, governance mechanisms and restrictions that apply after the Sempra Acquisition. As a result of these ring-fencing measures, Sempra does not control Oncor, and the ring-fencing measures limit Sempra’s ability to direct the management, policies and operations of Oncor, including the deployment or disposition of Oncor’s assets, declarations of dividends, strategic planning and other important corporate issues and actions.

None of the assets of the Oncor Ring-Fenced Entities are available to satisfy the debt or obligations of any Sempra entity or any other direct or indirect owner of Oncor or Oncor Holdings. The assets and liabilities of the Oncor Ring-Fenced Entities are separate and distinct from those of any Sempra entities and any other direct or indirect owner of Oncor or Oncor Holdings. We do not bear any liability for debt or contractual obligations of Sempra and its affiliates or any other direct or indirect owner of Oncor or Oncor Holdings, and vice versa. Accordingly, our operations are conducted, and our cash flows are managed, independently from Sempra and its affiliates and any other direct or indirect owner of Oncor or Oncor Holdings.

Oncor is a limited liability company governed by a board of directors, not its members. The Sempra Order and our Limited Liability Company Agreement require that the board of directors of Oncor consist of thirteen members, constituted as follows:

• seven Disinterested Directors, who (i) shall be independent directors in all material respects under the rules of the New York Stock Exchange in relation to Sempra or its subsidiaries and affiliated entities and any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, and (ii) shall have no material relationship with Sempra or its subsidiaries or affiliated entities or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, currently or within the previous ten years;

• two members designated by Sempra (through Oncor Holdings);

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• two members designated by Texas Transmission; and

• two current or former officers of Oncor (the Oncor Officer Directors), currently Robert S. Shapard and E. Allen Nye, Jr., who are our Chairman of the Board and Chief Executive, respectively.

In order for a current or former officer of Oncor to be eligible to serve as an Oncor Officer Director, the officer cannot have worked for Sempra or any of its affiliates (excluding Oncor Holdings and Oncor) or any other entity with a direct or indirect ownership interest in Oncor or Oncor Holdings in the ten-year period prior to the officer being employed by Oncor. Oncor Holdings, at the direction of STIH, has the right to nominate and/or seek the removal of the Oncor Officer Directors, subject to approval by a majority of the Oncor board of directors. STIH is a wholly owned indirect subsidiary of, and controlled by, Sempra following the Sempra Acquisition.

In addition, the Sempra Order provides that Oncor’s board cannot be overruled by the board of Sempra or any of its subsidiaries on dividend policy, the issuance of dividends or other distributions (except for contractual tax payments), debt issuance, capital expenditures, operation and maintenance expenditures, management and service fees, and appointment or removal of board members, provided that certain actions may also require the additional approval of the Oncor Holdings board of directors. The Sempra Order also provides that any changes to the size, composition, structure or rights of the board must first be approved by the PUCT. In addition, if Sempra acquires Texas Transmission’s interest in Oncor, the two board positions on Oncor’s board of directors that Texas Transmission is entitled to appoint will be eliminated and the size of Oncor’s board of directors will be reduced by two.

Additional regulatory commitments, governance mechanisms and restrictions provided in the Sempra Order and our Limited Liability Company Agreement to ring-fence Oncor from its owners include, among others:

• A majority of the Disinterested Directors of Oncor must approve any annual or multi-year budget if the aggregate amount of capital expenditures or operating and maintenance expenditures in such budget is more than a 10% increase or decrease from the corresponding amounts of such expenditures in the budget for the preceding fiscal year or multi-year period, as applicable;

• Oncor may not pay any dividends or make any other distributions (except for contractual tax payments) if a majority of its Disinterested Directors determines that it is in the best interests of Oncor to retain such amounts to meet expected future requirements;

• At all times, Oncor will remain in compliance with the debt-to-equity ratio established by the PUCT from time to time for ratemaking purposes, and Oncor will not pay dividends or other distributions (except for contractual tax payments), if that payment would cause its debt-to-equity ratio to exceed the debt-to-equity ratio approved by the PUCT;

• If the credit rating on Oncor’s senior secured debt by any of the three major rating agencies falls below BBB (or the equivalent), Oncor will suspend dividends and other distributions (except for contractual tax payments), unless otherwise allowed by the PUCT;

• Without the prior approval of the PUCT, neither Sempra nor any of its affiliates (excluding Oncor) will incur, guaranty or pledge assets in respect of any indebtedness that is dependent on the revenues of Oncor in more than a proportionate degree than the other revenues of Sempra or on the stock of Oncor, and there will be no debt at STH or STIH at any time following the closing of the Sempra Acquisition;

• Neither Oncor nor Oncor Holdings will lend money to or borrow money from Sempra or any of its affiliates (other than Oncor subsidiaries), or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, and neither Oncor nor Oncor Holdings will share credit facilities with Sempra or any of its affiliates (other than Oncor subsidiaries), or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings;

• There must be maintained certain “separateness measures” that reinforce the financial separation of Oncor from its owners, including a requirement that dealings between Oncor, Oncor Holdings and their subsidiaries with Sempra, any of Sempra’s other affiliates or any entity with a direct or indirect ownership interest in Oncor or Oncor Holdings, must be on an arm’s-length basis, limitations on affiliate transactions, separate recordkeeping requirements and a prohibition on Sempra or its affiliates pledging Oncor assets or stock for any entity other than Oncor; and

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• Sempra will continue to hold indirectly at least 51% of the ownership interests in Oncor and Oncor Holdings for at least five years following the closing of the Sempra Acquisition, unless otherwise specifically authorized by the PUCT.

Basis of Presentation

Our consolidated financial statements have been prepared in accordance with GAAP governing rate-regulated operations. 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. No material adjustments were made to previous estimates or assumptions during the current year.

Revenue Recognition

Oncor’s revenue is billed under tariffs approved by the PUCT and the majority of revenues are related to providing electric delivery service to consumers. Tariff rates are designed to recover the cost of providing electric delivery service including a reasonable rate of return on invested capital. Revenues are generally recognized when the underlying service has been provided in an amount prescribed by the related tariff. See Note 4 for additional information regarding revenues.

Goodwill

The increase in goodwill to $4,740 million at December 31, 2019 from $4,064 million at December 31, 2018 is due to the InfraREIT Acquisition. See Note 2 for more information on the InfraREIT Acquisition.

Impairment of Long-Lived Assets and Goodwill

We evaluate long-lived assets (including intangible assets with finite lives) for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. We also evaluate goodwill for impairment annually on October 1 and whenever events or changes in circumstances indicate that an impairment may exist. The determination of the existence of these and other indications of impairment involves judgments that are subjective in nature and may require the use of estimates in forecasting future results and cash flows.

If at the assessment date our carrying value exceeds our estimated fair value (enterprise value), then the estimated enterprise value is compared to the estimated fair values of our operating assets (including identifiable intangible assets) and liabilities at the assessment date. The resultant implied goodwill amount is compared to the recorded goodwill amount. Any excess of the recorded goodwill amount over the implied goodwill amount is written off as an impairment charge.

In each of 2019, 2018 and 2017, we concluded, based on a qualitative assessment, that our estimated enterprise fair value was more likely than not greater than our carrying value. As a result, no additional testing for impairment was required and no impairments were recognized.

Provision in Lieu of Income Taxes

Our tax sharing agreement with Oncor Holdings, Texas Transmission and STH (as successor to EFH Corp.) provides for the calculation of amounts related to income taxes for each of Oncor Holdings and Oncor substantially as if these entities were taxed as corporations and requires payments to the members determined on that basis (without duplication for any income taxes paid by a subsidiary of Oncor Holdings).

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We are a partnership for U.S. federal income tax purposes. Accordingly, while partnerships are not subject to income taxes, in consideration of the presentation of our financial statements as an entity subject to cost-based regulatory rate-setting processes, with such costs historically including income taxes, the financial statements present amounts determined under the tax sharing agreement as “provision in lieu of income taxes” and “liability in lieu of deferred income taxes”. Such amounts are determined in accordance with the provisions of the accounting guidance for income taxes and accounting standards that provide interpretive guidance for accounting for uncertain tax positions and thus differences between the book and tax bases of assets and liabilities are accounted for as if we were a stand-alone corporation. In the 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.

We classify any interest and penalties expense related to uncertain tax positions as current provision in lieu of income taxes as discussed in Note 5.

Defined Benefit Pension Plans and Oncor OPEB Plans

We have liabilities under pension plans that offer benefits based on either a traditional defined benefit formula or a cash balance formula and Oncor OPEB plans that offer certain health care and life insurance benefits to eligible employees and their eligible dependents upon the retirement of such employees. Costs of pension and Oncor OPEB plans are dependent upon numerous factors, assumptions and estimates. See Note 10 for additional information regarding pension and OPEB plans.

System of Accounts

Our accounting records have been maintained in accordance with the FERC Uniform System of Accounts as adopted by the PUCT.

Property, Plant and Equipment

Properties are stated at original cost. The cost of self-constructed property additions includes materials and both direct and indirect labor and applicable overhead and an allowance for funds used during construction.

Depreciation of property, plant and equipment is calculated on a straight-line basis over the estimated service lives of the properties based on depreciation rates approved by the PUCT. As is common in the industry, depreciation expense is recorded using composite depreciation rates that reflect blended estimates of the lives of major asset groups as compared to depreciation expense calculated on a component asset-by-asset basis. Depreciation rates include plant removal costs as a component of depreciation expense, consistent with regulatory treatment. Actual removal costs incurred are charged to accumulated depreciation. Accrued removal costs in excess of incurred removal costs are reclassified as a regulatory liability to retire assets in the future.

Regulatory Assets and Liabilities

We are subject to rate regulation and our financial statements reflect regulatory assets and liabilities in accordance with accounting standards related to the effect of certain types of regulation. Regulatory assets and liabilities represent probable future revenues that will be recovered from or refunded to customers through the ratemaking process based on PURA and/or the PUCT’s orders, precedents or substantive rules. Rate regulation is premised on the full recovery of prudently incurred costs and a reasonable rate of return on invested capital subject to PUCT review for reasonableness and prudence and possible disallowance. Regulatory decisions can have an impact on the recovery of costs, the rate earned on invested capital and the timing and amount of assets to be recovered by rates. See Note 3 for more information regarding regulatory assets and liabilities.

Franchise Taxes

Franchise taxes are assessed to us by local governmental bodies, based on kWh delivered and are a principal component of taxes other than amounts related to income taxes as reported in the income statement. Franchise taxes are not a “pass through” item. The rates we charge customers are intended to recover the franchise taxes, but we are not acting as an agent to collect the taxes from customers.

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Allowance for Funds Used During Construction (AFUDC)

AFUDC is a regulatory cost accounting procedure whereby both interest charges on borrowed funds and a return on equity capital used to finance construction are included in the recorded cost of utility plant and equipment being constructed. AFUDC is capitalized on all projects involving construction periods lasting greater than thirty days. The interest portion of capitalized AFUDC is accounted for as a reduction to interest expense and the equity portion of capitalized AFUDC is accounted for as other income. See Note 13 for detail of amounts reducing interest expense and increasing other income.

Cash and Cash Equivalents

For purposes of reporting cash and cash equivalents, temporary cash investments purchased with an original maturity of three months or less are considered to be cash equivalents.

Fair Value of Nonderivative Financial Instruments

The carrying amounts for financial assets classified as current assets and the carrying amounts for financial liabilities classified as current liabilities approximate fair value due to the short maturity of such instruments. The fair values of other financial instruments, for which carrying amounts and fair values have not been presented, are not materially different than their related carrying amounts. The following discussion of fair value accounting standards applies primarily to our determination of the fair value of assets in the pension and Oncor OPEB plans’ trusts (see Note 10) and long-term debt (see Note 7).

Accounting standards related to the determination of fair value define fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. We use a “mid-market” valuation convention (the mid-point price between bid and ask prices) as a practical expedient to measure fair value for the majority of our assets and liabilities subject to fair value measurement on a recurring basis. We primarily use the market approach for recurring fair value measurements and use valuation techniques to maximize the use of observable inputs and minimize the use of unobservable inputs.

We categorize our assets and liabilities recorded at fair value based upon the following fair value hierarchy:

• Level 1 valuations use quoted prices in active markets for identical assets or liabilities that are accessible at the measurement date. An active market is a market in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis.

• Level 2 valuations use inputs that, in the absence of actively quoted market prices, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include: (a) quoted prices for similar assets or liabilities in active markets, (b) quoted prices for identical or similar assets or liabilities in markets that are not active, (c) inputs other than quoted prices that are observable for the asset or liability such as interest rates and yield curves observable at commonly quoted intervals and (d) inputs that are derived principally from or corroborated by observable market data by correlation or other means. Our Level 2 valuations utilize over-the-counter broker quotes, quoted prices for similar assets or liabilities that are corroborated by correlations or other mathematical means and other valuation inputs.

• Level 3 valuations use unobservable inputs for the asset or liability. Unobservable inputs are used to the extent observable inputs are not available, thereby allowing for situations in which there is little, if any, market activity for the asset or liability at the measurement date. We use the most meaningful information available from the market combined with internally developed valuation methodologies to develop our best estimate of fair value.

We utilize several different valuation techniques to measure the fair value of assets and liabilities, relying primarily on the market approach of using prices and other market information for identical and/or comparable assets and liabilities for those items that are measured on a recurring basis.

The fair value of certain investments is measured using the net asset value (NAV) per share as a practical expedient. Such investments measured at NAV are not required to be categorized within the fair value hierarchy.

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Derivative Instruments and Mark-to-Market Accounting

From time-to-time we enter into derivative instruments to hedge interest rate risk. If the instrument meets the definition of a derivative under accounting standards related to derivative instruments and hedging activities, the fair value of each derivative is recognized on the balance sheet as a derivative asset or liability and changes in the fair value are recognized in net income, unless criteria for cash flow hedge accounting are met. This recognition is referred to as “mark-to-market” accounting.

Changes in Accounting Standards

Topic 842, “Leases” – In February 2016, the FASB issued ASU 2016-02 which created FASB Topic 842, Leases (Topic 842). Topic 842 amends previous GAAP to require the balance sheet recognition of substantially all lease assets and liabilities, including operating leases. Operating lease liabilities are not classified as debt for GAAP purposes under Topic 842 and are not treated as debt for our regulatory purposes. All of Oncor’s existing leases meet the definition of an operating lease. Under the new rules, the recognition of any finance leases (previously known as capital leases) on the balance sheet are classified as debt for both GAAP and regulatory capital structure purposes (see Note 8 for details) similar to the previous capital lease treatment.

We adopted Topic 842 on January 1, 2019, using the optional transition method to apply the new guidance prospectively and not restate comparative periods. We elected the package of practical expedients that permits us to not reassess (a) whether a contract is or contains a lease, (b) lease classification or (c) determination of initial direct costs, which allows us to carry forward accounting conclusions under previous GAAP on contracts that commenced prior to adoption of the lease standard. We also elected the land easement practical expedient, which allows us to continue to account for pre-existing land easements under our accounting policy that existed before adoption of the lease standard. We did not elect the practical expedient to use hindsight in making judgments when determining the lease term.

The adoption of Topic 842 affects our balance sheet, as our contracts for office space, service centers and fleet vehicles are operating leases. The following table shows the increases on our balance sheet at January 1, 2019 from the initial adoption of Topic 842.

	At January 1, 2019
Operating Leases:
ROU assets:
Operating lease ROU and other assets	$	82
Lease liabilities:
Operating lease and other current liabilities	$	26
Employee benefit, operating lease and other obligations		56
Total operating lease liabilities	$	82

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Topic 220, “Income Statement—Reporting Comprehensive Income” amended by ASU 2018-02, “Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income” – In February 2018, the FASB issued ASU 2018-02, an amendment to Topic 220. Under ASU 2018-02, an entity is required to provide certain disclosures regarding stranded tax effects, including its accounting policy related to releasing the income tax effects from accumulated other comprehensive income (AOCI). We elected to reclassify stranded tax effects resulting from the TCJA from AOCI to capital accounts. Our stranded tax effects in AOCI, which are related to previous interest rate cash flow hedges, were $4 million and increased our capital account upon reclassification. We adopted the standard on a prospective basis effective January 1, 2019.

Topic 326, “Financial Instruments—Credit Losses” – In June 2016 the FASB issued ASU No. 2016-13, which changes how entities account for credit losses on receivables and certain other assets. The guidance requires use of a current expected credit loss model, which may result in earlier recognition of credit losses than under previous accounting standards. Topic 326 is required to be adopted in the first quarter of fiscal 2020 with earlier adoption permitted. We adopted on a prospective basis effective January 1, 2020. The adoption of the new standard did not have a material impact on our consolidated financial statements.

Topic 350, “Intangibles, Goodwill and Other —Internal-Use Software (Subtopic 40): Customer’s Accounting for Implementation Costs Incurred in a Cloud Computing Arrangement That Is a Service” – In August 2018, the FASB issued ASU 2018-15 which clarifies the accounting for implementation costs in cloud computing arrangements. ASU 2018-15 is required to be adopted in the first quarter of fiscal 2020 with earlier adoption permitted. We have early adopted on a prospective basis effective July 1, 2019. The early adoption did not have a material effect on our consolidated financial statements.

2. ACQUISITION ACTIVITY

InfraREIT Acquisition

On May 16, 2019, we completed the InfraREIT Acquisition, pursuant to which we acquired all of the equity interests of InfraREIT and its subsidiary, InfraREIT Partners. The InfraREIT Acquisition occurred through the merger of InfraREIT with and into a newly formed wholly owned subsidiary of Oncor, followed by the merger of another newly formed wholly owned subsidiary of Oncor with and into InfraREIT Partners. The stockholders of InfraREIT and the limited partners of InfraREIT Partners received $21.00 in cash per share of common stock or limited partnership unit, as applicable, resulting in a total cash consideration of $1,275 million. In addition, we paid certain transaction costs incurred by InfraREIT (including a management agreement termination fee of $40 million that InfraREIT paid an affiliate of Hunt Consolidated, Inc. at closing), with the aggregate cash consideration and payment of InfraREIT expenses totaling $1,324 million.

In connection with and immediately following the closing of the InfraREIT Acquisition, on May 16, 2019, we extinguished all $953 million outstanding principal amount of debt of InfraREIT and its subsidiaries through repaying $602 million principal amount of InfraREIT subsidiary debt and exchanging $351 million principal amount of InfraREIT subsidiary debt for new Oncor senior secured debt, as discussed in more detail in Notes 6 and 7.

On May 15, 2019, in connection with the InfraREIT Acquisition, we received capital contributions in an aggregate amount of $1,330 million from Sempra and certain indirect equity holders of Texas Transmission to fund the cash consideration and certain transaction expenses.

As a condition to the InfraREIT Acquisition, SDTS, and SDTS’s tenant, SU, completed the SDTS-SU Asset Exchange immediately prior to the closing of the InfraREIT Acquisition, pursuant to which SDTS exchanged certain of its south Texas assets for certain north Texas assets owned by SU. The north Texas assets acquired by SDTS consisted of certain real property and other assets owned by SU and used in the electric transmission and distribution business in central, north and west Texas, as well as equity interests in GS Project Entity, L.L.C., a Texas limited liability company that was merged with and into SDTS. The south Texas assets acquired by SU consisted of real property and other assets near the Texas-Mexico border. As a result of the InfraREIT Acquisition closing, we and our subsidiary NTU now own all of the assets and projects in the north, central, west and panhandle regions of Texas held by SDTS and SU immediately prior to the InfraREIT Acquisition, and Sharyland owns the assets that were held by SU and SDTS in south Texas immediately prior to the InfraREIT Acquisition. The assets we acquired include approximately 1,575 miles of transmission lines, including 1,235 circuit miles of 345kV transmission lines and approximately 340 circuit miles of 138kV transmission lines. The north, central, and west Texas transmission system acquired by us in the transaction is directly

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connected to approximately 20 operational generation facilities totaling approximately 3,900 MW and serves over 50 substations. We also acquired various projects in the north, central, west and panhandle regions of Texas, including a joint project with Lubbock Power & Light (LP&L) for the build out and associated station work to join most of the City of Lubbock’s electric facilities to the ERCOT market. Costs and investments for this project are ultimately to be split between Oncor and LP&L, with Oncor performing the construction and invoicing LP&L for its portion of the costs on a monthly basis.

In addition, as a condition to the closing of the SDTS-SU Asset Exchange, Sempra acquired an indirect 50 percent interest in Sharyland Holdings, the parent of Sharyland, in the Sempra-Sharyland Transaction. As a result of the Sempra-Sharyland Transaction, Sharyland is now our affiliate for purposes of PUCT rules. Pursuant to the agreement governing the SDTS-SU Asset Exchange and the PUCT order in Docket No. 48929 approving the InfraREIT Acquisition, upon closing of the InfraREIT Acquisition we entered into an operation agreement pursuant to which we will provide certain operations services to Sharyland at cost with no markup or profit.

Business Combination Accounting

We accounted for the InfraREIT Acquisition as a business acquisition with identifiable assets acquired and liabilities assumed recorded at their estimated fair values on the closing date. The combined results of operations are reported in our consolidated financial statements beginning as of the closing date. A summary of techniques used to estimate the preliminary fair value of the identifiable assets and liabilities is listed below.

• Assets and liabilities that are included in the PUCT cost-based regulatory rate-setting processes are recorded at fair values equal to their regulatory carrying value consistent with GAAP and industry practice.

• Working capital was valued using market information (Level 2).

The following tables set forth the purchase price paid and the allocation of the total purchase price paid to the identifiable assets acquired and liabilities assumed. The purchase price allocation is preliminary and the allocation to each identifiable asset acquired and liability assumed may change based upon the receipt of more detailed information and additional analyses related primarily to income tax liabilities. In the year ended December 31, 2019, we made various purchase price allocation adjustments related primarily to working capital accounts resulting in an $11 million reduction to goodwill. We currently expect the final purchase price allocation will be completed no later than the second quarter of 2020.

The total purchase price paid was comprised of the following

Purchase of outstanding InfraREIT shares and units	$	1,275
Certain transaction costs of InfraREIT paid by Oncor (a)		49
Total purchase price paid	$	1,324

(a) Represents certain transaction costs incurred by InfraREIT in connection with the transaction and paid by Oncor, including a $40 million management termination fee payable to an affiliate of Hunt Consolidated, Inc.

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Purchase price allocation is as follows:

	As of May 16, 2019
Assets acquired:
Current assets	$	45
Property, plant and equipment—net		1,800
Goodwill		676
Regulatory assets		16
Other noncurrent assets		10
Total assets acquired		2,547
Liabilities assumed:
Short-term debt		115
Other current liabilities		24
Regulatory liabilities		148
Liability in lieu of deferred income taxes		97
Long-term debt, including due currently		839
Total liabilities assumed		1,223
Net assets acquired		1,324
Total purchase price paid	$	1,324

The goodwill of $676 million arising from the InfraREIT Acquisition is attributable to the assets acquired, which expand our transmission footprint and help us support ERCOT market growth. None of the goodwill is recoverable nor provides a tax benefit in the rate-making process. We did not assume any employee benefit obligations in the acquisition.

Acquisition costs incurred in the InfraREIT Acquisition by Oncor and recorded to other deductions totaled $9 million in 2019. Our statements of consolidated income include revenues and net income of the acquired business totaling $156 million and $58 million, respectively, since the May 16, 2019 acquisition date.

Unaudited Pro Forma Financial Information

The following unaudited pro forma financial information for the year ended December 31, 2019 and 2018 assumes that the InfraREIT Acquisition occurred on January 1, 2018. The unaudited pro forma financial information is provided for information purposes only and is not necessarily indicative of the results of operations that would have occurred had the InfraREIT Acquisition been completed on January 1, 2018, nor is the unaudited pro forma financial information indicative of future results of operations, which may differ materially from the pro forma financial information presented here.

	Year Ended December 31,
	2019		2018
Oncor Consolidated Pro Forma Revenues	$	4,431	$	4,318

The unaudited pro forma financial information above excludes pro forma earnings due to the impracticability of a calculation. The acquiree previously operated under a real estate investment trust structure with a unique cost structure and unique federal tax attributes. An accurate retrospective application cannot be objectively and reliably calculated as the new cost structure and new tax attributes would require a significant amount of estimates and judgments.

Sharyland 2017 Asset Exchange

In November, 2017, we exchanged approximately $383 million of our transmission assets, consisting of 517 circuit miles of 345kV transmission lines, and approximately $25 million in cash for approximately $408 million of the Sharyland Entities’ distribution assets (constituting substantially all of their electricity distribution business) and certain of their transmission assets pursuant to the Sharyland 2017 Agreement. The Sharyland 2017 Asset Exchange expanded our customer base in west Texas and provides some potential growth opportunities for our distribution network. The exchange of assets between Oncor and the Sharyland Entities was structured to qualify, in part, as a simultaneous tax deferred like kind exchange to the extent that the assets exchanged are of “like kind” (within the meaning of section 1031 of the Code). The Sharyland 2017 Asset Exchange did not have a material effect on our results of operations, financial position or cash flows.

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3. REGULATORY MATTERS

Regulatory Assets and Liabilities

Recognition of regulatory assets and liabilities and the periods over which they are to be recovered or refunded through rate regulation reflect the decisions of the PUCT. Components of our regulatory assets and liabilities and their remaining recovery periods as of December 31, 2019 are provided in the table below. Amounts not earning a return through rate regulation are noted.

	Remaining Rate Recovery/Amortization Period at		At December 31,
	December 31, 2019		2019			2018
Regulatory assets:
Employee retirement liability (a)(b)(c)		To be determined	$	623		$	648
Employee retirement costs being amortized		8 years		262			297
Employee retirement costs incurred since the last rate review period (b)		To be determined		79			73
Self-insurance reserve (primarily storm recovery costs) being amortized		8 years		309			351
Self-insurance reserve incurred since the last rate review period (primarily storm related) (b)		To be determined		238			59
Securities reacquisition costs		Lives of related debt		29			10
Deferred conventional meter and metering facilities depreciation		1 year		15			36
Under-recovered AMS costs		8 years		170			185
Energy efficiency performance bonus (a)		1 year or less		9			7
Wholesale distribution substation service		To be determined		34			15
Other regulatory assets		Various		7			10
Total regulatory assets				1,775			1,691
Regulatory liabilities:
Estimated net removal costs		Lives of related assets		1,178			1,023
Excess deferred taxes		Primarily over lives of related assets		1,574			1,571
Over-recovered wholesale transmission service expense (a)		1 year or less		30			89
Other regulatory liabilities		Various		11			14
Total regulatory liabilities				2,793			2,697
Net regulatory assets (liabilities)			$	(1,018	)	$	(1,006	)

(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 accordance with pension and OPEB accounting standards.

InfraREIT Acquisition Approval (PUCT Docket No. 48929)

On May 9, 2019, the PUCT issued a final order in Docket No. 48929 approving the transactions contemplated by the InfraREIT Acquisition, including the SDTS-SU Asset Exchange, and the Sempra-Sharyland Transaction. For more information on these transactions, see Note 2.

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Regulatory Status of the TCJA

The excess deferred tax related balances above are primarily the result of the TCJA corporate federal income tax rate reduction from 35% to 21%. These regulatory liabilities reflect our obligation, as required by PUCT order in Docket No. 46957, to refund to utility customers any excess deferred tax related balances created by the reduction in the corporate federal income tax rate through reductions in our tariffs.

In 2018, we made filings to incorporate the impacts of the TCJA into our tariffs, including the reduction in the corporate income tax rate from 35% to 21% and amortization of excess deferred federal income taxes. In September 2018, we reached an unopposed stipulation regarding an overall settlement of the TCJA impacts. The settlement included, on an annual basis, $144 million decrease in our revenue requirement related to the reduction of income tax expense currently in rates and a $75 million decrease related to amortization of excess deferred federal income taxes. Unprotected excess deferred federal income taxes are being refunded over a ten-year period and the protected excess deferred federal income taxes are being refunded over the lives of the related assets.

The settlement rates were implemented on an interim basis during 2018 and were approved by the PUCT on April 4, 2019. During 2018, interim TCOS rates included refunds of excess deferred federal income taxes that were lower than the amount ultimately approved by the PUCT. Therefore, the PUCT approved in Docket 49160 an additional one time refund of $9 million, which was made in April and May of 2019.

DCRF (PUCT Docket No. 49427)

On April 8, 2019, we filed with the PUCT, as well as with cities with original jurisdiction over our rates, an application for approval of an updated DCRF. The DCRF allows us to recover, primarily through our tariff for retail delivery service, certain costs related to our distribution investments. In our DCRF application, we requested a $29 million increase in annual distribution revenues related to 2018 distribution investments. On May 30, 2019, a stipulated settlement agreement among the parties to the proceeding was reached that included a $25 million increase in annual distribution revenues, and, on June 10, 2019, interim rates based on the stipulated settlement agreement were authorized to begin on September 1, 2019. On September 12, 2019, the PUCT issued a final order implementing the settlement agreement and rates.

AMS Final Reconciliation (PUCT Docket No. 49721)

On July 9, 2019, we filed a request with the PUCT for a final reconciliation of our AMS costs. Effective with the implementation of rates pursuant to the Docket No. 46957 rate review, we ceased recovering AMS charges through a surcharge on November 26, 2017, and AMS costs are now being recovered through base rates. We made the following requests in our AMS reconciliation filing:

• a reconciliation of all costs incurred with the $87 million of revenues collected during the final period of the AMS surcharge from January 1, 2017 to November 26, 2017,

• a final PUCT determination of the net operating cost savings of $16 million from the final period of our AMS deployment that were used to reduce the amount of costs that were ultimately recovered through our AMS surcharge,

• authorization to add the under-recovery of the 2017 AMS costs from this reconciliation proceeding of $6 million to the existing AMS regulatory asset currently being recovered through base rates, and

• authorization to establish a regulatory asset to capture the costs associated with this reconciliation proceeding (if approved, Oncor would seek recovery of that regulatory asset in a future Oncor rate case).

On October 8, 2019, Oncor filed a joint motion to admit evidence and for approval of a joint proposed order that implements the requests detailed above, as agreed to by the PUCT staff and the Steering Committee of Cities. On December 16, 2019, the PUCT signed a Final Order approving Oncor’s requests as listed above.

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2017 Rate Review (PUCT Docket No. 46957)

In response to resolutions passed by numerous cities with original jurisdiction over electric utility rates, we filed rate review proceedings with the PUCT and original jurisdiction cities in our service territory in March 2017 based on a January 1, 2016 to December 31, 2016 test year.

In July 2017, we and certain parties to our rate review agreed to a settlement of that rate review, and on August 2, 2017 a settlement agreement was filed with the PUCT that settled all issues in the docket. On October 13, 2017, the PUCT issued an order approving the settlement of the rate review, subject to closing of the Sharyland Asset Exchange, which closed on November 9, 2017. As a result of the closing, the contingency in the PUCT Docket No. 46957 order was met and our new rates as set forth in that order took effect on November 27, 2017. The order also required us to record as a regulatory liability, instead of revenue, the amount that we collected through our approved tariffs for federal income taxes that was above the new corporate federal income rate. Other significant findings in the order include a change in our authorized return on equity to 9.80% and a change in our authorized regulatory capital structure to 57.5% debt to 42.5% equity. Our previous authorized return on equity was 10.25% and our previous authorized regulatory capital structure was 60% debt to 40% equity. The PUCT order required us to record a regulatory liability from November 27, 2017 until the new authorized regulatory capital structure was met to reflect our actual capitalization prior to achieving the authorized capital structure. Our authorized regulatory capital structure was met in May 2018, and therefore we ceased accruing amounts to the capital structure refund regulatory liability as of that time. The regulatory liability of $6 million was approved on September 14, 2018 in PUCT Docket No. 48522, and the liability was subsequently returned to customers in September 2018.

Also, in accordance with the rate review final order, effective November 27, 2017, the AMS surcharge ceased and ongoing AMS costs are being recovered through base rates which include the recovery of the AMS regulatory asset over a 10-year period. We continue to recover previously approved retired conventional meters over time as a regulatory asset.

Sharyland 2017 Asset Exchange (PUCT Docket No. 47469)

On July 21, 2017, we entered into the Sharyland 2017 Agreement, which provided for us to exchange certain of our transmission assets and cash for certain of the Sharyland Entities’ distribution assets (constituting substantially all of their electricity distribution business) and certain of their transmission assets. On October 13, 2017, the PUCT issued an order approving the Sharyland 2017 Asset Exchange and on November 9, 2017, the parties consummated the transaction. For more information on the Sharyland 2017 Agreement and the Sharyland 2017 Asset Exchange, see Note 2.

We are involved in various other regulatory proceedings in the normal course of business, the ultimate resolution of which, in the opinion of management, should not have a material effect upon our financial position, results of operations or cash flows.

4. REVENUES

General

Our revenue is billed monthly under tariffs approved by the PUCT and the majority of revenues are related to providing electric delivery service to consumers. Tariff rates are designed to recover the cost of providing electric delivery service to customers including a reasonable rate of return on invested capital. As the volumes delivered can be directly measured, our revenues are recognized when the underlying service has been provided in an amount prescribed by the related tariff. We recognize revenue in the amount that we have the right to invoice. Substantially all of our revenues are from contracts with customers except for alternative revenue program revenues discussed below.

Reconcilable Tariffs

The PUCT has designated certain tariffs (primarily TCRF and EECRF) 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.

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Alternative Revenue Program

The PUCT has implemented an incentive program allowing us to earn performance bonuses by exceeding PURA-mandated energy efficiency program targets. This incentive program and the related performance bonus revenues are considered an “alternative revenue program” under GAAP. Annual performance bonuses are recognized as revenue when approved by the PUCT, typically in the third or fourth quarter each year. In 2019 and 2018, the PUCT approved a $9 million and $7 million bonus that we recognized in revenues in 2019 and 2018, respectively.

Disaggregation of Revenues

The following table reflects electric delivery revenues disaggregated by tariff:

	Year Ended December 31,
	2019		2018
Operating revenues
Revenues contributing to earnings:
Distribution base revenues	$	2,143	$	2,139
Transmission base revenues (TCOS revenues)
Billed to third-party wholesale customers		681		548
Billed to REPs serving Oncor distribution customers, through TCRF		391		310
Total transmission base revenues		1,072		858
Other miscellaneous revenues		77	��	71
Total revenues contributing to earnings		3,292		3,068
Revenues collected for pass-through expenses:
TCRF—third-party wholesale transmission service		1,005		962
EECRF and other regulatory charges		50		71
Revenues collected for pass-through expenses		1,055		1,033
Total operating revenues	$	4,347	$	4,101

Customers

Our distribution customers consist of approximately 90 REPs and certain electric cooperatives in our certificated service area. The consumers of the electricity we deliver are free to choose their electricity supplier from REPs who compete for their business. Our transmission base revenues are collected from load serving entities benefitting from our transmission system. Our transmission customers consist of municipalities, electric cooperatives and other distribution companies. REP subsidiaries of our two largest counterparties represented 23% and 18% of our total operating revenues for the year ended 2019, 23% and 19% for the year ended 2018 and 22% and 18% for the year ended 2017. No other customer represented more than 10% of our total operating revenues.

Variability

Our revenues and cash flows are subject to seasonality, timing of customer billings, weather conditions and other electricity usage drivers, with revenues being highest in the summer. Payment is due 35 days after invoicing. Under a PUCT rule relating to the Certification of Retail Electric Providers, write-offs of uncollectible amounts owed by REPs are recoverable as a regulatory asset.

Pass-through Expenses

Expenses which are allowed to be passed-through to customers (primarily, third party wholesale transmission service and energy efficiency program costs) are generally recognized as revenue at the time the costs are incurred. Franchise taxes are assessed by local governmental bodies, based on kWh delivered and are not a “pass-through” item. The rates we charge customers are intended to recover the franchise taxes, but we are not acting as an agent to collect the taxes from customers; therefore, franchise taxes are reported as a principal component of “taxes other than amounts related to income taxes” instead of a reduction to “revenues” in the income statement.

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5. PROVISION IN LIEU OF INCOME TAXES

Tax Cuts and Jobs Act (TCJA)

On December 22, 2017, the TCJA was signed into law. Substantially all of the provisions of the TCJA were effective for our taxable years beginning January 1, 2018. The TCJA included significant changes to the Code, including amendments which significantly change the taxation of business entities and includes specific provisions related to regulated public utilities such as Oncor. The most significant TCJA change that impacts us is the reduction in the corporate federal income tax rate from 35% to 21%. The specific provisions related to regulated public utilities in the TCJA applicable to us include the continued deductibility of interest expense, the elimination of bonus depreciation on certain property acquired after September 27, 2017 and certain rate normalization requirements for accelerated depreciation benefits.

Changes in the Code from the TCJA had a material impact on our financial statements in 2017. Under GAAP, specifically Topic 740, Income Taxes, the tax effects of changes in tax laws must be recognized when the law is enacted, or December 22, 2017 for the TCJA. Topic 740 also requires deferred tax assets and liabilities to be measured at the enacted tax rate expected to apply when temporary differences are to be realized or settled. Based on this, our liability in lieu of deferred income taxes was re-measured at the date of enactment using the new tax rate.

We have completed the measurement and accounting for the effects of the TCJA. The re-measurement of our liability in lieu of deferred income taxes related to our non-regulated operations resulted in a $21 million charge to the nonoperating provision in lieu of tax expense for the year ended December 31, 2017. The re-measurement of our liability in lieu of deferred income taxes related to our regulated operations resulted in a $1.6 billion decrease in our liability in lieu of deferred income taxes at December 22, 2017 and a corresponding increase in our regulatory liabilities.

Components of Liability in Lieu of Deferred Income Taxes

The components of our liability in lieu of deferred income taxes are provided in the table below.

	At December 31,
	2019		2018
Deferred Tax Related Assets:
Employee benefit liabilities	$	224	$	234
Regulatory liabilities		51		55
Other		28		6
Total		303		295
Deferred Tax Related Liabilities:
Property, plant and equipment		1,851		1,651
Regulatory assets		272		245
Other		1		1
Total		2,124		1,897
Liability in lieu of deferred income taxes - net	$	1,821	$	1,602

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Provision (Benefit) in Lieu of Income Taxes

The components of our reported provision (benefit) in lieu of income taxes are as follows:

	Year Ended December 31,
	2019			2018			2017
Reported in operating expenses:
Current:
U.S. federal	$	69		$	112		$	(55	)
State		22			21			20
Deferred:
U.S. federal		49			21			303
State		—			—			—
Amortization of investment tax credits		(2	)		(2	)		(2	)
Total reported in operating expenses		138			152			266
Reported in other income and deductions:
Current:
U.S. federal		(21	)		(32	)		(5	)
State		—			—			—
Deferred federal		6			(3	)		6
Total reported in other income and deductions		(15	)		(35	)		1
Total provision in lieu of income taxes	$	123		$	117		$	267

Reconciliation of provision in lieu of income taxes computed at the U.S. federal statutory rate to provision in lieu of income taxes:

	Year Ended December 31,
	2019			2018			2017
Income before provision in lieu of income taxes	$	774		$	662		$	686
Provision in lieu of income taxes at the U.S. federal statutory rate of 21% for 2019 and 2018 and 35% for 2017	$	163		$	139		$	240
Amortization of investment tax credits – net of deferred tax effect		(2	)		(2	)		(2	)
Amortization of excess deferred taxes		(52	)		(18	)		(1	)
Impact of federal statutory rate change from 35% to 21%		—			—			21
Texas margin tax, net of federal tax benefit		17			17			13
Nontaxable gains on benefit plan investments		(2	)		(1	)		(4	)
Other		(1	)		(18	)		—
Reported provision in lieu of income taxes	$	123		$	117		$	267
Effective rate		15.9	%		17.7	%		38.9	%

The net amounts of $1.821 billion and $1.602 billion reported in the balance sheets at December 31, 2019 and 2018, respectively, as liability in lieu of deferred income taxes include amounts previously recorded as net deferred tax liabilities. Upon the sale of equity interests to Texas Transmission and Investment LLC in 2008, we became a partnership for U.S. federal income tax purposes, and the temporary differences that gave rise to the deferred taxes will, over time, become taxable to the equity holders. Under a tax sharing agreement among us and our equity holders (see Note 1), we make payments to the equity holders related to income taxes when amounts would have become due to the IRS if Oncor was taxed as a corporation. Accordingly, as the temporary differences become taxable, we will pay the equity holders. In the 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.

Accounting For Uncertainty in Provision in Lieu of Income Taxes

The statute of limitations is open for our partnership tax returns for the years beginning after December 31, 2009, however, the IRS has declined to review the tax returns for the years ended prior to January 1, 2016. Texas margin tax returns are under examination or still open for examination for tax years beginning after 2014. We are not a member of any consolidated federal tax group and assess our liability for uncertain tax positions in our partnership returns.

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We had no uncertain tax positions in 2019 and 2018. In the first quarter 2017, EFH Corp. settled all open tax claims with the IRS. As a result, we reduced the liability for uncertain tax positions by $3 million. This reduction is reported as a decrease in income taxes in 2017. Noncurrent liabilities included no accrued interest related to uncertain tax positions at December 31, 2019 and 2018. There were no amounts recorded related to interest and penalties in the years ended December 31, 2019, 2018 and 2017. The federal income tax benefit on the interest accrued on uncertain tax positions, if any, is recorded as liability in lieu of deferred income taxes.

6. SHORT-TERM BORROWINGS

At December 31, 2019 and 2018, outstanding short-term borrowings under our CP Program and Credit Facility consisted of the following:

	At December 31,
	2019			2018
Total credit facility borrowing capacity	$	2,000		$	2,000
Commercial paper outstanding (a)		(46	)		(813	)
Credit facility outstanding (b)		—			—
Letters of credit outstanding (c)		(10	)		(9	)
Available unused credit	$	1,944		$	1,178

a) The weighted average interest rate for commercial paper was 1.84% and 2.74% at December 31, 2019 and December 31, 2018, respectively.

b) At December 31, 2019, the applicable interest rate for any outstanding borrowings would have been LIBOR plus 1.00%.

c) Interest rates on outstanding letters of credit at December 31, 2019 and December 31, 2018 were 1.2% based on our credit ratings.

CP Program

In March 2018, we established the CP Program, under which we may issue unsecured commercial paper notes (CP Notes) on a private placement basis up to a maximum aggregate face or principal amount outstanding at any time of $2.0 billion. The proceeds of CP Notes issued under the CP Program are used for working capital and general corporate purposes. The CP Program obtains liquidity support from our Credit Facility discussed below. We may utilize either CP Program or the Credit Facility at our option, to meet our funding needs.

Credit Facility

In November 2017, we entered into a $2.0 billion unsecured Credit Facility to be used for working capital and general corporate purposes, issuances of letters of credit and support for any commercial paper issuances. We may request increases in our borrowing capacity in increments of not less than $100 million, not to exceed $400 million in the aggregate, provided certain conditions are met, including lender approvals. The Credit Facility has a five-year term expiring in November 2022 and gives us the option of requesting up to two one-year extensions, with such extensions subject to certain conditions and lender approvals. The Credit Facility replaced our previous $2.0 billion secured revolving credit facility (previous credit facility), which was terminated in connection with our entrance into the Credit Facility. Borrowings under our previous credit facility were secured with the lien of the Deed of Trust discussed in Note 7 below.

Borrowings under the Credit Facility bear interest at per annum rates equal to, at our option, (i) adjusted LIBOR plus a spread ranging from 0.875% to 1.50% 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) adjusted LIBOR plus 1.00%) plus a spread ranging from 0.00% to 0.50% depending on credit ratings assigned to our senior secured non-credit enhanced long-term debt. Amounts borrowed under the 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 0.075% to 0.225% (such spread depending on certain credit ratings assigned to our senior secured debt) of the daily unused commitments under the Credit Facility. Letter of credit fees on the stated amount of letters of credit issued under the Credit Facility are payable to the lenders quarterly in arrears and upon termination at a rate per annum equal to

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the spread over adjusted LIBOR. Customary fronting and administrative fees are also payable to letter of credit fronting banks. At December 31, 2019, letters of credit bore interest at 1.20%, and a commitment fee (at a rate of 0.125% per annum) was payable on the unfunded commitments under the Credit Facility, each based on our current credit ratings.

Under the terms of the Credit Facility, the commitments of the lenders to make loans to us are several and not joint. Accordingly, if any lender fails to make loans to us, our available liquidity could be reduced by an amount up to the aggregate amount of such lender’s commitments under the facility.

May 2019 Short-Term Bridge Loan

On May 9, 2019, we entered into a short-term unsecured term loan credit agreement (Bridge Loan) in an aggregate principal amount of up to $600 million in connection with the InfraREIT Acquisition. The Bridge Loan had a six-month term. Borrowings under the Bridge Loan could only be used to finance the repayment of indebtedness of InfraREIT or its affiliates and to pay expenses and fees related to the InfraREIT Acquisition. A fee was payable to the lenders under the Bridge Loan in an amount equal to 0.075% per annum on the average daily undrawn amount of the commitments.

The Bridge Loan contained 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. The Bridge Loan also contained a senior debt-to-capitalization ratio covenant that effectively limited our ability to incur indebtedness in the future.

On May 15, 2019, we borrowed $600 million under the Bridge Loan to pay, at closing of the InfraREIT Acquisition, all amounts outstanding under SDTS’s term loan, all amounts outstanding under the revolving credit facilities of SDTS and InfraREIT Partners, and amounts owed to discharge certain outstanding notes of InfraREIT’s subsidiaries. The borrowing under the Bridge Loan bore interest at a per annum rate equal to LIBOR plus 0.65%. The Bridge Loan was repaid in full in May 2019 with the proceeds from our May 23, 2019 senior secured notes issuance (discussed in Note 7 below) and as a result, the agreement is no longer in effect.

InfraREIT Short-Term Debt Repayments in Connection with the InfraREIT Acquisition

In connection with the closing of the InfraREIT Acquisition, on May 16, 2019, the credit facilities of InfraREIT and its subsidiaries were terminated and borrowings totaling $114 million principal amount were repaid in full by Oncor. For more information on the extinguishment of InfraREIT debt in connection with the InfraREIT Acquisition, see Notes 2 and 7.

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7. LONG-TERM DEBT

Our senior notes are secured by a 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. At December 31, 2019 and 2018, our long-term debt consisted of the following:

	December 31,
	2019			2018
Fixed Rate Secured:
2.15% Senior Notes due June 1, 2019	$	—		$	250
5.75% Senior Notes due September 30, 2020		126			126
8.50% Senior Notes, Series C, due December 30, 2020		14			—
4.10% Senior Notes, due June 1, 2022		400			400
7.00% Debentures due September 1, 2022		482			482
2.75% Senior Notes due June 1, 2024		500			—
2.95% Senior Notes due April 1, 2025		350			350
3.86% Senior Notes, Series A, due December 3, 2025		174			—
3.86% Senior Notes, Series B, due January 14, 2026		38			—
3.70% Senior Notes due November 15, 2028		650			350
5.75% Senior Notes due March 15, 2029		318			318
7.25% Senior Notes, Series B, due December 30, 2029		36			—
6.47% Senior Notes, Series A, due September 30, 2030		83			—
7.00% Senior Notes due May 1, 2032		500			500
7.25% Senior Notes due January 15, 2033		350			350
7.50% Senior Notes due September 1, 2038		300			300
5.25% Senior Notes due September 30, 2040		475			475
4.55% Senior Notes due December 1, 2041		400			400
5.30% Senior Notes due June 1, 2042		500			500
3.75% Senior Notes due April 1, 2045		550			550
3.80% Senior Notes due September 30, 2047		325			325
4.10% Senior Notes due November 15, 2048		450			450
3.80% Senior Notes, due June 1, 2049		500			—
3.10% Senior Notes, due September 15, 2049		700			—
Secured long-term debt		8,221			6,126
Variable Rate Unsecured:
Term loan credit agreement maturing December 9, 2019		—			350
Term loan credit agreement maturing October 6, 2020		460			—
Total long-term debt		8,681			6,476
Unamortized discount and debt issuance costs		(56	)		(41	)
Less amount due currently		(608	)		(600	)
Long-term debt, less amounts due currently	$	8,017		$	5,835

Long-Term Debt-Related Activity in 2019

Debt Repayments

Repayments of long-term debt in 2019 consisted of $488 million aggregate principal amount of long-term debt of InfraREIT’s subsidiaries that we paid on May 16, 2019 in connection with and immediately following the InfraREIT Acquisition through repayment of $288 million principal amount of outstanding InfraREIT subsidiary senior notes (plus $5 million in accrued interest and $19 million in make-whole fees relating to those notes) and repayment of an outstanding $200 million principal amount InfraREIT subsidiary term loan, $250 million aggregate principal amount of our 2.15% senior secured notes due June 1, 2019, $350 million aggregate principal amount of the term loan credit agreement maturing on December 9, 2019 (which was repaid in full and extinguished in November 2019) and $6 million principal amount of the quarterly amortizing debt for senior secured notes issued under the Note Purchase Agreements.

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Debt Issuances

Senior Secured Notes

In May 2019 we issued $500 million aggregate principal amount of 2.75% senior secured notes due 2024 (2024 Notes), $300 million aggregate principal amount of 3.70% senior secured notes due 2028 (2028 Notes) and $500 million aggregate principal amount of 3.80% Senior Secured Notes due 2049 (3.80% 2049 Notes). The 2028 Notes constitute an additional issuance of our 3.70% Senior Secured Notes due 2028, $350 million of which we previously issued on August 10, 2018 and are currently outstanding (Outstanding 2028 Notes). The 2028 Notes were issued as part of the same series as the Outstanding 2028 Notes. Additionally, the 2028 Notes exchanged or sold in connection with the transactions contemplated by a registration rights agreement are expected to become fungible with the Outstanding 2028 Notes. We used the proceeds (net of the initial purchasers’ discount, fees, expenses and accrued interest) of $1,297 million from the sale of the notes for general corporate purposes, including to repay all amounts outstanding under the Bridge Loan, to repay $250 million aggregate principal amount of our 2.15% Senior Secured Notes due June 1, 2019 and to repay CP Notes, when due, under our CP Program. For more information on the Bridge Loan, see Note 6.

Prior to May 1, 2024, in the case of the 2024 Notes, August 15, 2028 in the case of the 2028 Notes and December 1, 2048, in the case of the 2049 Notes, Oncor may redeem such notes at any time, in whole or in part, at a price equal to 100% of their principal amount, plus accrued and unpaid interest and a “make-whole” premium. On and after May 1, 2024, in the case of the 2024 Notes, August 15, 2028 in the case of the 2028 Notes and December 1, 2048, in the case of the 2049 Notes, Oncor may redeem such notes at any time, in whole or in part, at a redemption price equal to 100% of the principal amount of such notes, plus accrued and unpaid interest.

On September 12, 2019, we issued $700 million aggregate principal amount of 3.10% senior secured notes due September 15, 2049 (3.10% 2049 Notes and, together with the 2024 Notes, 2028 Notes and the 3.80% 2049 Notes, the New Indenture Notes). We used the proceeds (net of the initial purchasers’ discount, fees and expenses) of $689 million from the sale of the 3.10% 2049 Notes for general corporate purposes, including to repay CP Notes, when due, under our CP Program.

Prior to March 15, 2049, Oncor may redeem the 3.10% 2049 Notes at any time, in whole or in part, at a price equal to 100% of their principal amount, plus accrued and unpaid interest and a “make-whole” premium. On and after March 15, 2049, Oncor may redeem the 3.10% 2049 Notes at any time, in whole or in part, at a redemption price equal to 100% of the principal amount of the 3.10% 2049 Notes, plus accrued and unpaid interest.

The New Indenture Notes also contain customary events of default, including failure to pay principal or interest when due. The New Indenture Notes were issued in separate private placements. In November 2019, we completed an offering with the holders of the New Indenture Notes to exchange their respective New Indenture Notes for notes that have terms identical in all material respects to the New Indenture Notes (Exchange Notes), except that the Exchange Notes do not contain terms with respect to transfer restrictions, registration rights and payment of additional interest for failure to observe certain obligations in a certain registration rights agreement. The Exchange Notes were registered on a Form S-4, which was declared effective in October 2019.

Debt Exchange

In connection with closing the InfraREIT Acquisition on May 16, 2019, we exchanged $351 million principal amount of outstanding InfraREIT subsidiary senior notes for a like principal amount of newly issued Oncor secured senior notes. We received no proceeds from the issuance of the new Oncor notes and the exchanges were accounted for as debt modifications. Following are details of the exchanges:

(i) $87 million aggregate principal amount of newly issued Oncor 6.47% Senior Notes, Series A, due September 30, 2030 (2030 Notes), issued in exchange for a like principal amount of SDTS’s 6.47% Senior Notes due September 30, 2030,

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(ii) $38 million aggregate principal amount of newly issued Oncor 7.25% Senior Notes, Series B, due December 30, 2029 (2029 Notes), issued in exchange for a like principal amount of SDTS’s 7.25% Senior Notes due December 30, 2029,

(iii) $14 million aggregate principal amount of newly issued Oncor 8.50% Senior Notes, Series C, due December 30, 2020 (2020 Notes), issued in exchange for a like principal amount of Transmission and Distributions Company, L.L.C.’s 8.50% Senior Notes due December 30, 2020,

(iv) $174 million aggregate principal amount of newly issued Oncor 3.86% Senior Notes, Series A, due December 3, 2025 (2025 Notes), issued in exchange for a like principal amount of SDTS’s 3.86% Senior Notes due December 3, 2025, and

(v) $38 million aggregate principal amount of newly issued Oncor 3.86% Senior Notes, Series B, due January 14, 2026 (2026 Notes), issued in exchange for a like principal amount of SDTS’s 3.86% Senior Notes due January 14, 2026.

The 2030 Notes, 2029 Notes, 2020 Notes, 2025 Notes and 2026 Notes were each issued pursuant to a Note Purchase Agreement. Closing of the Note Purchase Agreements and issuance of the 2030 Notes, 2029 Notes, 2020 Notes, 2025 Notes and 2026 Notes (collectively, NPA Notes) occurred on May 16, 2019, immediately following consummation of the InfraREIT Acquisition.

The Note Purchase Agreements contain customary covenant restrictions and events of default. The NPA Notes are secured equally and ratably with our other secured indebtedness pursuant to the Deed of Trust. For more information on the Deed of Trust, see “Deed of Trust” below. We received no proceeds from the issuance of the NPA Notes.

Term Loan Credit Agreements

On September 6, 2019, we entered into an unsecured term loan credit agreement (2019 Term Loan Agreement) in an aggregate principal amount of up to $460 million. The 2019 Term Loan Agreement has a 13-month term, maturing on October 6, 2020. We borrowed the full aggregate principal amount available under the 2019 Term Loan Agreement of $460 million on September 25, 2019. The 2019 Term Loan Agreement bears interest at per annum rates equal to, at Oncor’s option, (i) LIBOR plus 0.50%, or (ii) an alternate base rate (the highest of (1) the prime rate of Wells Fargo Bank National Association, the administrative agent under the agreement, (2) the federal funds effective rate plus 0.50%, and (3) daily one-month LIBOR plus 1%). We used the proceeds (net of fees and expenses) for general corporate purposes, including to repay CP Notes, when due, under our CP program.

The 2019 Term Loan Agreement 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. The 2019 Term Loan Agreement contains a senior debt-to-capitalization ratio covenant that effectively limits our ability to incur indebtedness in the future. At December 31, 2019, we were in compliance with this covenant and all other covenants in the term loan credit agreement. See “Credit Rating Provisions, Covenants and Cross Default Provisions” below for additional information on this covenant and the calculation of this ratio.

In November 2019, we repaid $350 million, representing the full principal amount owed, under the term loan credit agreement entered into in 2018 that was scheduled to mature in December 2019. That term loan credit agreement contained covenants similar to the 2019 Term Loan Agreement. Upon repayment, the 2018 term loan agreement ceased to be in effect.

Deed of Trust

Our secured indebtedness 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 with the lien of the Deed of Trust up to the aggregate of (i) the amount of available bond credits, and (ii) 85% of the lower of the fair value or cost of certain property additions that could be certified to the Deed of Trust collateral agent. At December 31, 2019, the amount of available bond credits was $2,771 million 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 $2,410 million.

Borrowings under the CP Program, the Credit Facility and our term loan credit agreements are not secured.

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Maturities

Long-term debt maturities at December 31, 2019, are as follows:

Year	Amount
2020	$	608
2021		9
2022		891
2023		10
2024		510
Thereafter		6,653
Unamortized discount and debt issuance costs		(56	)
Total	$	8,625

Fair Value of Long-Term Debt

At December 31, 2019 and 2018, the estimated fair value of our long-term debt (including current maturities) totaled $10.003 billion and $7.086 billion, respectively, and the carrying amount totaled $8.625 billion and $6.435 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.

8. COMMITMENTS AND CONTINGENCIES

Leases

General

A lease exists when a contract conveys the right to control the use of an identified asset for a period of time in exchange for consideration. As lessee, our leased assets primarily consist of our vehicle fleet and real estate leased for company offices and service centers. Our leases are accounted for as operating leases for both GAAP and rate-making purposes. We generally recognize operating lease costs on a straight-line basis over the lease term in operating expenses. We are not a lessor to any material lease contracts.

As of the lease commencement date, we recognize a lease liability for our obligation to make lease payments, which we initially measure at present value using our incremental borrowing rate at the date of lease commencement, unless the rate implicit in the lease is readily determinable. We determine our incremental borrowing rate based on the rate of interest that we would have to pay to borrow an amount equal to the lease payments on a collateralized basis over a similar term in a similar economic environment. We also record a ROU asset for our right to use the underlying asset, which is initially equal to the lease liability and adjusted for any lease payments made at or before lease commencement, lease incentives and any initial direct costs.

Some of our lease agreements contain nonlease components, which represent items or activities that transfer a good or service. We separate lease components from nonlease components, if any, for our fleet vehicle and real estate leases for purposes of calculating the related lease liability and ROU asset.

Certain of our leases include options to extend the lease terms for up to 20 years, while others include options to terminate early. Our lease liabilities and ROU assets are based on lease terms that may include such options to extend or terminate the lease when it is reasonably certain that we will exercise that option.

Short-term Leases

Some of our contracts are short-term leases, which have a lease term of 12 months or less at lease commencement. As allowed by GAAP, we do not recognize a lease liability or ROU asset arising from short-term leases for all existing classes of underlying assets. We recognize short-term lease costs on a straight-line basis over the lease term.

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Lease Obligations, Lease Costs and Other Supplemental Data

The following tables summarize lease information on the consolidated balance sheet at December 31, 2019.

	At December 31, 2019
Operating Leases:
ROU assets:
Operating lease ROU and other assets	$	92
Lease liabilities:
Operating lease and other current liabilities	$	26
Employee benefit, operating lease and other obligations		66
Total operating lease liabilities	$	92
Weighted-average remaining lease term (in years)		4
Weighted-average discount rate		3.3	%

The components of lease costs and cash paid for amounts included in the measurement of lease liabilities in 2019 were as follows:

	Year Ended December 31, 2019
Operating lease cost:
Operating lease costs (including amounts allocated to property, plant and equipment)	$	40
Short-term lease costs		34
Total operating lease costs	$	74
Operating lease payments:
Cash paid for amounts included in the measurement of lease liabilities	$	32

The table below presents the maturity analysis of our lease liabilities and reconciliation to the present value of lease liabilities:

Year	Amount
2020	$	28
2021		25
2022		19
2023		13
2024		8
Thereafter		3
Total undiscounted lease payments		96
Less imputed interest		(4	)
Total operating lease obligations	$	92

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Leases that Have Not Yet Commenced

In December 2019, we entered into a 15 year lease agreement for replacement office space. The lease will commence in February 2020 and is expected to be accounted for as an operating lease.

Leases Disclosures Under Previous GAAP

At December 31, 2018, our future minimum lease payments under our operating leases (with initial or remaining noncancelable lease terms in excess of one year) were as follows:

Year	Amount
2019	$	29
2020		22
2021		20
2022		15
2023		8
Thereafter		5
Total future minimum lease payments	$	99

Rent charged to operation and maintenance expense totaled $28 million and $27 million for the years ended December 31, 2018 and 2017, respectively.

Capital Expenditures

As part of the Sempra Acquisition, Oncor has committed to make minimum aggregate capital expenditures equal to at least $7.5 billion over the five year period ending December 31, 2022.

Energy Efficiency Spending

We are required to annually invest in programs designed to improve customer electricity demand efficiencies to satisfy ongoing regulatory requirements. The requirement for the year 2020 is $50 million, which is recoverable in rates.

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.

Labor Contracts

At December 31, 2019, approximately 18% of our full time employees were represented by a labor union and covered by a collective bargaining agreement with an expiration date of October 25, 2022.

Environmental Contingencies

We must comply with environmental laws and regulations applicable to the handling and disposal of hazardous waste. We are in compliance with all current laws and regulations; however, the impact, if any, of changes to existing regulations or the implementation of new regulations is not determinable. The costs to comply with environmental regulations can be significantly affected by the following external events or conditions:

• changes to existing state or federal regulation by governmental authorities having jurisdiction over control of toxic substances and hazardous and solid wastes, and other environmental matters, and

• the identification of additional sites requiring clean-up or the filing of other complaints in which we may be asserted to be a potential responsible party.

We have not identified any significant potential environmental liabilities at this time.

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9. MEMBERSHIP INTERESTS

Cash Contributions

On February 18, 2020, we received cash capital contributions from our members totaling $87 million. During 2019, we received the following capital cash contributions from our members.

Received	Amount
November 21, 2019	$	340
October 28, 2019		98
July 29, 2019		70
May 15, 2019		1,330
April 30, 2019		70
February 19, 2019		70
	$	1,978

Cash Distributions

Distributions are limited by the requirement to maintain our regulatory capital structure at or below the assumed debt-to-equity ratio established periodically by the PUCT for ratemaking purposes. 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 including any finance leases 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 acquisition accounting from a 2007 transaction (which included recording the initial goodwill and fair value adjustments and subsequent related impairments and amortization).

The PUCT order issued in the Sempra Acquisition and our Limited Liability Company Agreement set forth various restrictions on distributions to our members. Among those restrictions is the commitment that we will make no distributions that would cause us to be out of compliance with the PUCT’s approved debt-to-equity ratio, which is currently 57.5% debt to 42.5% equity. The distribution restrictions also include the ability of our board, a majority of the Disinterested Directors, or either of the two member directors designated by Texas Transmission to limit distributions to the extent each determines it is necessary to meet expected future requirements of Oncor (including continuing compliance with the PUCT debt-to-equity ratio commitment). At December 31, 2019, we had $751 million available to distribute to our members as our regulatory capitalization ratio was 54.8% debt to 45.2% equity.

On February 19, 2020, our board of directors declared a cash distribution of $91 million, which was paid to our members on February 20, 2020. During 2019, our board of directors declared, and we paid, the following cash distributions to our members:

Declaration Date	Payment Date		Amount
October 29, 2019		October 31, 2019	$	106
July 30, 2019		July 31, 2019		71
May 1, 2019		May 2, 2019		71
February 20, 2019		February 22, 2019		71
			$	319

During 2018, our board of directors declared, and we paid, the following cash distributions to our members:

Declaration Date	Payment Date		Amount
October 24, 2018		November 6, 2018	$	179
July 25, 2018		August 1, 2018		30
			$	209

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Accumulated Other Comprehensive Income (Loss) (AOCI)

The following table presents the changes to accumulated other comprehensive income (loss) for the years ended December 31, 2019, 2018 and 2017 net of tax.

	Cash Flow Hedges – Interest Rate Swap			Defined Benefit Pension and OPEB Plans			Accumulated Other Comprehensive Income (Loss)
Balance at December 31, 2016	$	(20	)	$	(91	)	$	(111	)
Defined benefit pension plans		—			8			8
Cash flow hedge amounts reclassified from AOCI and reported in interest expense and related charges		2			—			2
Balance at December 31, 2017	$	(18	)	$	(83	)	$	(101	)
Defined benefit pension plans		—			(65	)		(65	)
Cash flow hedge amounts reclassified from AOCI and reported in interest expense and related charges		2			—			2
Balance at December 31, 2018	$	(16	)	$	(148	)	$	(164	)
Defined benefit pension plans		—			27			27
Cash flow hedge amounts reclassified from AOCI and reported in interest expense and related charges		2			—			2
Amounts reclassified from accumulated other comprehensive income (loss) to capital account		(4	)		—			(4	)
Balance at December 31, 2019	$	(18	)	$	(121	)	$	(139	)

10. EMPLOYEE BENEFIT PLANS

Regulatory Recovery of Pension and OPEB Costs

PURA provides for our recovery of pension and OPEB costs applicable to services of our active and retired employees, as well as services of certain EFH Corp./Vistra active and retired employees for periods prior to the deregulation and disaggregation of EFH Corp.’s electric utility businesses effective January 1, 2002 (recoverable service). Accordingly, in 2005, we entered into an agreement with a predecessor of EFH Corp. whereby we assumed responsibility for applicable pension and OPEB costs related to those personnel’s recoverable service. We subsequently entered into agreements with EFH Corp. and a Vistra affiliate regarding provision of these benefits. Pursuant to our agreement with the Vistra affiliate, we now sponsor an OPEB plan that provides certain retirement healthcare and life insurance benefits to eligible former Oncor, EFH Corp. and Vistra employees for whom both Oncor and Vistra bear a portion of the benefit responsibility. See “OPEB Plans” below for more information.

We are authorized to establish a regulatory asset or liability for the difference between the amounts of pension and OPEB costs approved in current billing rates and the actual amounts that would otherwise have been recorded as charges or credits to earnings related to recoverable service. Amounts deferred are ultimately subject to regulatory approval. At December 31, 2019 and 2018, we had recorded regulatory assets totaling $964 million and $1,018 million, respectively, related to pension and OPEB costs, including amounts related to deferred expenses as well as amounts related to unfunded liabilities that otherwise would be recorded as other comprehensive income.

We have also assumed primary responsibility for pension benefits of a closed group of retired and terminated vested plan participants not related to our regulated utility business (non-recoverable service) in a 2012 transaction. Any retirement costs associated with non-recoverable service are not recoverable through rates.

Pension Plans

We sponsor the Oncor Retirement Plan and also have liabilities under the Vistra Retirement Plan (formerly EFH Retirement Plan), both of which are qualified pension plans under Section 401(a) of the Code, and are subject to the provisions of ERISA. Employees do not contribute to either plan. These pension plans provide benefits to participants

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under one of two formulas: (i) a Cash Balance Formula under which participants earn monthly contribution credits based on their compensation and a combination of their age and years of service, plus monthly interest credits or (ii) a Traditional Retirement Plan Formula based on years of service and the average earnings of the three years of highest earnings. The interest component of the Cash Balance Formula is variable and is determined using the yield on 30-year Treasury bonds. Under the Cash Balance Formula, future increases in earnings will not apply to prior service costs.

All eligible employees hired after January 1, 2001 participate under the Cash Balance Formula. Certain employees, who, prior to January 1, 2002, participated under the Traditional Retirement Plan Formula, continue their participation under that formula. It is Oncor’s policy to fund its plans on a current basis to the extent required under existing federal tax and ERISA regulations.

We also have the Supplemental Retirement Plan for certain employees whose retirement benefits cannot be fully earned under the qualified retirement plan. Supplemental Retirement Plan amounts are included in the reported pension amounts below.

At December 31, 2019, the pension plans’ projected benefit obligation included a net actuarial loss of $367 million for 2019 due primarily to a decrease in the discount rate. Actual returns on the plans’ assets in 2019 were more than the expected return on assets by $367 million. We expect the pension plans’ amortizations of net actuarial losses to be $47 million in 2020.

OPEB Plans

We currently sponsor two OPEB Plans. One plan covers our eligible current and future retirees whose services are 100% attributed to the regulated business. Effective January 1, 2018, we established a second plan to cover eligible retirees of Oncor and EFH Corp./Vistra whose employment services were assigned to both Oncor (or a predecessor regulated utility business) and the non-regulated business of EFH Corp./Vistra. Vistra is solely responsible for its portion of the liability for retiree benefits related to those retirees.

Oncor’s contribution policy for the OPEB Plans is to place in irrevocable external trusts dedicated to the payment of OPEB expenses an amount at least equal to the OPEB expense recovered in rates.

At December 31, 2019, the Oncor OPEB Plans’ projected benefit obligation included a net actuarial gain of $5 million for 2019, including $145 million gain associated with mortality assumption changes, and updates to health care claims and trend assumptions, offset by a loss of $126 million due to a decrease in the discount rate and a loss of $14 million associated with census date updates. Actual returns on Oncor OPEB Plans’ assets in 2019 were more than the expected return on assets by $17 million resulting in a net actuarial gain of $22 million. We expect the Oncor OPEB Plans’ amortizations of net actuarial losses to decrease by $9 million in 2020 reflecting these changes.

Pension and OPEB Costs Recognized as Expense

Pension and OPEB amounts provided herein include amounts related only to our portion of the various plans based on actuarial computations and reflect our employee and retiree demographics as described above. Our net costs related to pension and the Oncor OPEB Plans were comprised of the following:

	Year Ended December 31,
	2019			2018			2017
Pension costs	$	63		$	77		$	85
OPEB costs		41			70			58
Total benefit costs		104			147			143
Less amounts recognized principally as property or a regulatory asset		(27	)		(69	)		(98	)
Net amounts recognized as operation and maintenance expense or other deductions	$	77		$	78		$	45

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The calculated value method is used to determine the market-related value of the assets held in the trust for purposes of calculating our pension costs. Realized and unrealized gains or losses in the market-related value of assets are included over a rolling four-year period. Each year, 25% of such gains and losses for the current year and for each of the preceding three years is included in the market-related value. Each year, the market-related value of assets is increased for contributions to the plan and investment income and is decreased for benefit payments and expenses for that year.

The fair value method is used to determine the market-related value of the assets held in the trust for purposes of calculating OPEB cost.

Detailed Information Regarding Pension and OPEB Benefits

The following pension and OPEB information is based on December 31, 2019, 2018 and 2017 measurement dates:

	Pension Plans									OPEB Plans
	Year Ended December 31,									Year Ended December 31,
	2019			2018			2017			2019			2018			2017
Assumptions Used to Determine Net Periodic Pension and OPEB Costs:
Discount rate		4.18	%		3.54	%		4.05	%		4.41	%		3.73	%		4.35	%
Expected return on plan assets		5.42	%		5.11	%		5.17	%		6.19	%		6.20	%		6.10	%
Rate of compensation increase		4.53	%		4.46	%		3.33	%		—			—			—
Components of Net Pension and OPEB Costs:
Service cost	$	25		$	27		$	24		$	6		$	8		$	7
Interest cost		128			121			131			43			44			47
Expected return on assets		(119	)		(120	)		(115	)		(7	)		(9	)		(8	)
Amortization of prior service cost (credit)		—			—			—			(20	)		(30	)		(20	)
Amortization of net loss		29			49			45			19			57			32
Net periodic pension and OPEB costs	$	63		$	77		$	85		$	41		$	70		$	58
Other Changes in Plan Assets and Benefit Obligations Recognized as Regulatory Assets or in Other Comprehensive Income:
Net loss (gain)	$	—		$	67		$	(11	)	$	(22	)	$	(177	)	$	139
Amortization of net loss		(29	)		(49	)		(45	)		(19	)		(57	)		(32	)
Plan amendments		—			—			—			—			—			(78	)
Amortization of prior service (cost) credit		—			—			—			20			30			20
Total recognized as regulatory assets or other comprehensive income		(29	)		18			(56	)		(21	)		(204	)		49
Total recognized in net periodic pension and OPEB costs and as regulatory assets or other comprehensive income	$	34		$	95		$	29		$	20		$	(134	)	$	107

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	Pension Plans									OPEB Plans
	Year Ended December 31,									Year Ended December 31,
	2019			2018			2017			2019			2018			2017
Assumptions Used to Determine Benefit Obligations at Period End:
Discount rate		3.13	%		4.18	%		3.54	%		3.29	%		4.41	%		3.73	%
Rate of compensation increase		4.64	%		4.53	%		4.46	%		—			—			—

	Pension Plans						OPEB Plans
	Year Ended December 31,						Year Ended December 31,
	2019			2018			2019			2018
Change in Projected Benefit Obligation:
Projected benefit obligation at beginning of year	$	3,162		$	3,500		$	1,006		$	1,198
Service cost		25			27			6			8
Interest cost		128			121			43			44
Participant contributions		—			—			19			19
Plan amendments		—			—			—			—
Actuarial (gain) loss		367			(232	)		(5	)		(196	)
Benefits paid		(164	)		(175	)		(70	)		(67	)
Annuity purchase		(118	)		(79	)		—			—
Projected benefit obligation at end of year	$	3,400		$	3,162		$	999		$	1,006
Accumulated benefit obligation at end of year	$	3,283		$	3,069		$	—		$	—
Change in Plan Assets:
Fair value of assets at beginning of year	$	2,249		$	2,600		$	132		$	149
Actual return (loss) on assets		486			(179	)		25			(10	)
Employer contributions		41			82			35			41
Participant contributions		—			—			19			19
Benefits paid		(164	)		(175	)		(70	)		(67	)
Annuity purchase		(118	)		(79	)		—			—
Fair value of assets at end of year	$	2,494		$	2,249		$	141		$	132
Funded Status:
Projected benefit obligation at end of year	$	(3,400	)	$	(3,162	)	$	(999	)	$	(1,006	)
Fair value of assets at end of year		2,494			2,249			141			132
Funded status at end of year	$	(906	)	$	(913	)	$	(858	)	$	(874	)

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	Pension Plans				OPEB Plans
	Year Ended December 31,				Year Ended December 31,
	2019		2018		2019		2018
Amounts Recognized in the Balance Sheet Consist of:
Liabilities:
Other current liabilities	$	(5)	$	(4)	$	(15)	$	(7)
Other noncurrent liabilities		(901)		(909)		(843)		(867)
Net liability recognized	$	(906)	$	(913)	$	(858)	$	(874)	��
Regulatory assets:
Net loss	$	531	$	534	$	129	$	171
Prior service cost (credit)		—		—		(37)		(57)
Net regulatory asset recognized	$	531	$	534	$	92	$	114
Accumulated other comprehensive net loss	$	120	$	147	$	1	$	1

The following tables provide information regarding the assumed health care cost trend rates.

	Year Ended December 31,
	2019			2018
Assumed Health Care Cost Trend Rates – Not Medicare Eligible:
Health care cost trend rate assumed for next year		7.20	%		7.60	%
Rate to which the cost trend is expected to decline (the ultimate trend rate)		4.50	%		4.50	%
Year that the rate reaches the ultimate trend rate		2029			2026
Assumed Health Care Cost Trend Rates – Medicare Eligible:
Health care cost trend rate assumed for next year		8.00	%		8.70	%
Rate to which the cost trend is expected to decline (the ultimate trend rate)		4.50	%		4.50	%
Year that the rate reaches the ultimate trend rate		2029			2027

	1-Percentage Point Increase		1-Percentage Point Decrease
Sensitivity Analysis of Assumed Health Care Cost Trend Rates:
Effect on accumulated postretirement obligation	$	128	$	(106	)
Effect on postretirement benefits cost		5		(4	)

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The following table provides information regarding pension plans with projected benefit obligations (PBO) and accumulated benefit obligations (ABO) in excess of the fair value of plan assets.

	At December 31,
	2019		2018
Pension Plans with PBO and ABO in Excess of Plan Assets:
Projected benefit obligations	$	3,400	$	3,162
Accumulated benefit obligations		3,283		3,069
Plan assets		2,494		2,249

Pension and OPEB Plans Investment Strategy and Asset Allocations

Our investment objective for the retirement plans is to invest in a suitable mix of assets to meet the future benefit obligations at an acceptable level of risk, while minimizing the volatility of contributions. Equity securities are held to achieve returns in excess of passive indexes by participating in a wide range of investment opportunities. International equity, real estate securities and credit strategies (high yield bonds, emerging market debt and bank loans) are used to further diversify the equity portfolio. International equity securities may include investments in both developed and emerging international markets. Fixed income securities include primarily corporate bonds from a diversified range of companies, U.S. Treasuries and agency securities and money market instruments. Our investment strategy for fixed income investments is to maintain a high grade portfolio of securities, which assists us in managing the volatility and magnitude of plan contributions and expense while maintaining sufficient cash and short-term investments to pay near-term benefits and expenses.

The Oncor Retirement Plan’s investments are managed in two pools: one pool associated with the recoverable service portion of plan obligations related to Oncor’s regulated utility business, and a second pool associated with the non-recoverable service portion of plan obligations not related to Oncor’s regulated utility business. Each pool is invested in a broadly diversified portfolio as shown below. The second pool represents 27% of total investments at December 31, 2019.

The target asset allocation ranges of the pension plan’s investments by asset category are as follows:

	Target Allocation Ranges
Asset Category	Recoverable	Non-recoverable
International equities	13% - 21%	6% - 12%
U.S. equities	16% - 24%	8% - 14%
Real estate	3% - 7%	—
Credit strategies	5% - 10%	5% - 9%
Fixed income	45% - 55%	68% - 78%

Our investment objective for the Oncor OPEB Plans primarily follows the objectives of the pension plans discussed above, while maintaining sufficient cash and short-term investments to pay near-term benefits and expenses. The actual amounts at December 31, 2019 provided below are consistent with the asset allocation targets.

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Fair Value Measurement of Pension Plans’ Assets

At December 31, 2019 and 2018, pension plans’ assets measured at fair value on a recurring basis consisted of the following:

	At December 31, 2019
	Level 1		Level 2		Level 3		Total
Asset Category
Equity securities:
U.S.	$	194	$	2	$	—	$	196
International		290		1		—		291
Fixed income securities:
Corporate bonds (a)		—		908		—		908
U.S. Treasuries		—		147		—		147
Other (b)		—		63		—		63
Real estate		—		—		3		3
Total assets in the fair value hierarchy	$	484	$	1,121	$	3		1,608
Total assets measured at net asset value (c)								886
Total fair value of plan assets							$	2,494

	At December 31, 2018
	Level 1		Level 2		Level 3		Total
Asset Category
Equity securities:
U.S.	$	170	$	2	$	—	$	172
International		239		—		—		239
Fixed income securities:
Corporate bonds (a)		—		930		—		930
U.S. Treasuries		—		110		—		110
Other (b)		—		69		—		69
Real estate		—		—		3		3
Total assets in the fair value hierarchy	$	409	$	1,111	$	3		1,523
Total assets measured at net asset value (c)								726
Total fair value of plan assets							$	2,249

(a) Substantially all corporate bonds are rated investment grade by Fitch, Moody’s or S&P.

(b) Other consists primarily of municipal bonds, emerging market debt, bank loans and fixed income derivative instruments.

(c) Fair value was measured using the net asset value (NAV) per share as a practical expedient as the investments did not have a readily determinable fair value and are not required to be classified in the fair value hierarchy. The NAV fair value amounts presented here are intended to permit a reconciliation to the total fair value of plan assets.

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Fair Value Measurement of Oncor OPEB Plans’ Assets

At December 31, 2019 and 2018, the Oncor OPEB Plans’ assets measured at fair value on a recurring basis consisted of the following:

	At December 31, 2019
	Level 1		Level 2		Level 3		Total
Asset Category
Interest-bearing cash	$	6	$	—	$	—	$	6
Equity securities:
U.S.		24		—		—		24
International		28		—		—		28
Fixed income securities:
Corporate bonds (a)		—		31		—		31
U.S. Treasuries		—		3		—		3
Other (b)		22		2		—		24
Total assets in the fair value hierarchy	$	80	$	36	$	—		116
Total assets measured at net asset value (c)								25
Total fair value of plan assets							$	141

	At December 31, 2018
	Level 1		Level 2		Level 3		Total
Asset Category
Interest-bearing cash	$	15	$	—	$	—	$	15
Equity securities:
U.S.		21		—		—		21
International		22		—		—		22
Fixed income securities:
Corporate bonds (a)		—		26		—		26
U.S. Treasuries		—		3		—		3
Other (b)		28		1		—		29
Total assets in the fair value hierarchy	$	86	$	30	$	—		116
Total assets measured at net asset value (c)								16
Total fair value of plan assets							$	132

(a) Substantially all corporate bonds are rated investment grade by Fitch, Moody’s or S&P.

(b) Other consists primarily of diversified bond mutual funds.

(c) Fair value was measured using the net asset value (NAV) per share as a practical expedient as the investments did not have a readily determinable fair value and are not required to be classified in the fair value hierarchy. The NAV fair value amounts presented here are intended to permit a reconciliation to the total fair value of plan assets.

Expected Long-Term Rate of Return on Assets Assumption

The retirement plans’ strategic asset allocation is determined in conjunction with the plans’ advisors and utilizes a comprehensive Asset-Liability modeling approach to evaluate potential long-term outcomes of various investment strategies. The modeling incorporates long-term rate of return assumptions for each asset class based on historical and future expected asset class returns, current market conditions, rate of inflation, current prospects for economic growth, and taking into account the diversification benefits of investing in multiple asset classes and potential benefits of employing active investment management.

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Pension Plans				Oncor OPEB Plans
Asset Class	Expected Long-Term Rate of Return			Asset Class	Expected Long-Term Rate of Return
International equity securities		7.63	%	401(h) accounts		6.26	%
U.S. equity securities		6.80	%	Life insurance VEBA		6.04	%
Real estate		5.20	%	Union VEBA		6.04	%
Credit strategies		4.56	%	Non-union VEBA		1.80	%
Fixed income securities		3.40	%	Shared retiree VEBA		1.80	%
Weighted average (a)		5.22	%	Weighted average		5.90	%

(a) The 2020 expected long-term rate of return for the nonregulated portion of the Oncor Retirement Plan is 4.18%, and for Oncor’s portion of the Vistra Retirement Plan is 4.89%.

Significant Concentrations of Risk

The plans’ investments are exposed to risks such as interest rate, capital market and credit risks. We seek to optimize return on investment consistent with levels of liquidity and investment risk which are prudent and reasonable, given prevailing capital market conditions and other factors specific to participating employers. While we recognize the importance of return, investments will be diversified in order to minimize the risk of large losses unless, under the circumstances, it is clearly prudent not to do so. There are also various restrictions and guidelines in place including limitations on types of investments allowed and portfolio weightings for certain investment securities to assist in the mitigation of the risk of large losses.

Assumed Discount Rate

For the Oncor retirement plans at December 31, 2019, we selected the assumed discount rate using the Aon AA-AAA Bond Universe yield curve, which is based on corporate bond yields and at December 31, 2019 consisted of 927 corporate bonds with an average rating of AA and AAA using Moody’s, S&P and Fitch ratings. For Oncor’s portion of the Vistra Retirement Plan and the Oncor OPEB Plans at December 31, 2019, we selected the assumed discount rate using the Aon AA Above Median yield curve, which is based on corporate bond yields and at December 31, 2019 consisted of 361 corporate bonds with an average rating of AA using Moody’s, S&P and Fitch ratings.

Amortization in 2020

In 2020, amortization of the net actuarial loss for the defined benefit pension plans from regulatory assets and other comprehensive income into net periodic benefit cost is expected to be $43 million and $5 million, respectively. No amortization of prior service credit is expected in 2020 for the defined benefit pension plans. Amortization of the net actuarial loss for the OPEB plans from regulatory assets and other comprehensive income into net periodic benefit cost is expected to be $10 million and zero, respectively. Amortization of prior service credit for the OPEB plans from regulatory assets and other comprehensive income into net periodic benefit cost is expected to be $20 million and zero, respectively.

Pension and Oncor OPEB Plans Cash Contributions

Our contributions to the benefit plans were as follows:

	Year Ended December 31,
	2019		2018		2017
Pension plans contributions	$	41	$	82	$	149
Oncor OPEB Plans contributions		35		41		31
Total contributions	$	76	$	123	$	180

Our funding for the pension plans and the Oncor OPEB Plans is expected to total $177 million and $35 million, respectively in 2020 and approximately $571 million and $176 million, respectively, in the five year period 2020 to 2024.

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Future Benefit Payments

Estimated future benefit payments to participants are as follows:

	2020		2021		2022		2023		2024		2025-29
Pension plans	$	179	$	183	$	188	$	191	$	196	$	996
Oncor OPEB Plans	$	50	$	51	$	53	$	55	$	56	$	285

Thrift Plan

Our employees are eligible to participate in a qualified savings plan, a participant-directed defined contribution plan intended to qualify under Section 401(a) of the Code, and is subject to the provisions of ERISA. Under the plan, employees may contribute, through pre-tax salary deferrals and/or after-tax applicable payroll deductions, a portion of their regular salary or wages as permitted under law. Employer matching contributions are made in an amount equal to 100% of the first 6% of employee contributions for employees who are covered under the Cash Balance Formula of the Oncor Retirement Plan, and 75% of the first 6% of employee contributions for employees who are covered under the Traditional Retirement Plan Formula of the Oncor Retirement Plan. Employer matching contributions are made in cash and may be allocated by participants to any of the plan’s investment options. Our contributions to the Oncor Thrift Plan totaled $20 million, $19 million and $17 million for the years ended December 31, 2019, 2018 and 2017, respectively.

11. STOCK-BASED COMPENSATION

We currently do not offer stock-based compensation to our employees or directors. In 2008 and 2009, we established stock appreciation rights (SARs) plans under which certain of our executive officers, key employees and non-employee members of our board of directors were granted SARs payable in cash, or in some circumstances, Oncor membership interests.

In November 2012, we accepted the early exercise for cash payments of all outstanding SARs (both vested and unvested) issued to date pursuant to both SARs plans. As part of the 2012 early exercise of SARs we began accruing interest on dividends declared with respect to the SARs. Under both SARs plans, dividends that were paid in respect of Oncor membership interests while the SARs were outstanding were credited to the SARs holder’s account as if the SARs were units, payable upon the earliest to occur of death, disability, separation from service, unforeseeable emergency, a change in control, or the occurrence of an event triggering SAR exercisability. As a result of the Sempra Acquisition, the dividend and interest accounts were distributed in 2018, totaling $15 million. For accounting purposes, the liability was discounted based on an employee’s or director’s expected retirement date. We recognized $4 million and $1 million in accretion and interest with respect to such dividend and interest accounts in years 2018 and 2017, respectively. No SARs liability remained at December 31, 2019.

12. RELATED-PARTY TRANSACTIONS

The following represent our significant related-party transactions and related matters.

• We are not a member of another entity’s consolidated tax group, but our owners’ federal income tax returns include their portion of our results. Under the terms of a tax sharing agreement among us, Oncor Holdings, Texas Transmission and STH (as successor to EFH Corp.), we are generally obligated to make payments to our owners, 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. STH will file a combined Texas margin tax return which includes our results and our share of 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 under “Provision in Lieu of 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 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.

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Amounts payable to (receivable from) members related to income taxes under the agreement and reported on our balance sheet consisted of the following:

	At December 31, 2019									At December 31, 2018
	STH			Texas Transmission			Total			STH		Texas Transmission		Total
Federal income taxes payable (receivable)	$	(2	)	$	(1	)	$	(3	)	$	4	$	1	$	5
Texas margin taxes payable		22			—			22			21		—		21
Net payable (receivable)	$	20		$	(1	)	$	19		$	25	$	1	$	26

Cash payments made to (received from) members related to income taxes consisted of the following:

	Year Ended December 31, 2019						Year Ended December 31, 2018									Year Ended December 31, 2017
	STH		Texas Transm.		Total		STH		EFH Corp.			Texas Transm.		Total		EFH Corp.			Texas Transm.			Total
Federal income taxes	$	45	$	11	$	56	$	59	$	(19	)	$	10	$	50	$	(102	)	$	(12	)	$	(114	)
Texas margin taxes		22		—		22		21		—			—		21		20			—			20
Total payments (receipts)	$	67	$	11	$	78	$	80	$	(19	)	$	10	$	71	$	(82	)	$	(12	)	$	(94	)

• As of March 8, 2018, approximately 16% of the equity in an existing vendor of the company was owned by a member of the Sponsor Group. As a result of the Sempra Acquisition, the Sponsor Group ceased to be a related party as of March 9, 2018. During 2018 and 2017, this vendor performed transmission and distribution system construction and maintenance services for us. Cash payments were made for such services to this vendor and/or its subsidiaries totaling $35 million dollars for the year-to-date period ended March 8, 2018, of which approximately $33 million was capitalized and $2 million was recorded as an operation and maintenance expense. Cash payments were made for such services to this vendor and/or its subsidiaries totaling $219 million for 2017, of which approximately $210 million was capitalized and $9 million recorded as an operation and maintenance expense.

• From the May 16, 2019 InfraREIT Acquisition date through December 31, 2019, we paid Sharyland $9 million pursuant to certain of their transmission and distribution tariffs applicable to us and we provided Sharyland with substation monitoring and switching service of $303,000.

• For the year ended December 31, 2019, we paid Sempra $109,000 pursuant to an agreement for certain corporate support services, including tax work.

See Notes 1, 5, and 9 for information regarding the tax sharing agreement and distributions to members.

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13. SUPPLEMENTARY FINANCIAL INFORMATION

Other Deductions and (Income)

	Year Ended December 31,
	2019			2018			2017
Professional fees	$	10		$	12		$	15
Sempra Acquisition related costs		—			12			—
InfraREIT Acquisition related costs		9			—			—
Recoverable Pension and OPEB—non-service costs		57			53			31
Non-recoverable pension and OPEB (Note 10)		4			6			5
AFUDC equity income		(10	)		—			—
Interest income		(5	)		(1	)		(6	)
Other		(2	)		2			1
Total other deductions and (income)—net	$	63		$	84		$	46

Interest Expense and Related Charges

	Year Ended December 31,
	2019			2018			2017
Interest	$	382		$	358		$	351
Amortization of debt issuance costs and discounts		9			6			3
Less AFUDC – capitalized interest portion		(16	)		(13	)		(12	)
Total interest expense and related charges	$	375		$	351		$	342

Trade Accounts and Other Receivables

Trade accounts and other receivables reported on our balance sheet consisted of the following:

	At December 31,
	2019			2018
Gross trade accounts and other receivables	$	666		$	562
Allowance for uncollectible accounts		(5	)		(3	)
Trade accounts receivable – net	$	661		$	559

At December 31, 2019, REP subsidiaries of two of our largest counterparties represented 15% and 11% of the trade accounts receivable balance and at December 31, 2018, represented 13% and 10% of the trade accounts receivable balance.

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.

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Investments and Other Property

Investments and other property reported on our balance sheet consist of the following:

	At December 31,
	2019		2018
Assets related to employee benefit plans	$	119	$	108
Land		12		12
Other		2		—
Total investments and other property	$	133	$	120

The majority of these assets represent cash surrender values of life insurance policies that are purchased to fund liabilities under deferred compensation plans. At December 31, 2019 and 2018, the face amount of these policies totaled $172 million and $157 million, respectively, and the net cash surrender values (determined using a Level 2 valuation technique) totaled $95 million and $87 million at December 31, 2019 and 2018, respectively. Changes in cash surrender value are netted against premiums paid. Other investment assets held to satisfy deferred compensation liabilities are recorded at market value.

Property, Plant and Equipment

Property, plant and equipment reported on our balance sheet consisted of the following:

	Composite Depreciation Rate/		At December 31,
	Avg. Life at December 31, 2019		2019		2018
Assets in service:
Distribution		2.8% / 35.8 years	$	14,007	$	13,105
Transmission		2.9% / 35.0 years		11,094		8,568
Other assets		6.9% / 14.5 years		1,648		1,497
Total				26,749		23,170
Less accumulated depreciation				7,986		7,513
Net of accumulated depreciation				18,763		15,657
Construction work in progress				585		417
Held for future use				22		16
Property, plant and equipment – net			$	19,370	$	16,090

Depreciation expense as a percent of average depreciable property approximated 2.7%, 2.8% and 3.4% for the years ended December 31, 2019, 2018 and 2017, respectively.

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Intangible Assets

Intangible assets (other than goodwill) reported on our balance sheet as part of property, plant and equipment consisted of the following:

	At December 31, 2019						At December 31, 2018
	Gross Carrying Amount		Accumulated Amortization		Net		Gross Carrying Amount		Accumulated Amortization		Net
Identifiable intangible assets subject to amortization:
Land easements	$	575	$	107	$	468	$	464	$	101	$	363
Capitalized software		933		430		503		787		385		402
Total	$	1,508	$	537	$	971	$	1,251	$	486	$	765

Aggregate amortization expense for intangible assets totaled $52 million, $50 million and $57 million for the years ended December 31, 2019, 2018 and 2017, respectively. At December 31, 2019, the weighted average remaining useful lives of capitalized land easements and software were 83 years and 9 years, respectively. The estimated aggregate amortization expense for each of the next five fiscal years is as follows:

Year	Amortization Expense
2020	$	61
2021		61
2022		61
2023		61
2024		60

Goodwill totaling $4,740 million and $4,064 million were reported on our balance sheet at December 31, 2019 and 2018, respectively. The increase is due to the InfraREIT Acquisition. None of this goodwill is being deducted for tax purposes. See Note 1 regarding goodwill impairment assessment and testing.

Employee Benefit, Operating Lease and Other Obligations

Employee benefit, operating lease and other obligations reported on our balance sheet consisted of the following:

	At December 31,
	2019		2018
Retirement plans and other employee benefits	$	1,834	$	1,858
Operating lease liabilities (Notes 1 and 8)		66		—
Investment tax credits		6		8
Other		74		77
Total employee benefit, operating lease and other obligations	$	1,980	$	1,943

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Supplemental Cash Flow Information

	Year Ended December 31,
	2019			2018			2017
Cash payments related to:
Interest	$	368		$	368		$	345
Less capitalized interest		(16	)		(13	)		(12	)
Interest payments (net of amounts capitalized)	$	352		$	355		$	333
Amount in lieu of income taxes (a):
Federal	$	56		$	50		$	(114	)
State		22			21			20
Total payments (refunds) in lieu of income taxes	$	78		$	71		$	(94	)
Noncash increase in operating lease obligation for ROU assets	$	38		$	—		$	—
Noncash Sharyland 2017 Asset Exchange costs	$	—		$	—		$	383
Noncash investing and financing activity (b):
Acquisition:
Assets acquired	$	2,547		$	—		$	—
Liabilities assumed		(1,223	)		—			—
Cash paid	$	1,324		$	—		$	—
Noncash construction expenditures (c)	$	278		$	174		$	129

(a) See Note 12 for income tax related detail.

(b) See Note 7 for more information on noncash debt exchanges related to InfraREIT Acquisition.

(c) Represents end-of-period accruals.

Quarterly Information (unaudited)

Results of operations by quarter for the years ended December 31, 2019 and 2018 are summarized below. In our opinion, all adjustments (consisting of normal recurring accruals) necessary for a fair statement of such amounts have been made. Quarterly results are not necessarily indicative of a full year’s operations because of seasonal and other factors.

2019	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Operating revenues	$	1,016	$	1,041	$	1,211	$	1,079
Operating income		216		253		369		236
Net income		116		139		263		133
2018	First Quarter		Second Quarter		Third Quarter		Fourth Quarter
Operating revenues	$	990	$	1,021	$	1,095	$	995
Operating income		202		244		293		206
Net income		89		143		194		119

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14. EFH BANKRUPTCY PROCEEDINGS AND SEMPRA ACQUISITION

In April 2014, EFH Corp. and the substantial majority of its direct and indirect subsidiaries at the time commenced proceedings under Chapter 11 of the U.S. Bankruptcy Code. The Oncor Ring-Fenced Entities were not parties to the EFH Bankruptcy Proceedings. On March 9, 2018, Sempra acquired the 80.03% of Oncor’s membership interests owned indirectly by EFH Corp. and EFIH (Sempra Acquisition). As a result of the Sempra Acquisition, EFH Corp. merged with an indirect subsidiary of Sempra, with EFH Corp. (renamed STH) continuing as the surviving company and an indirect, wholly owned subsidiary of Sempra. Sempra paid cash consideration of approximately $9.45 billion to acquire the indirect 80.03% outstanding membership interest in Oncor held by Oncor Holdings and other EFH Corp. assets and liabilities unrelated to Oncor. In addition, in a separate transaction, Oncor Holdings acquired 0.22% of the outstanding membership interests in Oncor from Investment LLC for $26 million in cash, which represents approximately $18.60 per membership interest. As a result, after the Sempra Acquisition, Oncor Holdings owns 80.25% of our outstanding membership interests and Texas Transmission owns 19.75% of our outstanding membership interests. In February 2020, Sempra acquired (through STIH) an indirect 1% ownership interest in Texas Transmission.

The Sempra Acquisition was consummated after obtaining the approval of the bankruptcy court in the EFH Bankruptcy Proceedings, the Federal Communications Commission and the PUCT. The PUCT approval was obtained in Docket No. 47675, and the final order issued in that docket as well as our Limited Liability Company Agreement outline certain ring-fencing measures, governance mechanisms and restrictions that apply after the Sempra Acquisition. As a result of these ring-fencing measures, Sempra does not control Oncor, and the ring-fencing measures limit Sempra’s ability to direct the management, policies and operations of Oncor, including the deployment or disposition of Oncor’s assets, declarations of dividends, strategic planning and other important corporate issues and actions. These limitations include limited representation on the board of directors of Oncor. For more information on the ring-fencing measures applicable after the Sempra Acquisition, see Note 1.

The Sempra Order also contains certain operational and financial commitments, including that Oncor will make minimum capital expenditures equal to at least $7.5 billion over the period from January 1, 2018 until December 31, 2022 (subject to certain adjustments).

F-68

ONCOR ELECTRIC DELIVERY COMPANY LLC

Offers to Exchange

$400,000,000 aggregate principal amount of its 2.75% Senior Secured Notes due 2030 and $400,000,000 aggregate principal amount of its 3.70% Senior Secured Notes due 2050, each of which have been registered under the Securities Act of 1933, as amended, for any and all of its outstanding 2.75% Senior Secured Notes due 2030 and 3.70% Senior Secured Notes due 2050.

Until October 12, 2020, the date that is 90 days from the date of this prospectus, all dealers that effect transactions in these securities, whether or not participating in the exchange offers, may be required to deliver a prospectus. This is in addition to the dealers’ obligation to deliver a prospectus when acting as underwriters with respect to their unsold allotments or subscriptions.