Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer”, “accelerated filer,” “smaller reporting company,” and "emerging growth company" in Rule 12b-2 of the Exchange Act.

As of April 30,October 31, 2019, Con Edison had outstanding 327,053,801332,430,408 Common Shares ($.10 par value). All of the outstanding common equity of CECONY is held by Con Edison.

The following is a glossary of abbreviations or acronyms that are used in the Companies’ SEC reports:

This report includes forward-looking statements intended to qualify for the safe-harbor provisions of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements are statements of future expectation and not facts. Words such as “forecasts,” “expects,” “estimates,” “anticipates,” “intends,” “believes,” “plans,” “will” and similar expressions identify forward-looking statements. Forward-looking statements are based on information available at the time the statements are made, and accordingly speak only as of that time. Actual results or developments might differ materially from those included in the forward-looking statements because of various factors including, but not limited to:

The Companies assume no obligation to update forward-looking statements.

The following table presents, for the three and nine months ended March 31,September 30, 2019 and 2018, revenue from contracts with customers as defined in Accounting Standards Codification (ASC) Topic 606, "Revenue from Contracts with Customers," as well as additional revenue from sources other than contracts with customers, disaggregated by major source.

As of March 31,September 30, 2019, the aggregate amount of the remaining fixed performance obligations of the Clean Energy Businesses under contracts with customers for energy services is $79$89 million, of which $43$53 million will be recognized within the next two years, and the remaining $36 million will be recognized pursuant to long-term service and maintenance agreements.

In January 2019, Pacific Gas and Electric Company (PG&E) filed in the United States Bankruptcy Court for the Northern District of California for reorganization under Chapter 11 of the U.S. Bankruptcy Code. The output of certain Con Edison Development renewable electric production projects with an aggregate generating capacity of 680 MW (AC) of generating capacity (PG&E Projects) is sold to PG&E under long-term power purchase agreements (PG&E PPAs). Most of the PG&E PPAs have contract prices that are higher than estimated market prices. PG&E, as a debtor in possession, may assume or reject the PG&E PPAs, subject to review by the bankruptcy court. In September 2019, PG&E submitted its plan of reorganization to the bankruptcy court. PG&E’s plan includes the assumption by PG&E of all of its power purchase agreements. PG&E’s plan is subject to, among other things: confirmation by the bankruptcy court by June 30, 2020 (or any extension of the date by which PG&E’s bankruptcy must be resolved for PG&E to participate in the insurance fund described below); approval by the California Public Utilities Commission (CPUC) of PG&E’s implementation of the plan and participation in the insurance fund; and PG&E obtaining funding for distributions under the plan. PG&E may revoke, withdraw or pursuantdelay consideration of the plan prior to its confirmation by the bankruptcy court, and file subsequent amended plans of reorganization. In October 2019, the Ad Hoc PG&E senior note holder committee (Noteholders) and tort claimant committee (TCC) submitted to the bankruptcy court an alternative plan of reorganization for PG&E. The Noteholder/TCC plan also calls for PG&E to assume all of its power purchase agreements and participate in the insurance fund. The Noteholder/TCC plan is also subject to, among other things, confirmation by the bankruptcy court, approval by the CPUC and obtaining funding for distributions under the plan. The Noteholder/TCC plan can be revoked, amended, withdrawn or delayed. Bankruptcy court approval is required for a plan of reorganization to be sent to creditors for consideration.

In January and May 2019, FERC orderissued orders (which PG&E is challenging), the bankruptcy court and FERC. In a May 1, 2019 order, FERC denied PG&E’s request for a rehearing of the January 2019 order and reaffirmed affirming its jurisdiction to review and approve the modification or abrogation of wholesale power contracts that are the subject of rejection in bankruptcy. In June 2019, the bankruptcy court ruled that FERC does not have concurrent jurisdiction with it and that FERC’s January and May 2019 orders are of no force and effect in the bankruptcy proceeding. FERC and additional parties, including Con Edison Development, are challenging the bankruptcy court’s June 2019 ruling in appeals that are pending in the United States Court of Appeals for the Ninth Circuit.

The PG&E bankruptcy is an event of default under the PG&E PPAs. Unless the lenders for the related project debt otherwise agree, distributions from the related projects to Con Edison Development will not be made during the pendency of the bankruptcy. See “Reconciliation of Cash, Temporary Cash Investments and Restricted Cash,” below.

At March 31,September 30, 2019, Con Edison’s consolidated balance sheet included $859$827 million of net non-utility plant relating to the PG&E Projects, $1,108$1,075 million of intangible assets relating to the PG&E PPAs, $289$287 million of net non-utility plant of additional projects that secure the related project debt and $1,041$1,012 million of non-recourse related project debt. See "Long-term Debt" in Note C. Con Edison has tested whether its net non-utility plant relating to the PG&E Projects and intangible assets relating to the PG&E PPAs have been impaired. The projected future cash flows used in the test reflected Con Edison’s expectation that the PG&E PPAs are not likely to be rejected. Based on the test, Con Edison has determined that there was no impairment. If, in the future, one or more of the PG&E PPAs is rejected or any such rejection becomes likely, there will be an impairment of the related intangible assets and could be an impairment of the related non-utility plant. The amount of any such impairment could be material.

Con Edison presents basic and diluted earnings per share (EPS) on the face of its consolidated income statement. Basic EPS is calculated by dividing earnings available to common shareholders (“Net income for common stock” on Con Edison’s consolidated income statement) by the weighted average number of Con Edison common shares outstanding during the period. In the calculation of diluted EPS, weighted average shares outstanding are increased for additional shares that would be outstanding if potentially dilutive securities were converted to common stock.

Potentially dilutive securities for Con Edison consist of restricted stock units and deferred stock units for which the average market price of the common shares for the period was greater than the exercise price.price and its common shares that are subject to a May 2019 forward sale agreement (see Note C). Before the issuance of common shares upon settlement of the forward sale agreement, the shares will be reflected in the company’s diluted earnings per share calculations using the treasury stock method. Under this method, the number of common shares used in calculating diluted earnings per share is deemed to be increased by the excess, if any, of the number of shares that would be issued upon physical settlement of the forward sale agreement over the number of shares that could be purchased by the company in the market (based on the average market price during the period) using the proceeds due upon physical settlement (based on the adjusted forward sale price at the end of the reporting period).

The computation of diluted EPS for the three and nine months ended March 31, 2019 andSeptember 30, 2018 excludes immaterial amounts of performance share awards that were not included because of their anti-dilutive effect.

For the three and nine months ended March 31,September 30, 2019 and 2018, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:

Cash, temporary cash investments and restricted cash are presented on a combined basis in the Companies’ consolidated statements of cash flows. At March 31,September 30, 2019 and 2018, cash, temporary cash investments and restricted cash for Con Edison and CECONY are as follows:

In March 2019, the NYSPSC approved the November 2018 joint proposalJoint Proposal for new electric and gas rates. The joint proposalJoint Proposal provides for electric rate increases of $13.4 million, $8.0 million and $5.8 million, effective January 1, 2019, 2020 and 2021, respectively. The joint proposalJoint Proposal provides for a gas rate decrease of $7.5 million, effective January 1, 2019, and gas rate increases of $3.6 million and $0.7 million, effective January 1, 2020 and 2021.2021, respectively.

In August and November 2017, the NYSPSC issued orders in its proceeding investigating an April 21, 2017 Metropolitan Transportation Authority (MTA) subway power outage. The orders indicated that the investigation determined that the outage was caused by a failure of CECONY’s electricity supply to a subway station, which led to a loss of the subway signals, and that one of the secondary services to the MTA facility had been improperly rerouted and was not properly documented by the company. The orders also indicated that the loss of power to the subway station affected multiple subway lines and caused widespread delays across the subway system. Pursuant to the orders, the company iswas required to take certain actions, including inspecting, repairing and installing certain electrical equipment that serves the subway system, analyzing power supply and power quality events affecting the MTA’s signaling services, and filing monthly reports with the NYSPSC on all of the company's activities related to the subway system. The company completed the required actions in 2018. Through March 31, 2019, the company incurredThe company’s costs related to this matter in excess of $270 million. Included in this amount is $31 million in capital and operating and maintenance coststhose reflected in the company'sits current electric rate plan and $239 millionwere deferred as a regulatory asset thatand are addressed in the company is seekingOctober 2019 Joint Proposal (see footnote (b) to recover in its pending electric rate proceeding. The company is unable to estimate the amount or range of its possible loss related to this matter. At March 31, 2019, the company had not accrued a liability related to this matter.CECONY - Electric table under “Rate Plans,” above).

In August 2018, the NYSPSC ordered CECONY to begin on January 1, 2019 to credit the company's electric and gas customers, and to begin on October 1, 2018 to credit its steam customers, with the net benefits of the federal Tax Cuts and Jobs Act of 2017 (TCJA) as measured based on amounts reflected in its rate plans prior to the enactment of the TCJA in December 2017. The net benefits include the revenue requirement impact of the reduction in the corporate federal income tax rate to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes. CECONY estimates that its credit of net benefits of the TCJA to its electric, gas and steam customers in 2019 will amount to $259 million, $113 million and $25 million, respectively. CECONY’s net benefits prior to January 1, 2019 and its net regulatory liability for future income taxes, including both the protected and unprotected portions, allocable to the company’s electric and gas customers ($311 million) are to be deferred and addressed in its pending electric rate proceeding. CECONY’s net benefits prior to January 1,the October 2019 allocableJoint Proposal (see footnote (b) to the company’s gas customers ($90 million)CECONY - Electric and Gas tables under “Rate Plans,” above). CECONY’s net benefits prior to October 1, 2018 allocable to the company’s steam customers ($15 million) are to bebeing amortized over a three-year period. CECONY’s net regulatory liability for future income taxes, including both the protected and unprotected portions, allocable to the company’s electric customers ($2,489 million) is to continue to be deferred and addressed in its pending electric rate proceeding and the amounts allocable to its gas and steam customers ($804 million and $185 million, respectively) are to be185 million) is being amortized over the remaining lives of the related assets (with the amortization period for the unprotected portion subject to review in its pending gas rate proceeding and next steam rate proceeding).