false--12-31--12-31Q32019000104786200000236322457200000057200000081230000001420000002536600000074000000088610000001830000002619700000080600000096000000002110000001000000000.480.4870000004500000008100000046100000088000000476000000960000000.156900000020000000740000002200000079000000250000000.10000.47140.0960P10YP10Y1130000008400000037000000012200000032600000016700000021660000000717100000022783000000791100000023926000000862200000065000000750000000.0930.093P3YP2YP3Y0.06610.066127500000025000000357000000250000006200000057000000670000006200000050000003000000500000030000000.7150.7150.7150.7150.740.740.740.02940.03460.03730.0382P2Y7.7571.774.110.4523.400.357.7571.772.437.030.4516.200.971.002000000290000003000000103000000800000000.04630.046370000006000000100000010000000.49930.0890.50160.0880.0881990000058000002030000010000002000000100000010000003000000P2Y0.0300.023267000000450000002690000004300000027200000010000000 0001047862 ed:TermLoanMember 2019-02-28

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q



x☒	Quarterly Report Pursuant To Section 13 or 15(d) of the Securities Exchange Act of 1934

FOR THE QUARTERLY PERIOD ENDED ~~SEPTEMBER~~September 30, ~~2017~~2019



¨☐	Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from to



Commission File Number	Exact name of registrant as specified in its charter and principal executive office address and telephone number					State of Incorporation	I.R.S. Employer ID. Number
1-14514	Consolidated Edison, Inc.					New York	13-3965100
	4 Irving Place,		New York,	New York	10003
	(212)	460-4600
1-1217	Consolidated Edison Company of New York, Inc.					New York	13-5009340
	4 Irving Place,		New York,	New York	10003
	(212)	460-4600

Securities Registered Pursuant to Section 12(b) of the Act:



Title of each class	Trading Symbol	Name of each exchange on which registered
Consolidated Edison, Inc.,	ED	New York Stock Exchange
Common Shares ($.10 par value)

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.



Consolidated Edison, Inc. (Con Edison)	Yesx	☒	No¨☐
Consolidated Edison Company of New York, Inc. (CECONY)	Yesx	☒	No¨☐

Indicate by check mark whether the registrant has submitted electronically ~~and posted on its corporate Web site, if any,~~ every Interactive Data File required to be submitted ~~and posted~~ 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 ~~and post~~ such files).



Con Edison	Yesx	☒	No¨☐
CECONY	Yesx	☒	No¨☐

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.



Con Edison
Large accelerated filerx	☒		Accelerated filer☐	~~Accelerated filer~~¨	Non-accelerated filer¨	☐
Smaller reporting company¨		☐	Emerging growth company¨	☐
CECONY
Large accelerated filer¨	☐		Accelerated filer¨☐		Non-accelerated filerx	☒
Smaller reporting company¨		☐	Emerging growth company¨	☐

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If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).



Con Edison	Yes¨	☐	Nox	☒
CECONY	Yes¨	☐	Nox	☒

As of October 31, ~~2017,~~2019, Con Edison had outstanding ~~310,068,797~~332,430,408 Common Shares ($.10 par value). All of the outstanding common equity of CECONY is held by Con Edison.

Filing Format

This Quarterly Report on Form 10-Q is a combined report being filed separately by two different registrants: Consolidated Edison, Inc. (Con Edison) and Consolidated Edison Company of New York, Inc. (CECONY). CECONY is a wholly-owned subsidiary of Con Edison and, as such, the information in this report about CECONY also applies to Con Edison. As used in this report, the term the “Companies” refers to Con Edison and CECONY. However, CECONY makes no representation as to the information contained in this report relating to Con Edison or the subsidiaries of Con Edison other than itself.

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Glossary of Terms

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



Con Edison Companies
Con Edison		Consolidated Edison, Inc.
CECONY		Consolidated Edison Company of New York, Inc.
Clean Energy Businesses		Con Edison Clean Energy Businesses, Inc., together with its subsidiaries
Con Edison Development		Consolidated Edison Development, Inc.
Con Edison Energy		Consolidated Edison Energy, Inc.
Con Edison Solutions		Consolidated Edison Solutions, Inc.
Con Edison Transmission		Con Edison Transmission, Inc., together with its subsidiaries
CET Electric		Consolidated Edison Transmission, LLC
CET Gas		Con Edison Gas Pipeline and Storage, LLC
O&R		Orange and Rockland Utilities, Inc.
RECO		Rockland Electric Company
The Companies		Con Edison and CECONY
The Utilities		CECONY and O&R

Regulatory Agencies, Government Agencies and Other Organizations
CPUC		California Public Utilities Commission
EPA		U.S. Environmental Protection Agency
FASB		Financial Accounting Standards Board
FERC		Federal Energy Regulatory Commission
IASB		International Accounting Standards Board
IRS		Internal Revenue Service
NJBPU		New Jersey Board of Public Utilities
NJDEP		New Jersey Department of Environmental Protection
NYISO		New York Independent System Operator
NYPA		New York Power Authority
NYSDEC		New York State Department of Environmental Conservation
NYSERDA		New York State Energy Research and Development Authority
NYSPSC		New York State Public Service Commission
NYSRC		New York State Reliability Council, LLC
PJM		PJM Interconnection LLC
SEC		U.S. Securities and Exchange Commission

Accounting
AFUDC		Allowance for funds used during construction
ASU		Accounting Standards Update
GAAP		Generally Accepted Accounting Principles in the United States of America
HLBV		Hypothetical liquidation at book value
OCI		Other Comprehensive Income
VIE		Variable Interest Entity

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Environmental
CO2		Carbon dioxide
GHG		Greenhouse gases
MGP Sites		Manufactured gas plant sites
PCBs		Polychlorinated biphenyls
PRP		Potentially responsible party
RGGI		Regional Greenhouse Gas Initiative
Superfund		Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes

Units of Measure
AC		Alternating current
Bcf		Billion cubic feet
Dt		Dekatherms
kV		Kilovolt
kWh		Kilowatt-hour
MDt		Thousand dekatherms
MMlb		Million pounds
MVA		Megavolt ampere
MW		Megawatt or thousand kilowatts
MWh		Megawatt hour

Other
AMI		Advanced metering infrastructure
COSO		Committee of Sponsoring Organizations of the Treadway Commission
DER		Distributed energy resources
~~EGWP~~		~~Employer Group Waiver Plan~~
Fitch		Fitch Ratings
First Quarter Form 10-Q		The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended March 31 of the current year
Second Quarter Form 10-Q		The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended June 30 of the current year
Third Quarter Form 10-Q		The Companies' combined Quarterly Report on Form 10-Q for the quarterly period ended September 30 of the current year
Form 10-K		The Companies’ combined Annual Report on Form 10-K for the year ended December 31, ~~2016~~2018
LTIP		Long Term Incentive Plan
Moody’s		Moody’s Investors Service
REV		Reforming the Energy Vision
S&P		S&P Global Ratings
TCJA		The federal Tax Cuts and Jobs Act of 2017, as enacted on December 22, 2017
VaR		Value-at-Risk

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TABLE OF CONTENTS



		PAGE
PART I—Financial Information
ITEM 1	Financial Statements (Unaudited)
	Con Edison
	Consolidated Income Statement	7
	Consolidated Statement of Comprehensive Income	8
	Consolidated Statement of Cash Flows	9
	Consolidated Balance Sheet	10
	Consolidated Statement of Equity	12
	CECONY
	Consolidated Income Statement	13
	Consolidated Statement of Comprehensive Income	14
	Consolidated Statement of Cash Flows	15
	Consolidated Balance Sheet	16
	Consolidated Statement of Shareholder’s Equity	18
	Notes to the Financial Statements (Unaudited)	19
ITEM 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3948
ITEM 3	Quantitative and Qualitative Disclosures About Market Risk	6984
ITEM 4	Controls and Procedures	6984
PART II—Other Information		7085
ITEM 1	Legal Proceedings	7085
ITEM 1A	Risk Factors	7085
ITEM 6	Exhibits	7085
	Signatures	7186

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FORWARD-LOOKING STATEMENTS

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 are extensively regulated and are subject to penalties;~~


��	the Companies are extensively regulated and are subject to penalties;

the Utilities’ rate plans may not provide a reasonable return;

the Companies may be adversely affected by changes to the Utilities’ rate plans;

the intentional misconduct of employees or contractors could adversely affect the Companies;

the failure of, or damage to, the Companies’ facilities could adversely affect the Companies;

a cyber attack could adversely affect the Companies;

the Companies are exposed to risks from the environmental consequences of their operations;

a disruption in the wholesale energy markets or failure by an energy supplier or customer could adversely affect the Companies;

the Companies have substantial unfunded pension and other postretirement benefit liabilities;

Con Edison’s ability to pay dividends or interest depends on dividends from its subsidiaries;

the Companies require access to capital markets to satisfy funding requirements;

changes to tax laws could adversely affect the Companies;

the Companies’ strategies may not be effective to address changes in the external business environment; and

the Companies also face other risks that are beyond their control.

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

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ConsolidatedEdison, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2017	2016	2017	2016
	(Millions of Dollars/ Except Per Share Data)
(Millions of Dollars/Except Share Data)					2019	2018	2019	2018
OPERATING REVENUES
Electric	$2,675	$2,769	$6,573	$6,717	$2,753	$2,783	$6,665	$6,611
Gas	296	235	1,593	1,246	306	298	1,790	1,726
Steam	62	63	448	406	58	64	469	474
Non-utility	178	350	458	999	248	183	699	577
TOTAL OPERATING REVENUES	3,211	3,417	9,072	9,368	3,365	3,328	9,623	9,388
OPERATING EXPENSES
Purchased power	460	798	1,253	2,047	483	545	1,203	1,287
Fuel	30	29	169	133	31	39	163	201
Gas purchased for resale	115	81	584	320	98	164	671	736
Other operations and maintenance	852	840	2,406	2,447	847	797	2,422	2,389
Depreciation and amortization	337	305	998	905	421	360	1,253	1,061
Taxes, other than income taxes	544	528	1,597	1,523	618	597	1,800	1,707
TOTAL OPERATING EXPENSES	2,338	2,581	7,007	7,375	2,498	2,502	7,512	7,381
Gain on sale of retail electric supply business and solar electric production project	—	104	1	104
OPERATING INCOME	873	940	2,066	2,097	867	826	2,111	2,007
OTHER INCOME (DEDUCTIONS)
Investment income	20	20	59	27	25	39	70	96
Other income	20	31	43		10	7	26	18
Allowance for equity funds used during construction	3	3	8	7	4	4	11	11
Other deductions	(4)	(5)	(12)	(16)	(25)	(61)	(76)	(154)
TOTAL OTHER INCOME	39	49	98	61
TOTAL OTHER INCOME (DEDUCTIONS)					14	(11)	31	(29)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	912	989	2,164	2,158	881	815	2,142	1,978
INTEREST EXPENSE
Interest on long-term debt	183	174	539	504	220	195	660	576
Other interest	4	5	11	17	45	13	122	28
Allowance for borrowed funds used during construction	(2)	(1)	(5)	(4)	(3)	(3)	(10)	(7)
NET INTEREST EXPENSE	185	178	545	517	262	205	772	597
INCOME BEFORE INCOME TAX EXPENSE	727	811	1,619	1,641	619	610	1,370	1,381
INCOME TAX EXPENSE	270	314	599	602	116	175	243	330
NET INCOME	$457	$497	$1,020	$1,039	$503	$435	$1,127	$1,051
Income attributable to non-controlling interest					30	—	79	—
NET INCOME FOR COMMON STOCK					$473	$435	$1,048	$1,051
Net income per common share—basic	$1.48	$1.63	$3.33	$3.47	$1.42	$1.40	$3.20	$3.38
Net income per common share—diluted	$1.48	$1.62	$3.31	$3.46	$1.42	$1.39	$3.19	$3.37
DIVIDENDS DECLARED PER COMMON SHARE	$0.69	$0.67	$2.07	$2.01
AVERAGE NUMBER OF SHARES OUTSTANDING—BASIC (IN MILLIONS)	307.8	304.5	306.2	299.1	332.2	311.1	327.3	310.8
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS)	309.3	305.9	307.7	300.5	333.2	312.3	328.3	311.9

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		Three Months Ended September 30,		Nine Months Ended September 30,
	2017	2016	2017	2016
	(Millions of Dollars)
(Millions of Dollars)					2019	2018	2019	2018
NET INCOME	$457	$497	$1,020	$1,039	$503	$435	$1,127	$1,051
INCOME ATTRIBUTABLE TO NON-CONTROLLING INTEREST					(30)	—	(79)	—
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1			2	1	2	6	8
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1			2	1	2	6	8
COMPREHENSIVE INCOME	$458	$498	$1,021	$1,041	$474	$437	$1,054	$1,059

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)


	For the Nine Months Ended September 30,		For the Nine Months Ended September 30,
	2017	2016
	(Millions of Dollars)
(Millions of Dollars)			2019	2018
OPERATING ACTIVITIES
Net income	$1,020	$1,039	$1,127	$1,051
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	998	905	1,253	1,061
Deferred income taxes	626	524	257	308
Rate case amortization and accruals	(93)	(157)	(88)	(85)
Common equity component of allowance for funds used during construction	(8)	(7)	(11)
Net derivative gains	(4)	(7)	55	5
Gain on sale of retail electric supply business and solar electric production project	(1)	(104)
Unbilled revenue and net unbilled revenue deferrals			29	135
Gain on sale of assets			(5)	—
Other non-cash items, net	(1)	99	(25)	(44)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	1	(138)	8	(246)
Materials and supplies, including fuel oil and gas in storage	2	15	—	(4)
Revenue decoupling mechanism receivable			(91)	—
Other receivables and other current assets	(39)	90	103	(31)
Income taxes receivable	33	100
Taxes receivable			39	47
Prepayments	(433)	(403)	(520)	(487)
Accounts payable	(54)	142	(67)	(8)
Pensions and retiree benefits obligations, net	305	464	253	264
Pensions and retiree benefits contributions	(462)	(510)	(353)	(475)
Accrued taxes	(21)	(21)	(27)	(60)
Accrued interest	59	66	95	67
Superfund and environmental remediation costs, net	(9)	68	(8)	(14)
Distributions from equity investments	87	45	46	88
System benefit charge	194	193	9	74
Deferred charges, noncurrent assets and other regulatory assets	(18)	(104)	(238)	(223)
Deferred credits and other regulatory liabilities	(40)	116	144	382
Other current and noncurrent liabilities	85	(79)	(25)	(194)
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,227	2,336	1,960	1,600
INVESTING ACTIVITIES
Utility construction expenditures	(2,148)	(2,057)	(2,428)	(2,457)
Cost of removal less salvage	(185)	(149)	(219)	(188)
Non-utility construction expenditures	(288)	(436)	(143)	(193)
Investments in electric and gas transmission projects	(29)	(1,040)	(159)	(123)
Investments in/acquisitions of renewable electric production projects	(1)	(241)	—	(15)
Proceeds from the transfer of assets to NY Transco	—	122
Proceeds from sale of assets	34	250	48	—
Restricted cash	13	(21)
Other investing activities	32	(145)	17	29
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,572)	(3,717)	(2,884)	(2,947)
FINANCING ACTIVITIES
Net payment of short-term debt	(698)	(928)
Net issuance/(payment) of short-term debt			(1,266)	775
Issuance of long-term debt	997	1,765	1,989	1,905
Retirement of long-term debt	(429)	(407)	(702)	(1,319)
Debt issuance costs	(12)	(16)	(15)	(21)
Common stock dividends	(600)	(570)	(690)	(631)
Issuance of common shares - public offering	343	702	825	—
Issuance of common shares for stock plans	37	38	40	39
Distribution to noncontrolling interest	—	(1)	(10)	—
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	(362)	583
CASH AND TEMPORARY CASH INVESTMENTS:
NET CASH FLOWS FROM FINANCING ACTIVITIES			171	748
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(707)	(798)	(753)	(599)
BALANCE AT BEGINNING OF PERIOD	776	944	1,006	844
BALANCE AT END OF PERIOD	$69	$146	$253	$245
LESS: CHANGE IN CASH BALANCES HELD FOR SALE	—	(4)
BALANCE AT END OF PERIOD EXCLUDING HELD FOR SALE	$69	$150
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$479	$437	$576	$519
Income taxes	$(34)	$(144)	$(28)	$(1)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$352	$242	$328	$318
Issuance of common shares for dividend reinvestment	$35	$35	$36
Software licenses acquired but unpaid as of end of period			$80	$100
Equipment acquired but unpaid as of end of period			$33	—

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)


	September 30, 2017	December 31, 2016
	(Millions of Dollars)
(Millions of Dollars)			September 30, 2019	December 31, 2018
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$69	$776	$78	$895
Accounts receivable – customers, less allowance for uncollectible accounts of $63 and $69 in 2017 and 2016, respectively	1,111	1,106
Other receivables, less allowance for uncollectible accounts of $8 and $14 in 2017 and 2016, respectively	181	195
Income taxes receivable	46	79
Accounts receivable – customers, less allowance for uncollectible accounts of $67 and $62 in 2019 and 2018, respectively			1,254	1,267
Other receivables, less allowance for uncollectible accounts of $5 in 2019 and 2018			169	285
Taxes receivable			10	49
Accrued unbilled revenue	411	447	505	514
Fuel oil, gas in storage, materials and supplies, at average cost	337	339	358	358
Prepayments	592	159	707	187
Regulatory assets	109	100	83	76
Restricted cash	41	54	175	111
Revenue decoupling mechanism			91	—
Other current assets	199	151	151	122
TOTAL CURRENT ASSETS	3,096	3,406	3,581	3,864
INVESTMENTS	1,977	1,921	1,983	1,766
UTILITY PLANT, AT ORIGINAL COST
Electric	28,595	27,747	31,584	30,378
Gas	7,972	7,524	9,879	9,100
Steam	2,458	2,421	2,594	2,562
General	2,891	2,719	3,492	3,331
TOTAL	41,916	40,411	47,549	45,371
Less: Accumulated depreciation	8,904	8,541	10,329	9,769
Net	33,012	31,870	37,220	35,602
Construction work in progress	1,415	1,175	1,963	1,978
NET UTILITY PLANT	34,427	33,045	39,183	37,580
NON-UTILITY PLANT
Non-utility property, less accumulated depreciation of $185 and $140 in 2017 and 2016, respectively	1,686	1,482
Non-utility property, less accumulated depreciation of $357 and $275 in 2019 and 2018, respectively			3,848	4,000
Construction work in progress	615	689	203	169
NET PLANT	36,728	35,216	43,234	41,749
OTHER NONCURRENT ASSETS
Goodwill	428		446	440
Intangible assets, less accumulated amortization of $12 and $6 in 2017 and 2016, respectively	114	124
Intangible assets, less accumulated amortization of $103 and $29 in 2019 and 2018, respectively			1,580	1,654
Regulatory assets	6,769	7,024	4,159	4,294
Operating lease right-of-use asset			834	—
Other deferred charges and noncurrent assets	134	136	123	153
TOTAL OTHER NONCURRENT ASSETS	7,445	7,712	7,142	6,541
TOTAL ASSETS	$49,246	$48,255	$55,940	$53,920

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)


	September 30, 2017	December 31, 2016
	(Millions of Dollars)
(Millions of Dollars)			September 30, 2019	December 31, 2018
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$687	$39	$1,914	$650
Term loan			—	825
Notes payable	356	1,054	1,300	1,741
Accounts payable	1,057	1,147	1,082	1,187
Customer deposits	344	352	348	351
Accrued taxes	43	64	35	61
Accrued interest	209	150	224	129
Accrued wages	105	101	115	109
Fair value of derivative liabilities	70	77	72	50
Regulatory liabilities	58	128	93	114
System benefit charge	628	434	636	627
Operating lease liabilities			59	—
Other current liabilities	358	297	341	363
TOTAL CURRENT LIABILITIES	3,915	3,843	6,219	6,207
NONCURRENT LIABILITIES
Provision for injuries and damages	164	160	139	146
Pensions and retiree benefits	1,443	1,847	810	1,228
Superfund and other environmental costs	745	753	767	779
Asset retirement obligations	256	246	360	450
Fair value of derivative liabilities	83	40	147	16
Deferred income taxes and unamortized investment tax credits	10,744	10,205	6,136	5,820
Operating lease liabilities			819	—
Regulatory liabilities	1,873	1,905	4,590	4,641
Other deferred credits and noncurrent liabilities	262	215	282	299
TOTAL NONCURRENT LIABILITIES	15,570	15,371	14,050	13,379
LONG-TERM DEBT	14,651	14,735	17,537	17,495
EQUITY
Common shareholders’ equity	15,102	14,298	17,959	16,726
Noncontrolling interest	8		175	113
TOTAL EQUITY (See Statement of Equity)	15,110	14,306	18,134	16,839
TOTAL LIABILITIES AND EQUITY	$49,246	$48,255	$55,940	$53,920

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison, Inc.

CONSOLIDATED STATEMENT OF EQUITY (UNAUDITED)



(In Millions, except for dividends per share)	Common Stock		Additional Paid-In Capital	Retained Earnings	Treasury Stock		Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Non- controlling Interest	Total
(In Millions, except for dividends per share)	Shares	Amount	Additional Paid-In Capital	Retained Earnings	Shares	Amount	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Non- controlling Interest	Total
BALANCE AS OF DECEMBER 31, 2017	310	$34	$6,298	$10,235	23	$(1,038)	$(85)	$(26)	$7	$15,425
Net income				428						428
Common stock dividends ($0.715 per share)				(221)						(221)
Issuance of common shares for stock plans	1		25							25
Other comprehensive income								4		4
Noncontrolling interest										—
BALANCE AS OF MARCH 31, 2018	311	$34	$6,323	$10,442	23	$(1,038)	$(85)	$(22)	$7	$15,661
Net income				188						188
Common stock dividends ($0.715 per share)				(223)						(223)
Issuance of common shares for stock plans			27							27
Other comprehensive income								2		2
Noncontrolling interest										—
BALANCE AS OF JUNE 30, 2018	311	$34	$6,350	$10,407	23	$(1,038)	$(85)	$(20)	$7	$15,655
Net income				435						435
Common stock dividends ($0.715 per share)				(223)						(223)
Issuance of common shares for stock plans			25							25
Other comprehensive income								2		2
Noncontrolling interest									4	4
BALANCE AS OF SEPTEMBER 30, 2018	311	$34	$6,375	$10,619	23	$(1,038)	$(85)	$(18)	$11	$15,898
Net income				331						331
Common stock dividends ($0.715 per share)				(222)						(222)
Issuance of common shares - public offering	10		719				(14)			705
Issuance of common shares for stock plans			23							23
Other comprehensive income								2		2
Noncontrolling interest									102	102
BALANCE AS OF DECEMBER 31, 2018	321	$34	$7,117	$10,728	23	$(1,038)	$(99)	$(16)	$113	$16,839
Net income				424					21	445
Common stock dividends ($0.74 per share)				(237)						(237)
Issuance of common shares – public offering	6		433				(8)			425
Issuance of common shares for stock plans			27							27
Other comprehensive income								4		4
Distributions to noncontrolling interest									(2)	(2)
BALANCE AS OF MARCH 31, 2019	327	$34	$7,577	$10,915	23	$(1,038)	$(107)	$(12)	$132	$17,501
Net income				152					27	179
Common stock dividends ($0.74 per share)				(242)						(242)
Issuance of common shares – public offering	5	1	402				(3)			400
Issuance of common shares for stock plans			29							29
Other comprehensive income								1		1
Distributions to noncontrolling interest									(3)	(3)
BALANCE AS OF JUNE 30, 2019	332	$35	$8,008	$10,825	23	$(1,038)	$(110)	$(11)	$156	$17,865
Net income				473					30	503
Common stock dividends ($0.74 per share)				(247)						(247)
Issuance of common shares for stock plans			23							23
Other comprehensive income								1		1
Distributions to noncontrolling interest									(11)	(11)
BALANCE AS OF SEPTEMBER 30, 2019	332	$35	$8,031	$11,051	23	$(1,038)	$(110)	$(10)	$175	$18,134

(In Millions) Common Stock Additional
Paid-In
Capital Retained
Earnings Treasury Stock Capital
Stock
Expense Accumulated
Other
Comprehensive
Income/(Loss) Noncontrolling
Interest Total
Shares Amount Shares Amount
BALANCE AS OF
DECEMBER 31, 2015 293 $32 $5,030 $9,123 23 $(1,038) $(61) $(34) $9 $13,061
Net income 310 310
Common stock dividends (197) (197)
Issuance of common shares for stock plans 1 28 28
Other comprehensive income
—
Noncontrolling interest (1) (1)
BALANCE AS OF
MARCH 31, 2016 294 $32 $5,058 $9,236 23 $(1,038) $(61) $(34) $8 $13,201
Net income 232 232
Common stock dividends (204) (204)
Issuance of common shares - public offering 10 1 723 (22) 702
Issuance of common shares for stock plans
26 26
Other comprehensive income 1 1
BALANCE AS OF
JUNE 30, 2016 304 $33 $5,807 $9,264 23 $(1,038) $(83) $(33) $8 $13,958
Net income 497 497
Common stock dividends (204) (204)
Issuance of common shares for stock plans 1
23 23
Other comprehensive income 1 1
BALANCE AS OF
SEPTEMBER 30, 2016 305 $33 $5,830 $9,557 23 $(1,038) $(83) $(32) $8 $14,275

BALANCE AS OF DECEMBER 31, 2016 305 $33 $5,854 $9,559 23 $(1,038) $(83) $(27) $8 $14,306
Net income 388 388
Common stock dividends (211) (211)
Issuance of common shares for stock plans 24 24
Other comprehensive loss (1) (1)
BALANCE AS OF
MARCH 31, 2017 305 $33 $5,878 $9,736 23 $(1,038) $(83) $(28) $8 $14,506
Net income 175 175
Common stock dividends (210) (210)
Issuance of common shares for stock plans 1 26 26
Other comprehensive income 1 1
BALANCE AS OF
JUNE 30, 2017 306 $33 $5,904 $9,701 23 $(1,038) $(83) $(27) $8 $14,498
Net income 457 457
Common stock dividends (214) (214)
Issuance of common shares - public offering 4
345 (2) 343
Issuance of common shares for stock plans

25 25
Other comprehensive income 1 1
BALANCE AS OF
SEPTEMBER 30, 2017 310 $33 $6,274 $9,944 23 $(1,038) $(85) $(26) $8 $15,110

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		For the Three Months Ended September 30,		For the Nine Months Ended September 30,
	2017	2016	2017	2016
	(Millions of Dollars)
(Millions of Dollars)					2019	2018	2019	2018
OPERATING REVENUES
Electric	$2,469	$2,557	$6,079	$6,222	$2,544	$2,571	$6,174	$6,107
Gas	268	208	1,421	1,113	275	264	1,605	1,540
Steam	62	63	448	406	58	64	469	474
TOTAL OPERATING REVENUES	2,799	2,828	7,948	7,741	2,877	2,899	8,248	8,121
OPERATING EXPENSES
Purchased power	400	495	1,110	1,216	423	472	1,058	1,117
Fuel	30	29	169	133	31	39	163	201
Gas purchased for resale	58	34	372	217	52	66	445	457
Other operations and maintenance	691	724	1,992	2,105	712	666	2,022	1,926
Depreciation and amortization	300	278	891	825	346	322	1,020	949
Taxes, other than income taxes	520	502	1,523	1,446	590	570	1,715	1,621
TOTAL OPERATING EXPENSES	1,999	2,062	6,057	5,942	2,154	2,135	6,423	6,271
OPERATING INCOME	800	766	1,891	1,799	723	764	1,825	1,850
OTHER INCOME (DEDUCTIONS)
Investment and other income	2	4	9	6	10	6	23	14
Allowance for equity funds used during construction	3	2	7	6	3	4	9	10
Other deductions	(5)	(4)	(10)		(22)	(43)	(63)	(123)
TOTAL OTHER INCOME	—	2	6	2
TOTAL OTHER INCOME (DEDUCTIONS)					(9)	(33)	(31)	(99)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	800	768	1,897	1,801	714	731	1,794	1,751
INTEREST EXPENSE
Interest on long-term debt	155	150	456	440	168	167	501	492
Other interest	4	5	11	14	16	10	52	23
Allowance for borrowed funds used during construction	(2)	(1)	(4)	(3)	(3)	(2)	(8)	(7)
NET INTEREST EXPENSE	157	154	463	451	181	175	545	508
INCOME BEFORE INCOME TAX EXPENSE	643	614	1,434	1,350	533	556	1,249	1,243
INCOME TAX EXPENSE	242	226	551	491	119	125	271	274
NET INCOME	$401	$388	$883	$859	$414	$431	$978	$969

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME (UNAUDITED)


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		Three Months Ended September 30,		Nine Months Ended September 30,
	2017	2016	2017	2016
	(Millions of Dollars)
(Millions of Dollars)					2019	2018	2019	2018
NET INCOME	$401	$388	$883	$859	$414	$431	$978	$969
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	—	1		1	—	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	—	1		1	—	1
COMPREHENSIVE INCOME	$402	$388	$884	$860	$415	$431	$979	$970

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF CASH FLOWS (UNAUDITED)


	For the Nine Months Ended September 30,		For the Nine Months Ended September 30,
	2017	2016
	(Millions of Dollars)
(Millions of Dollars)			2019	2018
OPERATING ACTIVITIES
Net income	$883	$859	$978	$969
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	891	825	1,020	949
Deferred income taxes	566	569	244	346
Rate case amortization and accruals	(107)	(170)	(87)	(98)
Common equity component of allowance for funds used during construction	(7)	(6)	(9)	(10)
Unbilled revenue and net unbilled revenue deferrals			38	43
Gain on sale of assets			(5)	—
Other non-cash items, net	(14)	7	(19)	(20)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	18	(79)	(2)	(218)
Materials and supplies, including fuel oil and gas in storage	(18)	15	9	(3)
Revenue decoupling mechanism			(91)	—
Other receivables and other current assets	29	18	107	(47)
Accounts receivable from affiliated companies	12	38	14	(267)
Prepayments	(398)	(351)	(499)	(448)
Accounts payable	(20)	82	(92)	(32)
Accounts payable to affiliated companies	1	8	(4)	8
Pensions and retiree benefits obligations, net	274	439	237	242
Pensions and retiree benefits contributions	(416)	(472)	(322)	(436)
Superfund and environmental remediation costs, net	(7)	76	(10)	(14)
Accrued taxes	(18)	(17)	(23)	(63)
Accrued taxes to affiliated companies	(119)	(2)	—	(72)
Accrued interest	61	43	68	67
System benefit charge	175	176	9	70
Deferred charges, noncurrent assets and other regulatory assets	(60)	(153)	(248)	(158)
Deferred credits and other regulatory liabilities	77	165	184	376
Other current and noncurrent liabilities	(13)	(53)	(7)	(99)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,790	2,017	1,490	1,085
INVESTING ACTIVITIES
Utility construction expenditures	(2,020)	(1,932)	(2,271)	(2,315)
Cost of removal less salvage	(179)	(146)	(214)	(183)
Proceeds from the transfer of assets to NY Transco	—	122
Restricted cash	2	13
Proceeds from sale of assets			48	—
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,197)	(1,943)	(2,437)	(2,498)
FINANCING ACTIVITIES
Net payment of short-term debt	(453)	(553)
Net issuance/(payment) of short-term debt			(262)	854
Issuance of long-term debt	500	550	700	1,640
Retirement of long-term debt	—	(400)	(475)	(1,236)
Debt issuance costs	(7)	(6)	(9)	(18)
Capital contribution by parent	279	76	875	95
Dividend to parent	(597)	(558)	(685)	(635)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(278)	(891)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CASH FLOWS FROM FINANCING ACTIVITIES			144	700
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(685)	(817)	(803)	(713)
BALANCE AT BEGINNING OF PERIOD	702	843	818	730
BALANCE AT END OF PERIOD	$17	$26	$15	$17
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$388	$386	$439	$424
Income taxes	$96	$(130)	$13	$268
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$240	$195	$295	$279
Software licenses acquired but unpaid as of end of period			$76	$95
Equipment acquired but unpaid as of end of period			$33	—

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)


	September 30, 2017	December 31, 2016
	(Millions of Dollars)
(Millions of Dollars)			September 30, 2019	December 31, 2018
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$17	$702	$15	$818
Accounts receivable – customers, less allowance for uncollectible accounts of $58 and $65 in 2017 and 2016, respectively	1,021	1,032
Other receivables, less allowance for uncollectible accounts of $7 and $13 in 2017 and 2016, respectively	85	81
Accounts receivable – customers, less allowance for uncollectible accounts of $62 and $57 in 2019 and 2018, respectively			1,160	1,163
Other receivables, less allowance for uncollectible accounts of $3 in 2019 and 2018			104	211
Taxes receivable			—	5
Accrued unbilled revenue	382	399	374	392
Accounts receivable from affiliated companies	97	109	200	214
Fuel oil, gas in storage, materials and supplies, at average cost	288	270	295	304
Prepayments	498	100	616	117
Regulatory assets	100	90	69	64
Restricted cash	—	2
Revenue decoupling mechanism receivable			91	—
Other current assets	62	95	81	69
TOTAL CURRENT ASSETS	2,550	2,880	3,005	3,357
INVESTMENTS	370	315	436	385
UTILITY PLANT, AT ORIGINAL COST
Electric	26,930	26,122	29,736	28,595
Gas	7,229	6,814	9,012	8,295
Steam	2,458	2,421	2,594	2,562
General	2,640	2,490	3,201	3,056
TOTAL	39,257	37,847	44,543	42,508
Less: Accumulated depreciation	8,170	7,836	9,504	8,988
Net	31,087	30,011	35,039	33,520
Construction work in progress	1,327	1,104	1,843	1,850
NET UTILITY PLANT	32,414	31,115	36,882	35,370
NON-UTILITY PROPERTY
Non-utility property, less accumulated depreciation of $25 in 2017 and 2016	4	4
Non-utility property, less accumulated depreciation of $25 in 2019 and 2018			3	4
NET PLANT	32,418	31,119	36,885	35,374
OTHER NONCURRENT ASSETS
Regulatory assets	6,248	6,473	3,831	3,923
Operating lease right-of-use asset			610	—
Other deferred charges and noncurrent assets	61	69	41	69
TOTAL OTHER NONCURRENT ASSETS	6,309	6,542	4,482	3,992
TOTAL ASSETS	$41,647	$40,856	$44,808	$43,108

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED BALANCE SHEET (UNAUDITED)


	September 30, 2017	December 31, 2016
	(Millions of Dollars)
(Millions of Dollars)				September 30, 2019	December 31, 2018
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$600		$—	$350	$475
Notes payable	147	600		930	1,192
Accounts payable	802	876		883	977
Accounts payable to affiliated companies	11	10		13	17
Customer deposits	332	336		335	339
Accrued taxes	32	50		33	55
Accrued taxes to affiliated companies	—	119
Accrued interest	172	111		180	112
Accrued wages	95	91		104	99
Fair value of derivative liabilities	59	66		33	25
Regulatory liabilities	38	90		56	73
System benefit charge	573	398		578	569
Operating lease liabilities				49	—
Other current liabilities	207	242		269	267
TOTAL CURRENT LIABILITIES	3,068	2,989		3,813	4,200
NONCURRENT LIABILITIES
Provision for injuries and damages	158	154		135	141
Pensions and retiree benefits	1,150	1,544		577	952
Superfund and other environmental costs	648	655		684	693
Asset retirement obligations	234	227		301	292
Fair value of derivative liabilities	73	33		82	6
Deferred income taxes and unamortized investment tax credits	10,060	9,450		6,082	5,739
Operating lease liabilities				595	—
Regulatory liabilities	1,673	1,712		4,200	4,258
Other deferred credits and noncurrent liabilities	217	190		236	241
TOTAL NONCURRENT LIABILITIES	14,213	13,965		12,892	12,322
LONG-TERM DEBT	11,971	12,073		14,024	13,676
SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	12,395	11,829		14,079	12,910
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$41,647	$40,856		$44,808	$43,108

The accompanying notes are an integral part of these financial statements.

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Consolidated Edison Company of New York, Inc.

CONSOLIDATED STATEMENT OF SHAREHOLDER’S EQUITY (UNAUDITED)


	Common Stock		Additional Paid-In Capital	Retained Earnings	Repurchased Con Edison Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Total	Common Stock		Additional Paid-In Capital	Retained Earnings	Repurchased Con Edison Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Total
(In Millions)	Shares	Amount
BALANCE AS OF DECEMBER 31, 2015	235	$589	$4,247	$7,611	$(962)	$(61)	$(9)	$11,415
(In Millions, except for dividends per share)									Shares	Amount	Additional Paid-In Capital	Retained Earnings	Repurchased Con Edison Stock	Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Total
BALANCE AS OF DECEMBER 31, 2017									235	$589
Net income				310				310				389				389
Common stock dividend to parent				(186)				(186)				(211)				(211)
Capital contribution by parent			23					23			45					45
Other comprehensive income							—	—								—
BALANCE AS OF MARCH 31, 2016	235	$589	$4,270	$7,735	$(962)	$(61)	$(9)	$11,562
BALANCE AS OF MARCH 31, 2018									235	$589	$4,694	$8,409	$(962)	$(62)	$(6)	$12,662
Net income				161				161				149				149
Common stock dividend to parent				(186)				(186)				$(212)				(212)
Capital contribution by parent			28					28			25					25
Other comprehensive income							1								1	1
BALANCE AS OF JUNE 30, 2016	235	$589	$4,298	$7,710	$(962)	$(61)	$(8)	$11,566
BALANCE AS OF JUNE 30, 2018									235	$589	$4,719	$8,346	$(962)	$(62)	$(5)	$12,625
Net income				388				388				$431				431
Common stock dividend to parent				(186)				(186)				(212)				(212)
Capital contribution by parent			25					25			25					25
Other comprehensive income							—	—								—
BALANCE AS OF SEPTEMBER 30, 2016	235	$589	$4,323	$7,912	$(962)	$(61)	$(8)	$11,793

BALANCE AS OF DECEMBER 31, 2016	235	$589	$4,347	$7,923	$(962)	$(61)	$(7)	$11,829
BALANCE AS OF SEPTEMBER 30, 2018									235	$589	$4,744	$8,565	$(962)	$(62)	$(5)	$12,869
Net income				339				339				227				227
Common stock dividend to parent				(199)				(199)				(211)				(211)
Capital contribution by parent			22					22			25					25
Other comprehensive income							—	—								—
BALANCE AS OF MARCH 31, 2017	235	$589	$4,369	$8,063	$(962)	$(61)	$(7)	$11,991
BALANCE AS OF DECEMBER 31, 2018									235	$589	$4,769	$8,581	$(962)	$(62)	$(5)	$12,910
Net income				143				143				412				412
Common stock dividend to parent				(199)				(199)				(228)				(228)
Capital contribution by parent			23					23			225					225
Other comprehensive income							—	—								—
BALANCE AS OF JUNE 30, 2017	235	$589	$4,392	$8,007	$(962)	$(61)	$(7)	$11,958
BALANCE AS OF MARCH 31, 2019									235	$589	$4,994	$8,765	$(962)	$(62)	$(5)	$13,319
Net income				401				401				152				152
Common stock dividend to parent				(199)				(199)				(228)				(228)
Capital contribution by parent			235			(1)		234			625					625
Other comprehensive income							1									—
BALANCE AS OF SEPTEMBER 30, 2017	235	$589	$4,627	$8,209	$(962)	$(62)	$(6)	$12,395
BALANCE AS OF JUNE 30, 2019									235	$589	$5,619	$8,689	$(962)	$(62)	$(5)	$13,868
Net income												414				414
Common stock dividend to parent												(229)				(229)
Capital contribution by parent											25					25
Other comprehensive income															1	1
BALANCE AS OF SEPTEMBER 30, 2019									235	$589	$5,644	$8,874	$(962)	$(62)	$(4)	$14,079

The accompanying notes are an integral part of these financial statements.

Table of Contents

NOTES TO THE FINANCIAL STATEMENTS (UNAUDITED)

General

These combined notes accompany and form an integral part of the separate consolidated financial statements of each of the ~~two~~2 separate registrants: Consolidated Edison, Inc. and its subsidiaries (Con Edison) and Consolidated Edison Company of New York, Inc. and its subsidiaries (CECONY). CECONY is a subsidiary of Con Edison and as such its financial condition and results of operations and cash flows, which are presented separately in the CECONY consolidated financial statements, are also consolidated, along with those of Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. (together with its subsidiaries, the Clean Energy Businesses) and Con Edison Transmission, Inc. (together with its subsidiaries, Con Edison Transmission) in Con Edison’s consolidated financial statements. The term “Utilities” is used in these notes to refer to CECONY and O&R.

As used in these notes, the term “Companies” refers to Con Edison and CECONY and, except as otherwise noted, the information in these combined notes relates to each of the Companies. However, CECONY makes no representation as to information relating to Con Edison or the subsidiaries of Con Edison other than itself.

The separate interim consolidated financial statements of each of the Companies are unaudited but, in the opinion of their respective managements, reflect all adjustments (which include only normally recurring adjustments) necessary for a fair presentation of the results for the interim periods presented. The Companies’ separate interim consolidated financial statements should be read together with their separate audited financial statements (including the combined notes thereto) included in Item 8 of their combined Annual Report on Form 10-K for the year ended December 31, ~~2016~~2018 and their separate unaudited financial statements (including the combined notes thereto) included in Part 1, Item 1 of their combined Quarterly Report on Form 10-Q for the quarterly periods ended March 31, ~~2017~~2019 and June 30, ~~2017. Certain prior period amounts have been reclassified to conform to the current period presentation.~~2019.

Con Edison has ~~two~~2 regulated utility subsidiaries: CECONY and O&R. CECONY provides electric service and gas service in New York City and Westchester County. The company also provides steam service in parts of Manhattan. O&R, along with its regulated utility subsidiary, provides electric service in southeastern New York and northern New Jersey and gas service in southeastern New York. Con Edison Clean Energy Businesses, Inc. has ~~three~~3 subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), a company that develops, owns and operates renewable and energy infrastructure projects; Consolidated Edison Energy, Inc. (Con Edison Energy), a company that provides energy-related products and services to wholesale customers; and Consolidated Edison Solutions, Inc. (Con Edison Solutions), a company that provides energy-related products and services to retail customers. Con Edison Transmission, Inc. invests in electric transmission facilities through its subsidiary, Consolidated Edison Transmission, LLC (CET Electric), and invests in gas pipeline and storage facilities through its subsidiary Con Edison Gas Pipeline and Storage, LLC (CET Gas).

Note A – Summary of Significant Accounting Policies and Other Matters

Revenue Recognition

The following table presents, for the three and nine months ended 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.

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	For the Three Months Ended September 30, 2019				For the Three Months Ended September 30, 2018
(Millions of Dollars)	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)		Total operating revenues
CECONY
Electric	$2,582		$(38)	$2,544	$2,631		$(60)		$2,571
Gas	263		12	275	264		—		264
Steam	54		4	58	64		—		64
Total CECONY	$2,899		$(22)	$2,877	$2,959		$(60)		$2,899
O&R
Electric	205		5	210	215		(3)		212
Gas	25		6	31	31		3		34
Total O&R	$230		$11	$241	$246			$—	$246
Clean Energy Businesses
Renewables	193	(b)	—	193	68	(b)	—		68
Energy services	14		—	14	24		—		24
Other	—		40	40	—		89		89
Total Clean Energy Businesses	$207		$40	$247	$92		$89		$181
Con Edison Transmission	1		—	1	1		—		1
Other (c)	—		(1)	(1)	—		1		1
Total Con Edison	$3,337		$28	$3,365	$3,298		$30		$3,328

(a) For the Utilities, this includes revenue from alternative revenue programs, such as the revenue decoupling mechanisms under their New York electric and gas rate plans.For the Clean Energy Businesses, this includes revenue from wholesale services.

(b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $3 millionfor the three months ended September 30, 2019 and 2018, of revenue related to engineering, procurement and construction services.


(c)	Parent company and consolidation adjustments.



	For the Nine Months Ended September 30, 2019				For the Nine Months Ended September 30, 2018
(Millions of Dollars)	Revenues from contracts with customers		Other revenues (a)	Total operating revenues	Revenues from contracts with customers		Other revenues (a)	Total operating revenues
CECONY
Electric	$6,048		$126	$6,174	$6,106		$1	$6,107
Gas	1,573		32	1,605	1,516		24	1,540
Steam	456		13	469	467		7	474
Total CECONY	$8,077		$171	$8,248	$8,089		$32	$8,121
O&R
Electric	488		5	493	508		(3)	505
Gas	178		7	185	179		7	186
Total O&R	$666		$12	$678	$687		$4	$691
Clean Energy Businesses
Renewables	465	(b)	—	465	273	(b)	—	273
Energy services	53		—	53	65		—	65
Other	—		178	178	—		235	235
Total Clean Energy Businesses	$518		$178	$696	$338		$235	$573
Con Edison Transmission	3		—	3	3		—	3
Other (c)	—		(2)	(2)	—		—	—
Total Con Edison	$9,264		$359	$9,623	$9,117		$271	$9,388

(b) Included within the totals for Renewables revenue at the Clean Energy Businesses is $9 millionand $100 millionfor the nine months ended September 30, 2019 and 2018, respectively, of revenue related to engineering, procurement and construction services.


(c)	Parent company and consolidation adjustments.

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	2019			2018
(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)		Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1,	$29	$20		$58	$87
Additions (c)	63	2		111	34
Subtractions (c)	68	2	(d)	138	105	(d)
Ending balance as of September 30,	$24	$20		$31	$16

(a)

Unbilled contract revenue represents accumulated incurred costs and earned profits on contracts (revenue arrangements), which have been recorded as revenue, but have not yet been billed to customers, and which represent contract assets as defined in Topic 606. Substantially all accrued unbilled contract revenue is expected to be collected within one year. Unbilled contract revenue arises from the cost-to-cost method of revenue recognition. Unbilled contract revenue from fixed-price type contracts is converted to billed receivables when amounts are invoiced to customers according to contractual billing terms, which generally occur when deliveries or other performance milestones are completed.


(b)	Unearned revenue represents a liability for billings to customers in excess of earned revenue, which are contract liabilities as defined in Topic 606.


(c)	Additions for unbilled contract revenue and subtractions for unearned revenue represent additional revenue earned. Additions for unearned revenue and subtractions for unbilled contract revenue represent billings. Activity also includes appropriate balance sheet classification for the period.


(d)	Of the subtractions from unearned revenue, $2 million and $50 million were included in the balance as of January 1, 2019 and 2018, respectively.

As of 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 $89 million, of which $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.

Utility Plant

General utility plant of Con Edison and CECONY included $95 million and $90 million, respectively, at September 30, 2019 and $100 million and $95 million, respectively, at December 31, 2018, related to a May 2018 acquisition of software licenses. The estimated aggregate annual amortization expense related to the software licenses for Con Edison and CECONY is $7 million. The accumulated amortization for Con Edison and CECONY was $8 million at September 30, 2019 and was $3 million at December 31, 2018.

Long-Lived and Intangible Assets

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) (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 delay 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 issued orders (which PG&E is challenging) 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.

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In July 2019, California enacted a law addressing future California wildfires. The law includes provisions for the establishment of wildfire liquidity and insurance funds and possible limitation of future wildfire liabilities for California utilities. PG&E, Southern California Edison Company and San Diego Gas & Electric Company have agreed to participate in the insurance fund. PG&E’s participation will require bankruptcy court approval and is conditioned on, among other things, resolution of PG&E’s bankruptcy by June 30, 2020, and a determination by the CPUC that PG&E’s bankruptcy reorganization plan is consistent with the state’s climate goals as required under the California Renewables Portfolio Standard Program and related procurement requirements of the state.

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 September 30, 2019, Con Edison’s consolidated balance sheet included $827 million of net non-utility plant relating to the PG&E Projects, $1,075 million of intangible assets relating to the PG&E PPAs, $287 million of net non-utility plant of additional projects that secure the related project debt and $1,012 million of non-recourse related project debt. See 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.

Acquisitions and Investments

For the nine months ended September 2019, the Clean Energy Businesses reclassified approximately $100 million related to the purchase price adjustments for the December 2018 acquisition by a Con Edison Development subsidiary of Sempra Solar Holdings, LLC. The adjustments primarily decreased property, plant and equipment and asset retirement obligations, and were recorded within the one year available to finalize the purchase price allocation, including working capital and other closing adjustments.

Earnings Per Common Share

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”~~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 ~~and stock options~~ 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).

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For the three and nine months ended September 30, ~~2017~~2019 and ~~2016,~~2018, basic and diluted EPS for Con Edison are calculated as follows:

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For the Three Months Ended September 30, For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions) 2017 2016 2017 2016
Net income $457 $497 $1,020 $1,039
Weighted average common shares outstanding – basic 307.8 304.5 306.2 299.1
Add: Incremental shares attributable to effect of potentially dilutive securities 1.5 1.4 1.5 1.4
Adjusted weighted average common shares outstanding – diluted 309.3 305.9 307.7 300.5
Net Income per common share – basic $1.48 $1.63 $3.33 $3.47
Net Income per common share – diluted $1.48 $1.62 $3.31 $3.46



	For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2019	2018	2019	2018
Net income for common stock	$473	$435	$1,048	$1,051
Weighted average common shares outstanding – basic	332.2	311.1	327.3	310.8
Add: Incremental shares attributable to effect of potentially dilutive securities	1.0	1.2	1.0	1.1
Adjusted weighted average common shares outstanding – diluted	333.2	312.3	328.3	311.9
Net Income per common share – basic	$1.42	$1.40	$3.20	$3.38
Net Income per common share – diluted	$1.42	$1.39	$3.19	$3.37

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

Changes in Accumulated Other Comprehensive Income/(Loss) by Component

For the three and nine months ended September 30, ~~2017~~2019 and ~~2016,~~2018, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:



	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Beginning balance, accumulated OCI, net of taxes (a)	$(11)	$(20)	$(5)	$(5)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2019 and 2018 (a)(b)	1	2	1	—
Current period OCI, net of taxes	1	2	1	—
Ending balance, accumulated OCI, net of taxes	$(10)	$(18)	$(4)	$(5)

For the Three Months Ended September 30,
Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Beginning balance, accumulated OCI, net of taxes (a) $(27) $(33) $(7) $(8)
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2017 and 2016 (a)(b) 1 1 1 —
Current period OCI, net of taxes 1 1 1 —
Ending balance, accumulated OCI, net of taxes $(26) $(32) $(6) $(8)


	For the Nine Months Ended September 30,				For the Nine Months Ended September 30,
	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2019	2018	2019	2018
Beginning balance, accumulated OCI, net of taxes (a)	$(27)	$(34)	$(7)	$(9)	$(16)	$(26)	$(5)	$(6)
OCI before reclassifications, net of tax of $1 for Con Edison in 2017 and 2016	(2)	(1)	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(2) for Con Edison in 2017 and 2016 (a)(b)	3		1	1
OCI before reclassifications, net of tax of $(1) for Con Edison in 2019 and 2018					2	3	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) and $(2) for Con Edison in 2019 and 2018, respectively (a)(b)					4	5	1	1
Current period OCI, net of taxes	1	2	1	1	6	8	1	1
Ending balance, accumulated OCI, net of taxes	$(26)	$(32)	$(6)	$(8)	$(10)	$(18)	$(4)	$(5)


(a)	Tax reclassified from accumulated OCI is reported in the income tax expense line item of the consolidated income statement.


(b)	For the portion of unrecognized pension and other postretirement benefit costs relating to the Utilities, costs are recorded into, and amortized out of, regulatory assets instead of OCI. The net actuarial losses and prior service costs recognized during the period are included in the computation of total periodic pension and other postretirement benefit cost. See Notes E and F.

Reconciliation of Cash, Temporary Cash Investments and Restricted Cash

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



	At September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Cash and temporary cash investments	$78	$199	$15	$17
Restricted cash (a)	175	46	—	—
Total cash, temporary cash investments and restricted cash	$253	$245	$15	$17

(a)

Restricted cash included cash of Con Edison Development renewable electric production project subsidiaries ($174 million and $44 million at September 30, 2019 and 2018, respectively) that, under the related project debt agreements, is either restricted until the various maturity dates of the project debt to being used for normal operating expenses and capital expenditures, debt service, and required reserves or

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restricted as a result of the PG&E bankruptcy. During the pendency of the PG&E bankruptcy, unless the lenders for the related project debt otherwise agree, cash may not be distributed from the related projects to Con Edison Development. See “Long-Lived and Intangible Assets,” above, and Note C. In addition, restricted cash included O&R's New Jersey utility subsidiary, Rockland Electric Company transition bond charge collections, net of principal, interest, trustee and service fees ($1 million and $2 million at September 30, 2019 and 2018, respectively).

Note B —– Regulatory Matters

Rate Plans

~~Rockland Electric Company (RECO)~~

In ~~February 2017,~~October 2019, CECONY, the staff of the New ~~Jersey Board of~~York State Public ~~Utilities (NJBPU) approved~~Service Commission (NYSPSC) and other parties entered into a ~~stipulation of settlement~~Joint Proposal for ~~a RECO~~CECONY electric and gas rate ~~plan commencing March 2017.~~plans for the three-year period January 2020 through December 2022. The Joint Proposal is subject to NYSPSC approval. The following ~~table contains~~tables contain a summary of the ~~electric~~ rate ~~plan.~~plans.



~~RECO~~CECONY Electric
Effective period		~~March 2017 (a)~~January 2020 – December 2022 (c)
Base rate changes (a)		Yr. 1 ~~- $1.7~~– $113 million Yr. 2 – $370 million Yr. 3 – $326 million
~~Amortization~~Amortizations to income of net regulatory ~~(assets) and~~ liabilities (b)		~~$0.2~~Yr. 1 – $267 million ~~over three years and continuation~~ Yr. 2 – $269 million Yr. 3 – $272 million
Other revenue sources		Retention of ~~$(25.6)~~$75 million of ~~deferred storm costs over four years expiring July 31, 2018 (b)~~annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $69 million; Yr. 2 - $74 million; and Yr. 3 - $79 million.
Revenue decoupling mechanism		Continuation of reconciliation of actual to authorized electric delivery revenues.
Recoverable energy costs		~~Current~~Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments		Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million; Yr. 2 - $461 million; and Yr. 3 - $476 million.
Cost reconciliations		~~None~~Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (f)
Net utility plant reconciliations		Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,572 million; Yr. 2 - $25,366 million; Yr. 3 - $26,197 million AMI: Yr. 1 - $572 million; Yr. 2 - $740 million; Yr. 3 - $806 million (g)
Average rate base		Yr. 1 - ~~$178.7~~$21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million
Weighted average cost of capital (after-tax)		~~7.47~~6.61 percent
Authorized return on common equity		~~9.6~~8.80 percent
Earnings sharing		Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt		~~5.37~~4.63 percent
Common equity ratio		~~49.7~~48 percent

(a)

~~Effective until a new rate plan approved~~Base rates reflect recovery by the ~~NJBPU goes into effect.~~company of certain costs of its energy efficiency, Reforming the Energy Vision demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(b)

~~In January 2016,~~Amounts reflect amortization of the ~~NJBPU approved RECO’s plan~~2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to ~~spend $15.7~~CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a 5-year period ($48 million annually).


(c)	If at the end of any semi-annual period ending June 30 and December 31, Consolidated Edison Inc.’s investments in its non-utility businesses exceed 15 percent of its total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total

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consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures are not necessary.


(d)	Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points.

(e)

In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain exceptions, of 15 percent of the amount reflected in rates.


(f)	In addition, the NYSPSC staff has commenced a focused operations audit to investigate the income tax accounting of CECONY and other New York utilities. Any NYSPSC-ordered adjustment to CECONY’s income tax accounting will be refunded to or collected from customers, as determined by the NYSPSC.


(g)	Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas.



CECONY Gas
Effective period		January 2020 – December 2022 (c)
Base rate changes (a)		Yr. 1 – $84 million Yr. 2 – $122 million Yr. 3 – $167 million
Amortizations to income of net regulatory liabilities (b)		Yr. 1 – $45 million Yr. 2 – $43 million Yr. 3 – $10 million
Other revenue sources		Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to Yr. 1 - $20 million; Yr. 2 - $22 million; and Yr. 3 - $25 million
Revenue decoupling mechanism		Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer.
Recoverable energy costs		Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments		Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $81 million; Yr. 2 - $88 million; and Yr. 3 - $96 million.
Cost reconciliations		Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (f)
Net utility plant reconciliations		Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 - $8,123 million; Yr. 2 - $8,861 million; Yr. 3 - $9,600 million AMI: Yr. 1 - $142 million; Yr. 2 - $183 million; Yr. 3 - $211 million (g)
Average rate base		Yr. 1 - $7,171 million Yr. 2 - $7,911 million Yr. 3 - $8,622 million
Weighted average cost of capital ~~over three years~~(after-tax)		6.61 percent
Authorized return on common equity		8.80 percent
Earnings sharing		Most earnings above an annual earnings threshold of 9.3 percent are to ~~harden its electric system against storms,~~be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt		4.63 percent
Common equity ratio		48 percent

(a)

At the NYSPSC’s option, the gas base rate increases shown above may be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3. Base rates reflect recovery by the company of certain costs of ~~which RECO, beginning~~its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(b)

Amounts reflect amortization of the remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in ~~2017, is collecting through a customer surcharge.~~Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually)


(c)-(g)	See footnotes (c), (d), (e), (f) and (g) to the table under “CECONY Electric,” above.

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O&R New York – Electric and Gas

In ~~September 2017, RECO,~~March 2019, the NYSPSC approved the November 2018 Joint Proposal for new electric and gas rates. The Joint 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 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, respectively.

Rockland Electric Company (RECO)

In October 2019, the New Jersey Division of Rate Counsel ~~and~~staff submitted testimony in the New Jersey Board of Public Utilities ~~entered into a settlement agreement,~~proceeding in which ~~is subject to FERC approval, that increases RECO's annual transmission revenue requirement from $11.8~~RECO requested an electric rate increase, effective February 2020. The Division of Rate Counsel staff testimony supports an electric rate increase of $5.8 million ~~to $17.7 million, effective April 2017. The revenue requirement reflects a~~reflecting, among other things, an 8.9 percent return on common equity and a common equity ratio of ~~10.0~~47.14 percent. In October 2019, RECO filed an update to the request it filed in May 2019. The company increased its requested February 2020 rate increase from $19.9 million to $20.3 million. The updated filing reflects an increase to the common equity ratio from 49.93 percent to 50.16 percent and a decrease in the return on common equity from 10.00 percent to 9.60 percent.

Other Regulatory Matters

OnIn August ~~16,~~and November 2017, the ~~New York State Public Service Commission (NYSPSC)~~NYSPSC issued ~~an order~~orders in its proceeding investigating an April 21, 2017 Metropolitan Transportation Authority (MTA) subway power outage. The ~~order~~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 ~~order~~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 ~~order,~~orders, the company iswas required to take certain actions, including ~~performing inspections of~~inspecting, repairing and installing certain electrical equipment that serves the ~~MTA~~subway system, analyzing power supply and power quality events affecting the MTA’s signaling services, ~~providing new monitoring and other equipment~~ and filing monthly reports with the NYSPSC on all of the company's activities related to the ~~MTA~~subway system. The company completed the required actions in 2018. The company’s costs related to this matter in excess of those reflected in its current electric rate plan were deferred as a regulatory asset and are addressed in the October 2019 Joint Proposal (see footnote (b) to the CECONY - Electric table under “Rate Plans,” above).

In ~~July 2017,~~August 2018, the ~~Chairman~~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 ~~NYSPSC notified~~federal Tax Cuts and Jobs Act of 2017 (TCJA) as measured based on amounts reflected in its rate plans prior to the ~~company that the April 21, 2017 subway power outage incident will likely result in a prudence review~~enactment of the ~~reasonableness~~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 are addressed in the October 2019 Joint Proposal (see footnote (b) to the 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 being 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 steam customers ($185 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 next steam rate proceeding).

In January 2018, the NYSPSC issued an order initiating a focused operations audit of the income tax accounting of certain utilities, including CECONY and O&R. The Utilities are unable to estimate the amount or range of their possible loss related to this matter. At September 30, 2019, the Utilities had not accrued a liability related to this matter.

In March 2018, Winter Storms Riley and Quinn caused damage to the Utilities’ electric distribution systems and interrupted service to approximately 209,000 CECONY customers, 93,000 O&R customers and 44,000 RECO customers. At September 30, 2019, CECONY's ~~actions~~costs related to March 2018 storms, including Riley and ~~conduct.~~Quinn, amounted to $134 million, including operation and maintenance expenses reflected in its electric rate plan ($15 million), operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan

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($84 million), capital expenditures ($29 million) and removal costs ($6 million). At September 30, 2019, O&R and RECO costs related to 2018 storms amounted to $43 million and $17 million, respectively, most of which were deferred as regulatory assets pursuant to their electric rate plans. In January 2019, O&R began recovering its deferred storm costs over a six year period in accordance with its New York electric rate plan. The ~~order did~~NYSPSC investigated the preparation and response to the storms by CECONY, O&R, and other New York electric utilities, including all aspects of their emergency response plans. In April 2019, following the issuance of a NYSPSC staff report on the investigation, the NYSPSC ordered the utilities to show cause why the NYSPSC should not commence a ~~prudence review~~penalty action against them for violating their emergency response plans. The Utilities are unable to estimate the amount or ~~address cost recovery.~~range of their possible loss related to this matter. At September 30, 2019, the Utilities had not accrued a liability related to this matter.

In May 2018, FERC denied a complaint the NJBPU filed with FERC seeking the re-allocation to CECONY of certain PJM Interconnection LLC (PJM) transmission costs that had been allocated to the company prior to April 2017 when transmission service provided to the company pursuant to the PJM open access transmission tariff terminated. The transmission service terminated because the company did not exercise its option to continue the service following a series of requests PJM had submitted to FERC that substantially increased the charges for the transmission service. CECONY challenged each of these requests. FERC rejected all but one of CECONY’s protests. In June 2015 and May 2016, CECONY filed appeals of certain FERC decisions with the U.S. Court of Appeals. In July 2018, FERC established a settlement proceeding relating to the allocation of PJM transmission costs. Under ~~the New York State Administrative Procedure Act, the order could not remain in effect for more than 90 days without further action~~CECONY’s electric rate plan, unless and until changed by the NYSPSC, ~~because it was adopted on an emergency basis. At its October 19, 2017 meeting,~~the company will recover all charges incurred associated with the transmission service.

In July 2018, the NYSPSC ~~approved another order in~~commenced an investigation into the rupture of a CECONY steam main (see Note H).

In March 2019, the NYSPSC ordered CECONY to show cause why the NYSPSC should not commence a penalty action and prudence proceeding against CECONY for alleged violations of gas operator qualification, performance, and inspection requirements. The company is seeking to resolve this ~~proceeding. The~~matter through settlement negotiations with the NYSPSC ~~has not yet issued this other order.~~staff. Any settlement would be subject to NYSPSC approval. The company is unable to estimate the amount or range of its possible ~~costs~~loss related to this matter. At September 30, 2019, the company had not accrued a liability related to this matter.

On July 13, 2019, electric service was interrupted to approximately 72,000 CECONY customers on the west side of Manhattan. The NYSPSC and the Northeast Power Coordinating Council, a regional reliability entity, are investigating the July 13, 2019 power outage. The NYSPSC is also investigating other CECONY power outages that occurred in July 2019. Pursuant to the reliability performance provisions of its electric rate plan, as a result of the July 13, 2019 power outage, the company is subject to a $5 million negative revenue adjustment (which it recognized in the third quarter of 2019). The company is unable to estimate the amount or range of its possible additional loss related to the power outages. At September 30, 2019, the company had accrued a $5 million liability related to the power outages.

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Regulatory Assets and Liabilities

Regulatory assets and liabilities at September 30, ~~2017~~2019 and December 31, ~~2016~~2018 were comprised of the following items:


	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2019	2018	2019	2018
Regulatory assets
Unrecognized pension and other postretirement costs	$2,626	$2,874	$2,476	$2,730	$1,919	$2,238	$1,816	$2,111
Future income tax	2,419	2,439	2,308	2,325
Environmental remediation costs	803	823	690	711	774	810	685	716
Revenue taxes	341	295	325	280	315	291	302	278
MTA power reliability deferral					245	229	245	229
Property tax reconciliation					160	101	150	86
Deferred derivative losses	88	48	78	42	99	17	90	11
Municipal infrastructure support costs					80	67	80	67
Pension and other postretirement benefits deferrals	70	38	45	7	77	73	55	56
Municipal infrastructure support costs	57	44	57	44
Deferred storm costs	43	56	—	3	69	76	—	—
System peak reduction and energy efficiency programs					60	72	59	70
Meadowlands heater odorization project					35	36	35	36
Brooklyn Queens demand management program					35	39	35	39
Unamortized loss on reacquired debt	39	43	37	41	30	36	28	34
Indian Point Energy Center program costs	32	50	32	50
O&R property tax reconciliation	29	37	—	—
Brooklyn Queens demand management program	28	29	28	29
Preferred stock redemption	24	25	24	25	22	23	22	23
Surcharge for New York State assessment	18	28	16	26
Net electric deferrals	13	24	13	24
Recoverable REV demonstration project costs					21	20	18
Gate station upgrade project					19	17	19	17
Workers’ compensation	12	13	12	13	5	5	5
O&R transition bond charges	10	15	—	—	—	2	—	—
Recoverable energy costs	4	42	4	38
Other	113	101	103	85	194	142	187	127
Regulatory assets – noncurrent	6,769	7,024	6,248	6,473	4,159	4,294	3,831	3,923
Deferred derivative losses	81	91	75	86	68	36	57	29
Recoverable energy costs	28	9	25	4	15	40	12	35
Regulatory assets – current	109	100	100	90	83	76	69	64
Total Regulatory Assets	$6,878	$7,124	$6,348	$6,563	$4,242	$4,370	$3,900	$3,987
Regulatory liabilities
Future income tax					$2,448	$2,515	$2,302	$2,363
Allowance for cost of removal less salvage	$798	$755	$671	$641	952	928	808	790
TCJA net benefits*					462	434	444	411
Net unbilled revenue deferrals					145	117	145	117
Energy efficiency portfolio standard unencumbered funds					123	127	119	122
Pension and other postretirement benefit deferrals	202	193	174	162	67	62	41	40
Net unbilled revenue deferrals	166	145	166	145
Property tax reconciliation	140	178	140	178
Property tax refunds					45	45	45
Net proceeds from sale of property					44	6	44	6
System benefit charge carrying charge					43	27	38	24
Earnings sharing - electric, gas and steam					26	36	19	27
BQDM and REV Demo reconciliations					25	18	24	18
Settlement of prudence proceeding					15	37	15	37
Settlement of gas proceedings					11	15	11	15
Unrecognized other postretirement costs	84	60	84	60	5	7	—	7
Settlement of prudence proceeding	73	95	73	95
Carrying charges on repair allowance and bonus depreciation	49	68	48	67	4	21	4	21
New York State income tax rate change	48	61	48	60	3	17	3	17
Variable-rate tax-exempt debt – cost rate reconciliation	36	55	32	48
Property tax refunds	28	1	28	1
Settlement of gas proceedings	27		27
Base rate change deferrals	26	40	26	40	1	10	1	10
Earnings sharing - electric, gas and steam	24	39	15	28
Net utility plant reconciliations	11	16	8	15
Property tax reconciliation					—	36	—	36
Other	161	172	133	145	171	183	137	152
Regulatory liabilities – noncurrent	1,873	1,905	1,673	1,712	4,590	4,641	4,200	4,258
Refundable energy costs	29		9	5	36	31	8
Deferred derivative gains					33	30	32	29
Revenue decoupling mechanism	27	71	27	61	24	53	16	36
Deferred derivative gains	2	28	2	24
Regulatory liabilities – current	58	128	38	90	93	114	56	73
Total Regulatory Liabilities	$1,931	$2,033	$1,711	$1,802	$4,683	$4,755	$4,256	$4,331

* See "Other Regulatory Matters," above.

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Note C —– Capitalization

In February 2019, Con Edison borrowed $825 million under a two-year variable-rate term loan to fund the repayment of a six-month variable-rate term loan. In June 2019, Con Edison pre-paid $150 million of the amount borrowed.

In March ~~2017,~~2019, Con Edison issued 5,649,369 shares of its common stock for $425 million upon physical settlement of the remaining shares subject to its November 2018 forward sale agreements.

In April 2019, CECONY redeemed at maturity $475 million of 6.65 percent 10-year debentures.

In May 2019, Con Edison entered into a forward sale agreement relating to 5,800,000 shares of its common stock. In June 2019, the company issued 4,750,000 shares for $400 million upon physical settlement of shares subject to the forward sale agreement. At September 30, 2019, 1,050,000 shares remain subject to the forward sale agreement. The company expects the remaining shares under the forward sale agreement to settle by December 28, 2020. The company or the forward purchaser may accelerate the forward sale agreement upon the occurrence of certain events. On a settlement date, if the company decides to physically settle, it will issue shares to the forward purchaser at the then-applicable forward sale price. The forward sale price is equal to $84.83 per share subject to adjustment on a daily basis based on a floating interest rate factor less a spread and will be subject to decrease by amounts related to expected dividends. The remaining shares under the forward sale agreement will be physically settled, unless the company elects cash or net share settlement (which it has the right to do, subject to certain conditions, other than in limited circumstances). In the event the company elects to cash settle or net share settle, the settlement amount will be generally related to (1)(a) the market value of the common stock during the unwind period under the forward sale agreement minus (b) the applicable forward sale price; multiplied by (2) the number of shares subject to such cash settlement or net share settlement. If this settlement amount is a negative number, the forward purchaser will pay the company the absolute value of that amount or deliver to the company a number of shares having a value equal to the absolute value of such amount. If this settlement amount is a positive number, the company will pay the forward purchaser that amount or deliver to the forward purchaser a number of shares having a value equal to such amount.

In May 2019, CECONY issued $700 million aggregate principal amount of ~~2.00~~4.125 percent debentures, due ~~2020, and prepaid~~2049.

In May 2019, O&R’s New Jersey utility subsidiary paid the ~~$400~~remaining $1 million ~~variable rate term loan that was to mature~~principal amount of Transition Bonds issued in ~~2018. Also, in March 2017,~~2004.

In May 2019, a Con Edison

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Development subsidiary ~~issued $97~~borrowed $464 million at a variable-rate, due 2026, secured by equity interests in solar electric production projects. The company has entered into fixed-rate interest rate swaps in connection with this borrowing. See Note L.

In September 2019, O&R agreed to issue in November 2019 $43 million aggregate principal amount of ~~4.45~~3.73 percent ~~senior notes,~~debentures, due ~~2042, secured by the company’s Upton County Solar project. In June 2017, CECONY issued $500~~2049 and to issue in December 2019 $44 million aggregate principal amount of ~~3.875~~2.94 percent debentures, due ~~2047.~~ 2029 and $38 million aggregate principal amount of 3.46 percent debentures, due 2039.

In ~~August 2017,~~October 2019, a Con Edison Development subsidiary issued ~~4.1~~$303 million ~~common shares resulting in net proceeds~~aggregate principal amount of ~~$343 million, after issuance expenses, that were invested~~3.82 percent senior notes, due 2038, secured by ~~Con Edison in its subsidiaries, principally CECONY~~the company's Panoche Valley and ~~the Clean Energy Businesses, for funding of their construction expenditures and for other general corporate purposes.~~

Wistaria Solar renewable electric production projects.

The carrying amounts and fair values of long-term debt at September 30, ~~2017~~2019 and December 31, ~~2016~~2018 were:



(Millions of Dollars)	2019		2018
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$19,451	$22,412	$18,145	$18,740
CECONY	$14,374	$17,047	$14,151	$14,685

(Millions of Dollars) 2017 2016
Long-Term Debt (including current portion) (a)
Carrying
Amount
Fair
Value
Carrying
Amount
Fair
Value
Con Edison $15,338 $17,195 $14,774 $16,093
CECONY $12,571 $14,213 $12,073 $13,268


(a)	Amounts shown are net of unamortized debt expense and unamortized debt discount of ~~$137~~$167 million and ~~$115~~$141 million for Con Edison and CECONY, respectively, as of September 30, ~~2017~~2019 and ~~$134~~$185 million and ~~$113~~$139 million for Con Edison and CECONY, respectively, as of December 31, ~~2016.~~2018.

~~Fair~~The fair values of the Companies' long-term debt have been estimated primarily using available market ~~information. For Con Edison, $16,559 million~~information and ~~$636 million of the fair value of long-term debt~~ at September 30, ~~2017~~2019 are classified as Level 2 ~~and Level 3, respectively. For CECONY, $13,577 million and $636~~(see Note M).

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At December 31, 2018, the Clean Energy Businesses had $2,076 million of non-recourse project debt secured by the ~~fair value~~pledge of the applicable renewable energy production projects, of which $1,965 million was included in long-term debt atand $111 million was included in long-term debt due within one year in Con Edison's consolidated balance sheet. As a result of the January 2019 PG&E bankruptcy (see "Long-Lived and Intangible Assets" in Note A), during the first quarter of 2019, Con Edison reclassified on its consolidated balance sheet the PG&E-related project debt that was included in long-term debt to long-term debt due within one year. At September 30, ~~2017 are classified as Level 2 and Level 3, respectively (see Note L). The $636~~2019, long-term debt due within one year included $1,012 million of ~~long-term~~PG&E-related project debt. The lenders for the PG&E-related project debt ~~classified as Level 3~~may, upon written notice, declare principal and interest on the PG&E-related project debt to be due and payable immediately and, if such amounts are not timely paid, foreclose on the related projects. The company is ~~CECONY’s tax-exempt, auction-rate securities for~~seeking to negotiate agreements with the PG&E-related project debt lenders pursuant to which the ~~market is highly illiquid and there is a lack of observable inputs.~~lenders would defer exercising these remedies.

Note D —– Short-Term Borrowing

At September 30, ~~2017,~~2019, Con Edison had ~~$356~~$1,300 million of commercial paper outstanding of which ~~$147~~$930 million was outstanding under CECONY’s program. The weighted average interest rate at September 30, ~~2017~~2019 was ~~1.3~~2.3 percent for both Con Edison and CECONY. At December 31, ~~2016,~~2018, Con Edison had ~~$1,054~~$1,741 million of commercial paper outstanding of which ~~$600~~$1,192 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, ~~2016~~2018 was ~~1.0~~3.0 percent for both Con Edison and CECONY.

At September 30, ~~2017~~2019 and December 31, ~~2016, no~~2018, 0 loans were outstanding under the Companies' December 2016 credit agreement (Credit Agreement). An immaterial amount ~~and $2 million (including $2 million for CECONY)~~ of letters of credit were outstanding under the Credit Agreement as of September 30, ~~2017~~2019 and December 31, ~~2016, respectively.~~2018. In April 2019, the termination date of the Credit Agreement was extended from December 2022 to December 2023 with respect to banks with aggregate commitments of $2,200 million.

Note E —– Pension Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic benefit ~~costs~~cost for the three and nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 were as follows:



	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Service cost – including administrative expenses	$62	$72	$58	$68
Interest cost on projected benefit obligation	150	140	141	131
Expected return on plan assets	(247)	(258)	(234)	(245)
Recognition of net actuarial loss	130	172	123	163
Recognition of prior service cost/(credit)	(4)	(4)	(5)	(5)
TOTAL PERIODIC BENEFIT COST	$91	$122	$83	$112
Cost capitalized	(26)	(32)	(24)	(30)
Reconciliation to rate level	(5)	(22)	(4)	(24)
Total expense recognized	$60	$68	$55	$58

For the Three Months Ended September 30,
Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Service cost – including administrative expenses $66 $69 $61 $65
Interest cost on projected benefit obligation 148 149 139 140
Expected return on plan assets (243) (237) (229) (225)
Recognition of net actuarial loss 149 149 141 141
Recognition of prior service costs (4) 1 (5) —
TOTAL PERIODIC BENEFIT COST $116 $131 $107 $121
Cost capitalized (40) (51) (37) (49)
Reconciliation to rate level (14) 10 (16) 13
Cost charged to operating expenses $62 $90 $54 $85

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	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Service cost – including administrative expenses	$187	$218	$175	$204
Interest cost on projected benefit obligation	451	420	423	394
Expected return on plan assets	(741)	(775)	(702)	(734)
Recognition of net actuarial loss	389	516	369	488
Recognition of prior service cost/(credit)	(13)	(13)	(15)	(15)
TOTAL PERIODIC BENEFIT COST	$273	$366	$250	$337
Cost capitalized	(80)	(94)	(76)	(89)
Reconciliation to rate level	(12)	(68)	(10)	(74)
Total expense recognized	$181	$204	$164	$174

For the Nine Months Ended September 30,
Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Service cost – including administrative expenses $197 $207 $184 $194
Interest cost on projected benefit obligation 444 447 416 419
Expected return on plan assets (726) (711) (689) (674)
Recognition of net actuarial loss 446 447 423 424
Recognition of prior service costs (13) 3 (14) 1
TOTAL PERIODIC BENEFIT COST $348 $393 $320 $364
Cost capitalized (134) (157) (125) (148)
Reconciliation to rate level (28) 35 (32) 39
Cost charged to operating expenses $186 $271 $163 $255

Components of net periodic benefit cost other than service cost are presented outside of operating income on the Companies' consolidated income statements, and only the service cost component is eligible for capitalization. Accordingly, the service cost component is included in the line "Other operations and maintenance" and the non-service cost components are included in the line "Other deductions" in the Companies' consolidated income statements.

Expected Contributions

Based on estimates as of September 30, ~~2017,~~2019, the Companies expect to make contributions to the pension plans during ~~2017~~2019 of ~~$450~~$350 million (of which ~~$412~~$318 million is to be ~~contributed~~made by CECONY). The Companies’ policy is to fund the total periodic benefit cost of the qualified plan to the extent tax deductible and to also contribute to the non-qualified supplemental plans. During the first nine months of ~~2017,~~2019, the Companies contributed ~~$446~~$346 million to the pension plans (of which ~~$409~~$315 million was ~~contributed~~made by CECONY). CECONY also contributed ~~$14~~$15 million to ~~its~~the external trust for its non-qualified supplemental ~~plans.~~plan.

Note F —– Other Postretirement Benefits

Total Periodic Benefit Cost

The components of the Companies’ total periodic other postretirement benefit ~~costs~~cost/(credit) for the three and nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 were as follows:



	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Service cost	$4	$5	$3	$3
Interest cost on accumulated other postretirement benefit obligation	11	11	9	9
Expected return on plan assets	(16)	(18)	(14)	(16)
Recognition of net actuarial loss/(gain)	(2)	2	(2)	1
Recognition of prior service cost/(credit)	(1)	(2)	—	(1)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT)	$(4)	$(2)	$(4)	$(4)
Cost capitalized	(1)	(2)	(2)	(1)
Reconciliation to rate level	3	2	2	2
Total expense/(credit) recognized	$(2)	$(2)	$(4)	$(3)

For the Three Months Ended September 30,

Con Edison CECONY
(Millions of Dollars) 2017 2016 2017
2016
Service cost $5 $4 $3 $3
Interest cost on accumulated other postretirement benefit obligation 11 12 9 10
Expected return on plan assets (17) (19) (15) (17)
Recognition of net actuarial loss 1 1 —
1
Recognition of prior service cost (5) (5) (3) (3)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $(5) $(7) $(6) $(6)
Cost capitalized 2 2 2 2
Reconciliation to rate level (1) 7 —
6
Cost charged to operating expenses $(4) $2 $(4) $2

For the Nine Months Ended September 30,

Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Service cost $15 $13 $10 $10
Interest cost on accumulated other postretirement benefit obligation 34 36 28 30
Expected return on plan assets (52) (58) (45) (50)
Recognition of net actuarial loss/(gain) 2 4 (2) 2
Recognition of prior service cost (13) (15) (9) (11)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST $(14) $(20) $(18) $(19)
Cost capitalized 6 5 7 5
Reconciliation to rate level (3) 20 (1) 19
Cost charged to operating expenses $(11) $5 $(12) $5

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	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Service cost	$13	$15	$9	$10
Interest cost on accumulated other postretirement benefit obligation	33	32	27	26
Expected return on plan assets	(49)	(55)	(41)	(47)
Recognition of net actuarial loss/(gain)	(6)	6	(7)	2
Recognition of prior service cost/(credit)	(2)	(5)	(1)	(2)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT)	$(11)	$(7)	$(13)	$(11)
Cost capitalized	(6)	(6)	(4)	(4)
Reconciliation to rate level	10	6	6	7
Total expense/(credit) recognized	$(7)	$(7)	$(11)	$(8)

For information about the presentation of the components of other postretirement benefit costs, see Note E.

Contributions

During the first nine months of ~~2017, Con Edison~~2019, the Companies contributed ~~$16~~$7 million (substantially all of which ~~$8 million~~ was ~~contributed~~made by ~~CECONY,~~CECONY) to the other postretirement benefit plans. The Companies' policy is to fund the total periodic benefit cost of the plans to the extent tax deductible.

Note G —– Environmental Matters

Superfund Sites

Hazardous substances, such as asbestos, polychlorinated biphenyls (PCBs) and coal tar, have been used or generated in the course of operations of the Utilities and their predecessors and are present at sites and in facilities and equipment they currently or previously owned, including sites at which gas was manufactured or stored.

The Federal Comprehensive Environmental Response, Compensation and Liability Act of 1980 and similar state statutes (Superfund) impose joint and several liability, regardless of fault, upon generators of hazardous substances for investigation and remediation costs (which include costs of demolition, removal, disposal, storage, replacement, containment and monitoring) and natural resource damages. Liability under these laws can be material and may be imposed for contamination from past acts, even though such past acts may have been lawful at the time they occurred. The sites at which the Utilities have been asserted to have liability under these laws, including their manufactured gas plant sites and any neighboring areas to which contamination may have migrated, are referred to herein as “Superfund Sites.”

For Superfund Sites where there are other potentially responsible parties and the Utilities are not managing the site investigation and remediation, the accrued liability represents an estimate of the amount the Utilities will need to pay to investigate and, where determinable, discharge their related obligations. For Superfund Sites (including the manufactured gas plant sites) for which one of the Utilities is managing the investigation and remediation, the accrued liability represents an estimate of the company’s share of the undiscounted cost to investigate the sites and, for sites that have been investigated in whole or in part, the cost to remediate the sites, if remediation is necessary and if a reasonable estimate of such cost can be made. Remediation costs are estimated in light of the information available, applicable remediation standards and experience with similar sites.

The accrued liabilities and regulatory assets related to Superfund Sites at September 30, ~~2017~~2019 and December 31, ~~2016~~2018 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Accrued Liabilities:
Manufactured gas plant sites	$679	$689	$596	$603
Other Superfund Sites	88	90	88	90
Total	$767	$779	$684	$693
Regulatory assets	$774	$810	$685	$716

Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Accrued Liabilities:
Manufactured gas plant sites $659 $664 $563 $567
Other Superfund Sites 86 89 85 88
Total $745 $753 $648 $655
Regulatory assets $803 $823 $690 $711

Most of the accrued Superfund Site liability relates to sites that have been investigated, in whole or in part. However, for some of the sites, the extent and associated cost of the required remediation has not yet been

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determined. As investigations progress and information pertaining to the required remediation becomes available, the Utilities expect that additional liability may be accrued, the amount of which is not presently determinable but may be material. The Utilities are permitted to recover or defer as regulatory assets (for subsequent recovery through rates) prudently incurred site investigation and remediation costs.

Environmental remediation costs incurred related to Superfund Sites for the three and nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 were as follows:



	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Remediation costs incurred	$4	$8	$2	$5

For the Three Months Ended September 30,
Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Remediation costs incurred $4 $8 $3 $5



	For the Nine Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Remediation costs incurred	$15	$17	$10	$14

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For the Nine Months Ended September 30,
Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Remediation costs incurred $18 $20 $13 $10

Insurance and other third-party recoveries received by Con Edison or CECONY were immaterial for the three and nine months ended September 30, ~~2017. Con Edison~~2019 and ~~CECONY received $1 million in insurance recoveries for the three and nine months ended September 30, 2016.~~2018.

In ~~2016,~~2018, Con Edison and CECONY estimated that for their manufactured gas plant sites (including CECONY’s Astoria site), the aggregate undiscounted potential liability for the investigation and remediation of coal tar and/or other environmental contaminants could range up to $2.8 billion and $2.6 billion, respectively. These estimates were based on the assumption that there is contamination at all sites, including those that have not yet been fully investigated and additional assumptions about the extent of the contamination and the type and extent of the remediation that may be required. Actual experience may be materially different.

Asbestos Proceedings

Suits have been brought in New York State and federal courts against the Utilities and many other defendants, wherein a large number of plaintiffs sought large amounts of compensatory and punitive damages for deaths and injuries allegedly caused by exposure to asbestos at various premises of the Utilities. The suits that have been resolved, which are many, have been resolved without any payment by the Utilities, or for amounts that were not, in the aggregate, material to them. The amounts specified in all the remaining thousands of suits total billions of dollars; however, the Utilities believe that these amounts are greatly exaggerated, based on the disposition of previous claims. At September 30, ~~2017,~~2019, Con Edison and CECONY have accrued their estimated aggregate undiscounted potential liabilities for these suits and additional suits that may be brought over the next 15 years as shown in the following table. These estimates were based upon a combination of modeling, historical data analysis and risk factor assessment. Courts have begun, and unless otherwise determined on appeal may continue, to apply different standards for determining liability in asbestos suits than the standard that applied historically. As a result, the Companies currently believe that there is a reasonable possibility of an exposure to loss in excess of the liability accrued for the suits. The Companies are unable to estimate the amount or range of such loss. In addition, certain current and former employees have claimed or are claiming workers’ compensation benefits based on alleged disability from exposure to asbestos. CECONY is permitted to defer as regulatory assets (for subsequent recovery through rates) costs incurred for its asbestos lawsuits and workers’ compensation claims.

The accrued liability for asbestos suits and workers’ compensation proceedings (including those related to asbestos exposure) and the amounts deferred as regulatory assets for the Companies at September 30, ~~2017~~2019 and December 31, ~~2016~~2018 were as follows:



	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$79	$79	$75	$75
Regulatory assets – workers’ compensation	$5	$5	$5	$5

Con Edison CECONY
(Millions of Dollars) 2017 2016 2017 2016
Accrued liability – asbestos suits $8 $8 $7 $7
Regulatory assets – asbestos suits $8 $8 $7 $7
Accrued liability – workers’ compensation $87 $88 $83 $83
Regulatory assets – workers’ compensation $12 $13 $12 $13

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Note H —– Other Material Contingencies

Manhattan Explosion and Fire

On March 12, 2014, ~~two~~2 multi-use five-story tall buildings located on Park Avenue between 116^th and 117^th Streets in Manhattan were destroyed by an explosion and fire. CECONY had delivered gas to the buildings through service lines from a distribution main located below ground on Park Avenue. ~~Eight~~NaN people died and more than 50 people were injured. Additional buildings were also damaged. The National Transportation Safety Board (NTSB) investigated. The parties to the investigation included the company, the City of New York, the Pipeline and Hazardous Materials Safety Administration and the NYSPSC. In June 2015, the NTSB issued a final report concerning the incident, its probable cause and safety recommendations. The NTSB determined that the probable cause of the incident was (1) the failure of a defective fusion joint at a service tee (which joined a plastic service line to a plastic distribution main) installed by the company that allowed gas to leak from the distribution main and migrate into a building where it ignited and (2) a breach in a City sewer line that allowed groundwater and soil to flow into the sewer, resulting in a loss of support for the distribution main, which caused it to sag and overstressed the defective fusion joint. The NTSB also made safety recommendations, including recommendations to the company that addressed its procedures for the preparation and examination of plastic fusions, training of its staff on conditions for notifications to the City’s Fire Department and extension of its gas main isolation valve installation program. In February 2017, the NYSPSC approved a settlement agreement with the company related to the NYSPSC's investigations of the incident and the practices of qualifying persons to perform plastic fusions. Pursuant to the agreement, the company ~~will not recover from customers $126 million of costs it incurred for gas emergency response activities in 2014, 2015 and 2016 in excess of the amounts reflected in its gas rate plan and will provide~~is providing $27 million of future benefits to customers (for which it has accrued a regulatory ~~liability, see Note B).~~liability) and will not recover from customers $126 million of costs for gas emergency response activities that it had previously incurred and expensed. Approximately ~~eighty~~80 suits are pending against the company seeking generally unspecified damages and, in some cases, punitive damages, for wrongful death, personal injury, property damage and business interruption. The company has notified its insurers of the incident and believes that the policies in force at the time of the incident will cover the company’s costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages in connection with the incident. The company is unable to estimate the amount or range of its possible loss for damages related to the incident. At September 30, ~~2017,~~2019, the company had not accrued a liability for damages related to the incident.

Manhattan Steam Main Rupture

In July 2018, a CECONY steam main located on Fifth Avenue and 21^st Street in Manhattan ruptured. Debris from the incident included dirt and mud containing asbestos. The response to the incident required the closing of buildings and streets for various periods. The NYSPSC has commenced an investigation. As of September 30, 2019, with respect to the incident, the company incurred estimated operating costs of $16 million for property damage, clean- up and other response costs and invested $10 million in capital and retirement costs. The company has notified its insurers of the incident and believes that the policies currently in force will cover the company’s costs, in excess of a required retention (the amount of which is not material), to satisfy any liability it may have for damages to others in connection with the incident. The company is unable to estimate the amount or range of its possible loss related to the incident. At September 30, 2019, the company had not accrued a liability related to the incident.

Other Contingencies

~~See~~For information about the PG&E bankruptcy, see "Long-Lived and Intangible Assets" in Note A and Note C. Also, for additional contingencies, see "Other Regulatory Matters" in Note B and “Uncertain Tax Positions” in Note I.J.

Guarantees

Con Edison and its subsidiaries ~~enter~~have entered into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison under these agreements totaled ~~$2,162~~$1,954 million and ~~$2,370~~$2,439 million at September 30, ~~2017~~2019 and December 31, ~~2016,~~2018, respectively.

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A summary, by type and term, of Con Edison’s total guarantees under these agreements at September 30, ~~2017~~2019 is as follows:



Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)
Con Edison Transmission	$162	$411		$—	$573
Energy transactions	501	29	194		724
Renewable electric production projects	124	9	454		587
Other	70	—	—		70
Total	$857	$449	$648		$1,954

Guarantee Type 0 – 3 years 4 – 10 years
> 10 years
Total
(Millions of Dollars)
Con Edison Transmission $643 $404
$—
$1,047
Energy transactions 459 30 211 700
Renewable electric production projects 268 —
19 287
Other 128 —
—
128
Total $1,498 $434 $230 $2,162

Con Edison Transmission — Con Edison has guaranteed payment by CET Electric of the contributions CET Electric agreed to make to New York Transco LLC (NY Transco). CET Electric ~~acquired~~owns a 45.7 percent interest in NY ~~Transco when it was formed in 2014.~~Transco. In ~~May 2016, the transmission owners transferred certain projects to NY Transco, for which CET Electric made its required contributions. NY Transco has proposed other transmission projects in~~April 2019, the New York Independent System ~~Operator's competitive bidding process. These other~~Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco. The siting, construction and operation of the project will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, ~~are subject to certain authorizations from the NYSPSC, the FERC and, as applicable, other federal, state and local agencies.~~including a schedule for entry into service by December 2023. Guarantee amount shown ~~is for~~includes the maximum possible required amount of CET Electric’s contributions for ~~these other projects~~this project as calculated based on the assumptions that the ~~projects are~~project is completed at 175 percent of ~~their~~its estimated costs and NY Transco does not use any debt financing for the ~~projects. Guarantee term shown is assumed as the selection of the projects and resulting timing of the contributions is not certain.~~project. Also included within the table above ~~is a guarantee~~are guarantees for $25 million from Con Edison on behalf of CET Gas in relation to Mountain Valley Pipeline (MVP), LLC, a company developing a proposed gas transmission project in West Virginia and Virginia.

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Energy Transactions — Con Edison guarantees payments on behalf of the Clean Energy Businesses in order to facilitate physical and financial transactions in electricity, gas, pipeline capacity, transportation, oil, renewable energy credits and energy services. To the extent that liabilities exist under the contracts subject to these guarantees, such liabilities are included in Con Edison’s consolidated balance sheet.

Renewable Electric Production Projects — Con Edison, Con Edison Development, and Con Edison Solutions guarantee payments on behalf of their wholly-owned subsidiaries associated with their investment in, or development for others of, solar and wind energy facilities.

Other — Other guarantees include $70 million in guarantees provided by Con Edison to Travelers Insurance Company for indemnity agreements for surety bonds in connection with operation of solar energy facilities and energy service projects of Con Edison Development and Con Edison Solutions, respectively. Other guarantees also includes Con Edison's guarantee (subject to a $53 million maximum amount) of certain obligations of Con Edison Solutions under the agreement pursuant to which it sold its retail electric supply business. In addition, Con Edison issued a guarantee estimated at $5 million to the Public Utility Commission of Texas covering obligations of Con Edison Solutions as a retail electric provider. As part of the sale agreement for the retail electric supply business discussed above, the purchaser has agreed to pay Con Edison Solutions for draws on the guarantee to the Public Utility Commission of Texas.

Note I —– Leases

In January 2019, the Companies adopted Accounting Standards Update (ASU) No. 2016-02, “Leases (Topic 842),” including the amendments thereto, using a modified retrospective transition method of adoption that required no prior period adjustments or charges to retained earnings for cumulative impact. The standard supersedes the lease requirements within ASC Topic 840, “Leases.”

The Companies lease land, office buildings, equipment and access rights to support electric transmission facilities. Upon adoption of Topic 842, the Companies recognized lease right-of-use assets and lease liabilities on their consolidated balance sheets for virtually all of their leases (other than leases that meet the definition of a short-term lease, the expense for which was immaterial). A lease right-of-use asset represents a right to use an identifiable underlying asset and obtain substantially all of the economic benefits from the use of that asset for the lease term. A lease liability represents an obligation to make lease payments arising from the lease. Leases are classified as either operating leases or finance leases. Operating leases are included in operating lease right-of-use asset and operating lease liabilities on the Companies’ consolidated balance sheets. Finance leases are included in other noncurrent assets, other current liabilities and other noncurrent liabilities. The Utilities, as regulated entities, are permitted to continue to recognize expense for operating leases using the timing that conforms to the regulatory rate treatment as rental payments are recovered from our customers and to account the same way for finance leases. Lessor accounting is similar to the previous model, but updated to align with ASC Topic 606 “Revenue from Contracts with Customers."

The Companies elected the following practical expedients: (1) a package of practical expedients that allows the Companies to not reassess: (a) whether expired or existing contracts contained leases; (b) the lease classification

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for expired or existing leases and (c) the initial direct costs for existing leases; (2) for all underlying asset classes, an expedient that allows the Companies to not apply the recognition requirements to short-term leases and an expedient that allows the Companies to account for lease and associated non-lease components as a single lease component; (3) an expedient that allows the use of hindsight to determine lease term; and (4) an expedient that allows the Companies to not evaluate under Topic 842 land easements that exist or expired before the entity’s adoption of Topic 842 and that were not previously accounted for as leases under Topic 840.

The Companies, upon adoption of Topic 842 recognized, and for new operating leases at commencement date recognize, operating lease right-of-use assets and operating lease liabilities based on the present value of the future minimum lease payments over the lease term. As most of the Companies’ leases do not provide an implicit rate, the Companies used their collateralized incremental borrowing rate based on the information available at the commencement date to determine the present value of future payments. Most of the Companies’ leases have remaining lease terms of one year to 35 years, and may include options to renew or extend the leases for up to five years at the fair rental value. The Companies' lease terms may include options to renew, extend or terminate the lease when it is reasonably certain that the Companies will exercise that option. There were no leases with material variable lease payments or residual value guarantees.

Operating lease cost and cash paid for amounts included in the measurement of lease liabilities for the three and nine months ended September 30, 2019 were as follows:

As of September 30, 2019, assets recorded as finance leases for Con Edison and CECONY were $2 million and $1 million, respectively, and the accumulated amortization associated with finance leases for Con Edison and CECONY were $5 million and $3 million, respectively. For the three and nine months ended September 30, 2019, finance lease costs and cash flows for Con Edison and CECONY were immaterial.

Right-of-use assets obtained in exchange for lease obligations for Con Edison and CECONY were $2 million and $1 million, respectively, for the three months ended September 30, 2019 and $3 million and $2 million, respectively, for the nine months ended September 30, 2019.

Other information related to leases for Con Edison and CECONY at September 30, 2019 was as follows:



	Con Edison	CECONY
Weighted Average Remaining Lease Term:
Operating leases	18.9 years	14.3 years
Finance leases	11.2 years	2.3 years
Weighted Average Discount Rate:
Operating leases	4.3%	3.6%
Finance leases	3.8%	4.7%

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Future minimum lease payments under non-cancellable leases at September 30, 2019 were as follows:



(Millions of Dollars)	Con Edison			CECONY
Year Ending September 30,	Operating Leases	Finance Leases		Operating Leases	Finance Leases
2020	$74	$1		$58	$1
2021	73	—		57	—
2022	69	—		53	—
2023	69	—		53	—
2024	69	—		53	—
All years thereafter	966	1		550	—
Total future minimum lease payments	$1,320	$2		$824	$1
Less: imputed interest	(442)	—		(180)	—
Total	$878	$2		$644	$1
Reported as of September 30, 2019
Operating lease liabilities (current)	$59		$—	$49		$—
Operating lease liabilities (noncurrent)	819	—		595	—
Other current liabilities	—	1		—	1
Other noncurrent liabilities	—	1		—	—
Total	$878	$2		$644	$1

At September 30, 2019, the Companies do not have material obligations under operating or finance leases that have not yet commenced.

Disclosures related to the three and nine months ended September 30, 2019 are presented as required under Topic 842. Prior period disclosures for the year ended December 31, 2018 are presented under Topic 840. The Companies have elected to use a practical expedient provided by Topic 842 whereby comparative disclosures for prior periods are allowed to be presented under Topic 840. Prior period disclosures under Topic 840 have been provided on an annual basis. As a result, the disclosures presented under Topic 842 and Topic 840 will not be fully comparable in specific disclosure requirements or time period.

The future minimum lease commitments at December 31, 2018, accounted for under Topic 840, for the Companies’ operating lease agreements that are not cancellable by the Companies were as follows:



(Millions of Dollars)	Con Edison	CECONY
2019	$72	$56
2020	72	56
2021	71	54
2022	68	53
2023	68	53
All years thereafter	890	592
Total	$1,241	$864

The Companies are lessors under certain leases whereby the Companies own real estate and distribution poles and lease portions of them to others. Revenue under such leases was immaterial for Con Edison and CECONY for the three and nine months ended September 30, 2019.

Note J – Income Tax

Con Edison’s income tax expense decreased to ~~$270~~$116 million for the three months ended September 30, ~~2017~~2019 from ~~$314~~$175 million for the three months ended September 30, ~~2016.~~2018. The decrease in income tax expense is primarily due to lower income before income tax expense (excluding income attributable to noncontrolling interest (see Note N)), lower state income taxes, the absence of a $42 million re-measurement of deferred tax assets due to the TCJA associated with Con ~~Edison's effective~~Edison’s 2017 federal net operating loss carryforward into 2018 recognized at the filing of its 2017 federal tax ~~rate~~return, an increase in the amortization of excess deferred federal income taxes due to the TCJA and higher renewable energy credits and adjustments for prior period federal income tax returns primarily due to increased research and development credits at the Clean Energy Businesses, offset, in part, by an increase in uncertain tax positions at the Clean Energy Businesses.

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CECONY’s income tax expense decreased to $119 million for the three months ended September 30, ~~2017 and 2016 was 37 percent and 39 percent, respectively.~~2019 from $125 million for the three months ended September 30, 2018. The decrease in ~~Con Edison's effective~~income tax expense is primarily due to lower income before income tax expense, lower state income taxes and an increase in the amortization of excess deferred federal income taxes due to the TCJA, offset, in part, by lower tax benefits in 2019 for plant-related flow through items and adjustments for the 2017 federal income tax return primarily due to increased non-deductible business expenses.

Reconciliation of the difference between income tax expense and the amount computed by applying the prevailing statutory income tax rate to income before income taxes for the three months ended September 30, 2019 and 2018 is as follows:



	Con Edison				CECONY
(% of Pre-tax income)	2019		2018		2019		2018
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax	4		5		5		5
Other plant-related items	—		(1	)	—		(1	)
Renewable energy credits	(1	)	(1	)	—		—
TCJA deferred tax re-measurement	—		7		—		—
Reserve for uncertain tax positions	1		—		—		—
Amortization of excess deferred federal income taxes	(3	)	(2	)	(3	)	(2	)
Prior period return adjustments	(2	)	—		—		—
Other	—		(1	)	(1	)	(1	)
Effective tax rate	20	%	28	%	22	%	22	%

Con Edison’s income tax expense decreased to $243 million for the nine months ended September 30, 2019 from $330 million for the nine months ended September 30, 2018. The decrease in income tax expense is primarily due to lower income before income tax expense (excluding income attributable to noncontrolling interest (see Note N)), lower state income taxes, the absence of a $42 million re-measurement of deferred tax assets due to the TCJA associated with Con Edison’s 2017 federal net operating loss carryforward into 2018 recognized at the filing of its 2017 federal tax return, an increase in the amortization of excess deferred federal income taxes due to the TCJA, higher renewable energy credits and adjustments for prior period federal income tax returns primarily due to increased research and development credits at the Clean Energy Businesses, offset, in part, by an increase in uncertain tax positions at the Clean Energy Businesses.

CECONY’s income tax expense decreased to $271 million for the nine months ended September 30, 2019 from $274 million for the nine months ended September 30, 2018. The decrease in income tax expense is primarily due to lower state income taxes and an increase in the amortization of excess deferred federal income taxes due to the TCJA, offset, in part, by ~~a decrease in tax benefits for plant-related flow through items.~~

~~CECONY’s~~higher income before income tax expense ~~increased to $242 million for the three months ended September 30, 2017 from $226 million for the three months ended September 30, 2016. CECONY's effective~~and lower tax ~~rate for the three months ended September 30, 2017 and 2016 was 38 percent and 37 percent, respectively. The increase~~benefits in ~~CECONY's effective tax rate is primarily due to a decrease in tax benefits~~2019 for plant-related flow through items and ~~lower research and development credits, offset in part by lower state~~adjustments for the 2017 federal income ~~taxes.~~tax returns primarily due to increased non-deductible business expenses.

~~Con Edison’s~~Reconciliation of the difference between income tax expense ~~decreased~~and the amount computed by applying the prevailing statutory income tax rate to ~~$599 million~~income before income taxes for the nine months ended September 30, ~~2017 from $602 million~~2019 and 2018 is as follows:

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	Con Edison				CECONY
(% of Pre-tax income)	2019		2018		2019		2018
STATUTORY TAX RATE
Federal	21	%	21	%	21	%	21	%
Changes in computed taxes resulting from:
State income tax	4		5		5		5
Cost of removal	1		1		1		1
Other plant-related items	—		(1	)	(1	)	(1	)
Renewable energy credits	(2	)	(1	)	—		—
TCJA deferred tax re-measurement	—		3		—		—
Amortization of excess deferred federal income taxes	(4	)	(3	)	(3	)	(3	)
Other	(1	)	(1	)	(1	)	(1	)
Effective tax rate	19	%	24	%	22	%	22	%

CECONY and O&R deferred as regulatory liabilities their estimated net benefits under the TCJA for the nine months ended September 30, ~~2016. Con Edison's effective tax rate~~2018. CECONY's net benefits prior to January 1, 2019 for its electric service and amortization of excess deferred federal income taxes for its electric service for the nine months ended September 30, ~~2017 and 2016 was 37 percent.~~2019 continue to be deferred. RECO deferred as a regulatory liability its estimated net benefits under the TCJA for the three months ended March 31, 2018. The ~~effective~~net benefits include the revenue requirement impact of the reduction in the corporate federal income tax rate ~~remained unchanged as lower state~~to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes ~~were offset by a decrease~~the utilities collected from customers that will not need to be paid to the Internal Revenue Service under the TCJA. See “Other Regulatory Matters” in ~~tax benefits for plant-related flow through items.~~Note B.

CECONY’s income tax expense increased to $551 million for the nine months ended September 30, 2017 from $491 million for the nine months ended September 30, 2016. CECONY's effective tax rate for the nine months ended September 30, 2017 and 2016 was 38 percent and 36 percent, respectively. The increase in CECONY's effective tax rate is primarily due to a decrease in tax benefits for plant-related flow through items and lower research and development tax credits, offset in part by lower state income taxes.

Con Edison anticipates a federal consolidated net operating loss for 2017, primarily due to bonus depreciation. Con Edison expects to carryback a portion of its 2017 net operating loss to recover $19 million of income tax. The remaining 2017 net operating loss, as well as general business tax credits generated in 2017, will be carried forward to future tax years. A deferred tax asset for these tax attribute carryforwards was recorded, and no valuation allowance has been provided, as it is more likely than not that the deferred tax asset will be realized.

Uncertain Tax Positions

At September 30, ~~2017,~~2019, the estimated liability for uncertain tax positions for Con Edison was ~~$41~~$15 million ($214 million for CECONY). Con Edison reasonably expects to resolve ~~approximately $35 million ($24 million, net of federal taxes) of its uncertain tax positions~~ within the next twelve months ~~including $21~~approximately $12 million ~~($15 million, net~~ of various federal ~~taxes),~~and state uncertainties due to the expected completion of ongoing tax examinations, of which the entire amount, if recognized, would reduce Con ~~Edison’s~~Edison's effective tax rate. The amount related to CECONY is approximately ~~$18 million ($13 million, net of federal taxes), including $4~~$3 million, which, if recognized, would reduce CECONY’s effective tax rate. The total amount of unrecognized tax benefits, if recognized, that would reduce Con Edison’s effective tax rate is ~~$25~~$15 million ($1814 million, net of federal taxes).

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The Companies recognize interest on liabilities for uncertain tax positions in interest expense and would recognize penalties, if any, in operating expenses in the Companies’ consolidated income statements. In the three and nine months ended September 30, ~~2017,~~2019, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At September 30, ~~2017~~2019 and December 31, ~~2016,~~2018, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

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Note ~~J —~~K – Financial Information by Business Segment

Con Edison’s principal business segments are CECONY’s regulated utility activities, O&R’s regulated utility activities, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business segments are its regulated electric, gas and steam utility activities. The financial data for the business segments for the three and nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 were as follows:


	For the Three Months Ended September 30,										For the Three Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income/(loss)		Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2017	2016	2017		2016		2017	2016	2017	2016	2019	2018	2019		2018		2019	2018	2019	2018
CECONY
Electric	$2,469	$2,557	$4		$5		$232	$217	$855	$841	$2,544	$2,571	$4				$266	$248	$803	$850
Gas	268	208	2		1		47	41	(12)	(28)	275	264	2				58	52	(24)	(34)
Steam	62	63	19		22		21	20	(43)	(47)	58	64	18		19		22		(56)	(52)
Consolidation adjustments	—	—	(25)		(28)		—	—	—	—	—	—	(24)		(25)		—	—	—	—
Total CECONY	$2,799	$2,828		$—		$—	$300	$278	$800	$766	$2,877	$2,899		$—		$—	$346	$322	$723	$764
O&R
Electric	$206	$213		$—		$—	$13	$12	$56	$55	$210	$212		$—		$—	$16	$14	$56	$52
Gas	28	27	—		—		5		(11)	(7)	31	34	—		—		6	5	(10)
Total O&R	$234	$240		$—		$—	$18	$17	$45	$48	$241	$246		$—		$—	$22	$19	$46	$42
Clean Energy Businesses	$177	$350		$—	$(2)		$19	$11	$29	$125	$247	$181		$—		$—	$53	$18	$100	$25
Con Edison Transmission	1	—	—		—		—	—	(2)	(1)	1		—		—		—	—	(1)	(2)
Other (a)	—	(1)	—		2		—	(1)	1	2	(1)	1	—		—		—	1	(1)	(3)
Total Con Edison	$3,211	$3,417		$—		$—	$337	$305	$873	$940	$3,365	$3,328		$—		$—	$421	$360	$867	$826

For the Nine Months Ended September 30,

Operating
revenues
Inter-segment
revenues
Depreciation and
amortization
Operating
income/(loss)
(Millions of Dollars) 2017
2016
2017
2016
2017
2016
2017
2016
CECONY
Electric $6,079 $6,222 $12 $13 $690 $645 $1,477 $1,487
Gas 1,421 1,113 5 4 137 118 362 273
Steam 448 406 55 65 64 62 52 39
Consolidation adjustments —
—
(72) (82) —
—
—
—
Total CECONY $7,948 $7,741
$—

$—
$891 $825 $1,891 $1,799
O&R
Electric $495 $497
$—

$—
$38 $37 $83 $86
Gas 172 133 —
—
15 13 33 28
Total O&R $667 $630
$—

$—
$53 $50 $116 $114
Clean Energy Businesses $460 $998
$—
$7 $54 $30 $63 $184
Con Edison Transmission 1 —
—
—
—
—
(6) (1)
Other (a) (4) (1) —
(7) —
—
2 1
Total Con Edison $9,072 $9,368
$—

$—
$998 $905 $2,066 $2,097

(a)Parent company and consolidation adjustments. Other does not represent a business segment.



	For the Nine Months Ended September 30,
	Operating revenues		Inter-segment revenues				Depreciation and amortization		Operating income/(loss)
(Millions of Dollars)	2019	2018	2019		2018		2019	2018	2019	2018
CECONY
Electric	$6,174	$6,107	$13		$12		$785	$732	$1,374	$1,421
Gas	1,605	1,540	6		6		168	152	414	369
Steam	469	474	52		56		67	65	37	60
Consolidation adjustments	—	—	(71)		(74)		—	—	—	—
Total CECONY	$8,248	$8,121		$—		$—	$1,020	$949	$1,825	$1,850
O&R
Electric	$493	$505		$—		$—	$46	$41	$88	$79
Gas	185	186	—		—		17	16	25	31
Total O&R	$678	$691		$—		$—	$63	$57	$113	$110
Clean Energy Businesses	696	573	—		—		169	55	183	59
Con Edison Transmission	3	3	—		—		1	1	(5)	(5)
Other (a)	(2)	—	—		—		—	(1)	(5)	(7)
Total Con Edison	$9,623	$9,388		$—		$—	$1,253	$1,061	$2,111	$2,007

(a) Parent company and consolidation adjustments. Other does not represent a business segment.

~~Table of Contents~~

Note ~~K —~~L – Derivative Instruments and Hedging Activities

~~Con Edison’s subsidiaries~~The Utilities and the Clean Energy Businesses hedge market price fluctuations associated with physical purchases and sales of electricity, natural gas, steam and, to a lesser extent, refined fuels by using derivative instruments including futures, forwards, basis swaps, options, transmission congestion contracts and financial transmission rights contracts. These are economic hedges, for which the Utilities and the Clean Energy Business do not elect hedge accounting. The Clean Energy Businesses use interest rate swaps to manage the risks associated with interest rates related to outstanding and expected future debt issuances and borrowings. Derivatives are recognized on the consolidated balance sheet at fair value (see Note L)M), unless an exception is available under the accounting rules for derivatives and hedging. Qualifying derivative contracts that have been designated as normal purchases or normal sales contracts are not reported at fair value under the accounting rules.

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In August 2017, the FASB issued amendments to the guidance for derivatives and hedging through ASU 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities.” The amendments in this update provide greater clarification on hedge accounting for risk components, presentation and disclosure of hedging instruments, and overall targeted improvements to simplify hedge accounting. The amendments were effective for reporting periods beginning after December 15, 2018. The application of the guidance did not have a material impact on the Companies’ financial position, results of operations and liquidity because the Companies do not elect hedge accounting for their derivative instruments and hedging activities.

The fair values of the Companies’ ~~commodity~~ derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at September 30, ~~2017~~2019 and December 31, ~~2016~~2018 were:


(Millions of Dollars)	2017				2016				2019				2018
Balance Sheet Location	Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)		Gross Amounts of Recognized Assets/(Liabilities)	Gross Amounts Offset	Net Amounts of Assets/ (Liabilities) (a)
Con Edison
Fair value of derivative assets
Current	$77	$(67)	$10	(b)	$81	$(64)	$17	(b)	$51	$(8)	$43	(b)	$43	$(14)	$29	(b)
Noncurrent	64	(61)	3		49	(43)	6		7	(7)	—		16	(7)	9	(d)
Total fair value of derivative assets	$141	$(128)	$13		$130	$(107)	$23		$58	$(15)	$43		$59	$(21)	$38
Fair value of derivative liabilities
Current	$(141)	$71	$(70)		$(138)	$61	$(77)		$(89)	$17	$(72)	(c)	$(61)	$11	$(50)
Noncurrent	(143)	60	(83)		(91)	52	(39)	(c)	(156)	9	(147)	(c)	(25)	9	(16)	(d)
Total fair value of derivative liabilities	$(284)	$131	$(153)		$(229)	$113	$(116)		$(245)	$26	$(219)		$(86)	$20	$(66)
Net fair value derivative assets/(liabilities)	$(143)	$3	$(140)	(b)	$(99)	$6	$(93)	(b) (c)	$(187)	$11	$(176)		$(27)	$(1)	$(28)
CECONY
Fair value of derivative assets
Current	$55	$(53)	$2	(b)	$52	$(45)	$7	(b)	$42	$(19)	$23	(b)	$25	$(6)	$19	(b)
Noncurrent	57	(55)	2		41	(35)	6		6	(6)	—		11	(5)	6
Total fair value of derivative assets	$112	$(108)	$4		$93	$(80)	$13		$48	$(25)	$23		$36	$(11)	$25
Fair value of derivative liabilities
Current	$(116)	$57	$(59)		$(111)	$45	$(66)		$(61)	$28	$(33)		$(31)	$6	$(25)
Noncurrent	(127)	54	(73)		(77)	44	(33)		(90)	8	(82)		(12)	6	(6)
Total fair value of derivative liabilities	$(243)	$111	$(132)		$(188)	$89	$(99)		$(151)	$36	$(115)		$(43)	$12	$(31)
Net fair value derivative assets/(liabilities)	$(131)	$3	$(128)	(b)	$(95)	$9	$(86)	(b)	$(103)	$11	$(92)		$(7)	$1	$(6)

(a)

Derivative instruments and collateral were offset on the consolidated balance sheet as applicable under the accounting rules. The Companies enter into master agreements for their commodity derivatives. These agreements typically provide offset in the event of contract termination. In such case, generally the non-defaulting party’s payable will be offset by the defaulting party’s payable. The non-defaulting party will customarily notify the defaulting party within a specific time period and come to an agreement on the early termination amount.

(b)

At September 30, ~~2017~~2019 and December 31, ~~2016,~~2018, margin deposits for Con Edison ($~~5 million and $7 million, respectively)~~7 million) and CECONY ($~~5 million and $7 million, respectively)~~6 million) were classified as derivative assets on the consolidated balance sheet, but not included in the table. Margin is collateral, typically cash, that the holder of a derivative instrument is required to deposit in order to transact on an exchange and to cover its potential losses with its broker or the exchange.


(c)	~~Does not include $(1) million~~Includes amounts for interest rate ~~swap.~~swaps of $(7) million in current liabilities and $(57) million in noncurrent liabilities. At September 30, 2019, the Clean Energy Businesses had interest rate swaps with notional amounts of $934 million. The expiration dates of the swaps range from 2024-2041.


(d)	Includes amounts for interest rate swaps of $2 million in noncurrent assets and $(6) million in noncurrent liabilities. At December 31, 2018, the Clean Energy Business had interest rate swaps with notional amounts of $499 million. The expiration dates of the swaps range from 2024-2035.

The Utilities generally recover their prudently incurred fuel, purchased power and gas costs, including hedging gains and losses, in accordance with rate provisions approved by the applicable state utility regulators. In accordance with the accounting rules for regulated operations, the Utilities record a regulatory asset or liability to defer recognition of unrealized gains and losses on their electric and gas derivatives. As gains and losses are realized in future periods, they will be recognized as purchased power, gas and fuel costs in the Companies’ consolidated income statements.

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The Clean Energy Businesses record realized and unrealized gains and losses on their derivative contracts in purchased power, gas purchased for resale and non-utility revenue in the reporting period in which they occur. The Clean Energy Businesses record changes in the fair value of their interest rate swaps in other interest expense at the end of each reporting period. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity ~~prices.~~prices and interest rates.

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The following table presents the realized and unrealized gains or losses on ~~commodity~~ derivatives that have been deferred or recognized in earnings for the three and nine months ended September 30, ~~2017~~2019 and ~~2016:~~2018:


		For the Three Months Ended September 30,										For the Three Months Ended September 30,
		Con Edison					CECONY					Con Edison			CECONY
(Millions of Dollars)	Balance Sheet Location	2017			2016		2017		2016		Balance Sheet Location	2019	2018		2019		2018
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:	Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:										Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$(4)			$(1)		$(3)				Deferred derivative gains	$15	$6		$15		$6
Noncurrent	Deferred derivative gains	1			(2)		1		—		Deferred derivative gains	—	—		—		2
Total deferred gains/(losses)		$(3)			$(3)		$(2)		$(3)			$15	$6		$15		$8
Current	Deferred derivative losses	$(11)			$(19)		$(9)		$(18)		Deferred derivative losses	$6	$25		$6		$25
Current	Recoverable energy costs	(40)			(39)		(38)		(35)		Recoverable energy costs	(35)	(4)		(32)		(6)
Noncurrent	Deferred derivative losses	(12)			(17)		(8)		(14)		Deferred derivative losses	18	15		16		14
Total deferred gains/(losses)		$(63)			$(75)		$(55)		$(67)			$(11)	$36		$(10)		$33
Net deferred gains/(losses)		$(66)			$(78)		$(57)		$(70)			$4	$42		$5		$41
	Income Statement Location										Income Statement Location
Pre-tax gains/(losses) recognized in income	Pre-tax gains/(losses) recognized in income										Pre-tax gains/(losses) recognized in income
	Purchased power expense		$—		$(37)	(b)		$—		$—	Gas purchased for resale	$1		$—		$—		$—
	Gas purchased for resale	(47)			(38)		—		—		Non-utility revenue	5	(7)		—		—
	Non-utility revenue	5		(a)	(2)	(b)	—		—		Other operations and maintenance expense	(1)	—		(1)
											Other interest expense	(26)	—		—		—
Total pre-tax gains/(losses) recognized in income	Total pre-tax gains/(losses) recognized in income	$(42)			$(77)			$—		$—	Total pre-tax gains/(losses) recognized in income	$(21)	$(7)		$(1)			$—


~~(a)~~	~~For the three months ended September 30, 2017, Con Edison recorded an unrealized pre-tax gain in non-utility operating revenue ($6 million).~~


~~(b)~~	~~For the three months ended September 30, 2016, Con Edison recorded unrealized pre-tax losses in non-utility operating revenue ($2 million) and purchased power expense ($23 million).~~



		For the Nine Months Ended September 30,
		Con Edison		CECONY
(Millions of Dollars)	Balance Sheet Location	2019	2018	2019		2018
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current	Deferred derivative gains	$3	$(11)	$3		$(10)
Noncurrent	Deferred derivative gains	(8)	5	(5)		4
Total deferred gains/(losses)		$(5)	$(6)	$(2)		$(6)
Current	Deferred derivative losses	$(32)	$21	$(28)		$23
Current	Recoverable energy costs	(94)	(13)	(82)		(14)
Noncurrent	Deferred derivative losses	(82)	23	(79)		21
Total deferred gains/(losses)		$(208)	$31	$(189)		$30
Net deferred gains/(losses)		$(213)	$25	$(191)		$24
	Income Statement Location
Pre-tax gains/(losses) recognized in income
	Gas purchased for resale	$(2)	$(1)		$—		$—
	Non-utility revenue	20	(7)	—		—
	Other interest expense	(60)	—	—		—
Total pre-tax gains/(losses) recognized in income		$(42)	$(8)		$—		$—

For the Nine Months Ended September 30,
Con Edison CECONY
(Millions of Dollars) Balance Sheet Location 2017
2016 2017
2016
Pre-tax gains/(losses) deferred in accordance with accounting rules for regulated operations:
Current Deferred derivative gains $(26) $6 $(22) $2
Noncurrent Deferred derivative gains (2) (1) (2) (1)
Total deferred gains/(losses) $(28) $5 $(24) $1
Current Deferred derivative losses $10 $19 $11 $16
Current Recoverable energy costs (125) (163) (116) (148)
Noncurrent Deferred derivative losses (40) (5) (36) (3)
Total deferred gains/(losses) $(155) $(149) $(141) $(135)
Net deferred gains/(losses) $(183) $(144) $(165) $(134)
Income Statement Location
Pre-tax gains/(losses) recognized in income
Purchased power expense
$—
$(106) (b)
$—

$—
Gas purchased for resale (161) (72) —
—
Non-utility revenue 11 (a) 15 (b) —
—
Total pre-tax gains/(losses) recognized in income $(150) $(163)
$—

$—


~~(a)~~	~~For the nine months ended September 30, 2017, Con Edison recorded an unrealized pre-tax gain in non-utility operating revenue ($2 million).~~


~~(b)~~	For the nine months ended September 30, 2016, Con Edison recorded unrealized pre-tax gains and losses in non-utility operating revenue ($3 million loss) and purchased power expense ($11 million gain).

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The following table presents the hedged volume of Con Edison’s and CECONY’s commodity derivative transactions at September 30, ~~2017:~~2019:


	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)	Electric Energy (MWh) (a)(b)	Capacity (MW) (a)	Natural Gas (Dt) (a)(b)	Refined Fuels (gallons)
Con Edison	32,596,372	6,790	166,913,644	672,000	27,843,993	25,054	277,395,718	6,720,000
CECONY	30,492,575	3,000	158,500,000	672,000	25,361,275	16,800	260,350,000	6,720,000


(a)	Volumes are reported net of long and short positions, except natural gas collars where the volumes of long positions are reported.


(b)	Excludes electric congestion and gas basis swap contracts, which are associated with electric and gas contracts and hedged volumes.

The Companies are exposed to credit risk related to transactions entered into primarily for the various energy supply and hedging activities by the Utilities and the Clean Energy Businesses. Credit risk relates to the loss that may result from a counterparty’s nonperformance. The Companies use credit policies to manage this risk, including an established credit approval process, monitoring of counterparty limits, netting provisions within agreements, collateral or prepayment arrangements, credit insurance and credit default swaps. The Companies measure credit risk exposure as the replacement cost for open energy commodity and derivative positions plus amounts owed from counterparties for settled transactions. The replacement cost of open positions represents unrealized gains, net of any unrealized losses where the Companies have a legally enforceable right to offset.

At September 30, ~~2017,~~2019, Con Edison and CECONY had ~~$80~~$154 million and $8$6 million of credit exposure in connection with open energy supply net receivables and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of ~~$23~~$58 million with ~~investment-grade counterparties, $23~~independent system operators, $50 million with non-investment grade/non-rated counterparties, ~~$19~~$35 million with ~~independent system operators~~investment-grade counterparties and ~~$15~~$11 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $7$6 million with commodity exchange brokers and ~~$1 million~~an immaterial amount with investment-grade counterparties.

The collateral requirements associated with, and settlement of, derivative transactions are included in net cash flows from operating activities in the Companies’ consolidated statement of cash flows. Most derivative instrument contracts contain provisions that may require a party to provide collateral on its derivative instruments that are in a net liability position. The amount of collateral to be provided will depend on the fair value of the derivative instruments and the party’s credit ratings.

The following table presents the aggregate fair value of the Companies’ derivative instruments with credit-risk-related contingent features that are in a net liability position, the collateral posted for such positions and the additional collateral that would have been required to be posted had the lowest applicable credit rating been reduced one level and to below investment grade at September 30, ~~2017:~~2019:


(Millions of Dollars)	Con Edison (a)		CECONY (a)		Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$148		$131		$112		$95
Collateral posted	61		56		26		20
Additional collateral (b) (downgrade one level from current ratings)	23		22		18		14
Additional collateral (b) (downgrade to below investment grade from current ratings)	101	(c)	88	(c)	123	(c)	92	(c)

(a)

Non-derivative transactions for the purchase and sale of electricity and gas and qualifying derivative instruments, which have been designated as normal purchases or normal sales, are excluded from the table. These transactions primarily include purchases of electricity from independent system operators. In the event the Utilities and the Clean Energy Businesses were no longer extended unsecured credit for such purchases, the Companies would be required to post an immaterial amount of additional collateral ~~of $11 million~~ at September 30, ~~2017.~~2019. For certain other such non-derivative transactions, the Companies could be required to post collateral under certain circumstances, including in the event counterparties had reasonable grounds for insecurity.

(b)

The Companies measure the collateral requirements by taking into consideration the fair value amounts of derivative instruments that contain credit-risk-related contingent features that are in a net liability position plus amounts owed to counterparties for settled transactions and amounts required by counterparties for minimum financial security. The fair value amounts represent unrealized losses, net of any unrealized gains where the Companies have a legally enforceable right to offset.


(c)	Derivative instruments that are net assets have been excluded from the table. At September 30, ~~2017,~~2019, if Con Edison had been downgraded to below investment grade, it would have been required to post additional collateral for such derivative instruments of ~~$13~~$26 million.

~~Interest Rate Swap~~

In December 2016, the Clean Energy Businesses acquired Coram Wind project which holds an interest rate swap that terminates in June 2024, pursuant to which it pays a fixed-rate of 2.0855 percent and receives a LIBOR-based variable rate. The fair value of this interest rate swap was immaterial as of September 30, 2017 and a liability of $1 million as of December 31, 2016 on Con Edison’s consolidated balance sheet.

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Note ~~L —~~M – Fair Value Measurements

The accounting rules for fair value measurements and disclosures 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 in a principal or most advantageous market. Fair value is a market-based measurement that is determined based on inputs, which refer broadly to assumptions that market participants use in pricing assets or

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liabilities. These inputs can be readily observable, market corroborated, or generally unobservable firm inputs. The Companies often make certain assumptions that market participants would use in pricing the asset or liability, including assumptions about risk, and the risks inherent in the inputs to valuation techniques. The Companies use valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.

The accounting rules for fair value measurements and disclosures established a fair value hierarchy, which prioritizes the inputs to valuation techniques used to measure fair value in three broad levels. The rules require that assets and liabilities be classified in their entirety based on the level of input that is significant to the fair value measurement. Assessing the significance of a particular input may require judgment considering factors specific to the asset or liability, and may affect the valuation of the asset or liability and their placement within the fair value hierarchy. The Companies classify fair value balances based on the fair value hierarchy defined by the accounting rules for fair value measurements and disclosures as follows:

Level 1 – Consists of assets or liabilities whose value is based on unadjusted quoted prices in active markets at the measurement date. An active market is one in which transactions for assets or liabilities occur with sufficient frequency and volume to provide pricing information on an ongoing basis. This category includes contracts traded on active exchange markets valued using unadjusted prices quoted directly from the exchange.

Level 2 – Consists of assets or liabilities valued using industry standard models and based on prices, other than quoted prices within Level 1, that are either directly or indirectly observable as of the measurement date. The industry standard models consider observable assumptions including time value, volatility factors and current market and contractual prices for the underlying commodities, in addition to other economic measures. This category includes contracts traded on active exchanges or in over-the-counter markets priced with industry standard models.

Level 3 – Consists of assets or liabilities whose fair value is estimated based on internally developed models or methodologies using inputs that are generally less readily observable and supported by little, if any, market activity at the measurement date. Unobservable inputs are developed based on the best available information and subject to cost benefit constraints. This category includes contracts priced using models that are internally developed and contracts placed in illiquid markets. It also includes contracts that expire after the period of time for which quoted prices are available and internal models are used to determine a significant portion of the value.

~~Table of Contents~~

Assets and liabilities measured at fair value on a recurring basis as of September 30, ~~2017~~2019 and December 31, ~~2016~~2018 are summarized below.


	2017					2016						2019						2018
(Millions of Dollars)	Level 1	Level 2	Level 3	Netting Adjustment (e)	Total	Level 1	Level 2	Level 3		Netting Adjustment (e)	Total	Level 1	Level 2	Level 3	Netting Adjustment (e)		Total	Level 1	Level 2	Level 3	Netting Adjustment (e)	Total
Con Edison
Derivative assets:
Commodity (a)(b)(c)	$6	$28	$2	$(18)	$18	$14	$33	$7		$(24)	$30	$4	$33	$2	$11		$50	$6	$36	$7	$(6)	$43
Interest rate swaps (a)(b)(c)												—	—	—	—		—	—	2	—	—	2
Other (a)(b)(d)	271	118	—	—	389	222	111	—		—	333	330	123	—	—		453	287	114	—	—	401
Total assets	$277	$146	$2	$(18)	$407	$236	$144	$7		$(24)	$363	$334	$156	$2	$11		$503	$293	$152	$7	$(6)	$446
Derivative liabilities:
Commodity (a)(b)(c)	$2	$155	$22	$(26)	$153	$4	$144	$6		$(38)	$116	$18	$98	$46	$(7)		$155	$8	$43	$20	$(11)	$60
Interest Rate Swap (a)(b)(c)	—	—	—	—	—	—	1	—		—	1
Interest rate swaps (a)(b)(c)												—	64	—	—		64	—	6	—	—	6
Total liabilities	$2	$155	$22	$(26)	$153	$4	$145	$6		$(38)	$117	$18	$162	$46	$(7)		$219	$8	$49	$20	$(11)	$66
CECONY
Derivative assets:
Commodity (a)(b)(c)	$5	$12	$1	$(9)	$9	$10	$19	$1		$(10)	$20	$3	$25	$1		$—	$29	$3	$28	$1	$(1)	$31
Other (a)(b)(d)	248	113	—	—	361	200	106	—		—	306	310	117	—	—		427	267	109	—	—	376
Total assets	$253	$125	$1	$(9)	$370	$210	$125	$1		$(10)	$326	$313	$142	$1		$—	$456	$270	$137	$1	$(1)	$407
Derivative liabilities:
Commodity (a)(b)(c)	$1	$133	$15	$(17)	$132	$1	$124		$—	$(26)	$99	$15	$87	$32	$(19)		$115	$5	$30	$3	$(6)	$32


(a)	The Companies’ policy is to review the fair value hierarchy and recognize transfers into and transfers out of the levels at the end of each reporting period. ~~There were~~Con Edison and CECONY had no transfers between levels 1, 2, and 3 ~~for~~during the nine months ended September 30, ~~2017 and for the year ended December 31, 2016.~~2019.

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Con Edison and CECONY had $2 million of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, 2018 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of September 30, 2018 to less than three years as of December 31, 2018.

(b)

Level 2 assets and liabilities include investments held in the deferred compensation plan and/or non-qualified retirement plans, exchange-traded contracts where there is insufficient market liquidity to warrant inclusion in Level 1, certain over-the-counter derivative instruments for electricity, refined products and natural gas. Derivative instruments classified as Level 2 are valued using industry standard models that incorporate corroborated observable inputs; such as pricing services or prices from similar instruments that trade in liquid markets, time value and volatility factors.

(c)

The accounting rules for fair value measurements and disclosures require consideration of the impact of nonperformance risk (including credit risk) from a market participant perspective in the measurement of the fair value of assets and liabilities. At September 30, ~~2017~~2019 and December 31, ~~2016,~~2018, the Companies determined that nonperformance risk would have no material impact on their financial position or results of operations.


(d)	Other assets are comprised of assets such as life insurance contracts within the deferred compensation plan and non-qualified retirement plans.


(e)	Amounts represent the impact of legally-enforceable master netting agreements that allow the Companies to net gain and loss positions and cash collateral held or placed with the same counterparties.

The employees in the Companies’ risk management group develop and maintain the Companies’ valuation policies and procedures for, and verify pricing and fair value valuation of, commodity ~~derivatives.~~derivatives and interest rate swaps. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity ~~derivatives.~~derivatives and interest rate swaps. Fair value and changes in fair value of commodity derivatives and interest rate swaps are reported on a monthly basis to the Companies’ risk committees, comprised of officers and employees of the Companies that oversee energy hedging at the Utilities and the Clean Energy Businesses. The risk management group reports to the Companies’ Vice President and Treasurer.

~~Table of Contents~~

Fair Value of Level 3 at September 30, 2017
Valuation
Techniques
Unobservable Inputs Range
(Millions of Dollars)
Con Edison – Commodity
Electricity $(21) Discounted Cash Flow Forward energy prices (a) $19.00-$76.25 per MWh

Discounted Cash Flow Forward capacity prices (a) $1.26-$9.47 per kW-month
Transmission Congestion Contracts/Financial Transmission Rights 1 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 50.0%
Inter-zonal forward price curves adjusted for historical zonal losses (b) $0.50-$6.75 per MWh
Total Con Edison—Commodity $(20)
CECONY – Commodity
Electricity $(15) Discounted Cash Flow Forward energy prices (a) $20.50-$76.25 per MWh
Transmission Congestion Contracts 1 Discounted Cash Flow Discount to adjust auction prices for inter-zonal forward price curves (b) 50.0%
Total CECONY—Commodity $(14)



	Fair Value of Level 3 at September 30, 2019	Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)	Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$(26)	Discounted Cash Flow	Forward energy prices (a)	$16.20-$71.77 per MWh
	(18)	Discounted Cash Flow	Forward capacity prices (a)	$0.45-$7.75 per kW-month
Natural Gas	(1)	Discounted Cash Flow	Forward natural gas prices (a)	$0.97-$2.43 per Dt
Transmission Congestion Contracts/Financial Transmission Rights	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(1.00)-$7.03 per MWh
Total Con Edison—Commodity	$(44)
CECONY – Commodity
Electricity	$(24)	Discounted Cash Flow	Forward energy prices (a)	$23.40-$71.77 per MWh
	(8)	Discounted Cash Flow	Forward capacity prices (a)	$0.45-$7.75 per kW-month
Transmission Congestion Contracts	1	Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.35-$4.11 per MWh
Total CECONY—Commodity	$(31)


(a)	Generally, increases/(decreases) in this input in isolation would result in a higher/(lower) fair value measurement.


(b)	Generally, increases/(decreases) in this input in isolation would result in a lower/(higher) fair value measurement.

The table listed below provides a reconciliation of the beginning and ending net balances for assets and liabilities measured at fair value as of September 30, ~~2017~~2019 and ~~2016~~2018 and classified as Level 3 in the fair value hierarchy:



	For the Three Months Ended September 30,
	Con Edison		CECONY
(Millions of Dollars)	2019	2018	2019	2018
Beginning balance as of July 1,	$(46)	$(4)	$(30)		$—
Included in earnings	4	4	1	2
Included in regulatory assets and liabilities	(1)	(4)	(1)	—
Settlements	(1)	(6)	(1)	(2)
Ending balance as of September 30,	$(44)	$(10)	$(31)		$—

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For the Three Months Ended September 30,
�� Con Edison CECONY
(Millions of Dollars) 2017
2016 2017
2016
Beginning balance as of July 1, $(10) $5 $(6) $2
Included in earnings 7 (4) 1 —
Included in regulatory assets and liabilities (13) (5) (8) (3)
Sales —
4 —
—
Settlements (4) 1 (1) 1
Ending balance as of September 30, $(20) $1 $(14)
$—


	For the Nine Months Ended September 30,					For the Nine Months Ended September 30,
	Con Edison		CECONY			Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016		2019	2018	2019	2018
Beginning balance as of January 1,	$1	$6	$1	$8		$(13)	$1	$(2)	$4
Included in earnings	8	(1)	1	(1)		(2)	4	1	4
Included in regulatory assets and liabilities	(21)	(11)	(14)	(6)		(32)	(7)	(29)	(5)
Purchases	1	2	1	1
Sales	—	4	—	—
Settlements	(9)	1	(3)	(2)		3	(9)	(1)	(4)
Transfer out of level 3						—	1	—	1
Ending balance as of September 30,	$(20)	$1	$(14)		$—	$(44)	$(10)	$(31)		$—

For the Utilities, realized gains and losses on Level 3 commodity derivative assets and liabilities are reported as part of purchased power, gas and fuel costs. The Utilities generally recover these costs in accordance with rate provisions approved by the applicable state public utilities regulators. Unrealized gains and losses for commodity derivatives are generally deferred on the consolidated balance sheet in accordance with the accounting rules for regulated operations.

For the Clean Energy Businesses, realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ~~(immaterial for both periods)~~($3 million gain and $1 million loss) and purchased power costs ~~($4 million gain and $5 million loss)~~(immaterial for both periods) on the consolidated income statement for the three months ended September 30, ~~2017~~2019 and ~~2016,~~2018, respectively. Realized and unrealized gains and losses on Level 3 commodity derivative assets and liabilities are reported in non-utility revenues ~~(immaterial for both periods)~~($2 million gain and $4 million loss) and purchased power costs ~~($3 million gain and $6 million loss)~~(immaterial for both periods) on the consolidated income statement for the nine months ended September 30, ~~2017~~2019 and ~~2016,~~2018, respectively. The change in fair value relating to Level 3 commodity derivative assets and liabilities held at September 30, ~~2017~~2019 and ~~2016~~2018 is included in non-utility revenues ~~(immaterial for both periods)~~($3 million gain and $1 million loss) and purchased power costs ~~($4 million gain and $4 million loss)~~(immaterial for both periods) on the consolidated income statement for the three months ended

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September 30, ~~2017~~2019 and ~~2016,~~2018, respectively. For the nine months ended September 30, ~~2017~~2019 and ~~2016,~~2018, the change in fair value relating to Level 3 commodity ~~derivative~~derivatives assets and liabilities is included in non-utility revenues ~~(immaterial for both periods)~~($2 million gain and $5 million loss) and purchased power costs ~~($2 million gain and $2 million loss)~~(immaterial for both periods), respectively, on the consolidated income ~~statement, respectively.~~statement.

Note ~~M —~~N – Variable Interest Entities

~~Con Edison enters~~The accounting rules for consolidation address the consolidation of a variable interest entity (VIE) by a business enterprise that is the primary beneficiary. A VIE is an entity that does not have a sufficient equity investment at risk to permit it to finance its activities without additional subordinated financial support, or whose equity investors lack the characteristics of a controlling financial interest. The primary beneficiary is the business enterprise that has the power to direct the activities of the VIE that most significantly impact the VIE’s economic performance and either absorbs a significant amount of the VIE’s losses or has the right to receive benefits that could be significant to the VIE.

The Companies enter into arrangements including leases, partnerships and electricity purchase agreements, with various entities. As a result of these arrangements, ~~Con Edison retains~~the Companies retain or may retain a variable interest in these entities.

CECONY

CECONY has an ongoing long-term electricity purchase agreement with Brooklyn Navy Yard Cogeneration Partners, LP, a potential ~~variable interest entity (VIE).~~VIE. In ~~April 2017, CECONY's long-term electricity purchase agreement with Cogen Technologies Linden Venture, LP, another potential VIE, expired. In 2016, requests were~~2018, a request was made of ~~these counterparties~~this counterparty for information necessary to determine whether the entity was a VIE and whether CECONY is the primary beneficiary; however, the information was not made available. The payments for ~~these contracts~~this contract constitute CECONY’s maximum exposure to loss with respect to the potential ~~VIEs.~~VIE.

~~The following table summarizes~~Con Edison Development

In September 2019, Con Edison Development, which previously owned an 80 percent membership interest in OCI Solar San Antonio 4 LLC (Texas Solar 4), acquired the ~~VIEs~~remaining 20 percent interest. Texas Solar 4 is a consolidated entity. Prior to the acquisition, Con Edison had a variable interest in Texas Solar 4, as to which Con Edison ~~Development has entered into as of September 30, 2017:~~

Project Name (a)
Generating
Capacity (b)
(MW AC)
Power Purchase Agreement Term (in Years)
Year of
Initial
Investment
Location
Maximum
Exposure to Loss
(Millions of Dollars) (c)
Copper Mountain Solar 3 128 20 2014 Nevada $175
Mesquite Solar 1 83 20 2013 Arizona 102
Copper Mountain Solar 2 75 25 2013 Nevada 83
California Solar 55 25 2012 California 64
Broken Bow II 38 25 2014 Nebraska 44
Texas Solar 4 32 25 2014 Texas 47

(a) With the exception of Texas Solar 4, Con Edison’s ownership interest is 50 percent and these projects are accounted for using the equity method of accounting. With the exception of Texas Solar 4, Con Edison is notwas the primary beneficiary since the power to direct the activities that most significantly impact the economics of ~~the entities are shared equally between~~Texas Solar 4 was held by a Con Edison Development ~~and third parties. Con Edison’s ownership interest in~~subsidiary. Texas Solar 4 owns a project company that developed a 40 MW (AC) solar electric production project. Electricity generated by the project is ~~80 percent~~sold

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pursuant to a long-term power purchase agreement. Con Edison's losses from Texas Solar 4 for the three and ~~is consolidated~~nine months ended September 30, 2019 and 2018 were immaterial.

In December 2018, a Con Edison Development subsidiary completed its acquisition of Sempra Solar Holdings, LLC. Included in the ~~financial statements.~~acquisition were certain operating projects (Tax Equity Projects) with a noncontrolling tax equity investor to which a percentage of earnings, tax attributes and cash flows are allocated. The Tax Equity Projects are consolidated entities in which Con Edison has less than a 100 percent membership interest. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of ~~Texas Solar 4~~the Tax Equity Projects is held by Con Edison ~~Development.~~

~~(b) Represents Con Edison Development’s ownership interest in~~Development subsidiaries. Electricity generated by the ~~project.~~

~~(c)~~Tax Equity Projects is sold to utilities and municipalities pursuant to long-term power purchase agreements. For investments accounted for under the equity method, maximum exposure is equal to the carrying value of the investment on the consolidated balance sheet. For consolidated investments, such as Texas Solar 4, maximum exposure is equal to the net assets of the project on the consolidated balance sheet less any applicable noncontrolling interest ($7 million for Texas Solar 4). Con Edison did not provide any financial or other support during the three months ended September 30, 2019, the hypothetical liquidation at book value (HLBV) method of accounting for the Tax Equity Projects resulted in $30 million of income ($23 million, after tax) for the tax equity investor and a $13 million loss ($10 million, after tax) for Con Edison. For the nine months ended September 30, ~~2017 that was not previously contractually required.~~2019, the HLBV method of accounting for the Tax Equity Projects resulted in $79 million of income ($60 million, after-tax) for the tax equity investor and a $47 million loss ($36 million, after-tax) for Con Edison.

At September 30, 2019 and December 31, 2018, Con Edison’s consolidated balance sheet included the following amounts associated with its VIEs:



	Tax Equity Projects
	Great Valley Solar (c)(d)				Copper Mountain - Mesquite Solar (c)(e)				Texas Solar 4 (c)(f)
(Millions of Dollars)	2019		2018		2019		2018		2018
Restricted cash		$—		$—		$—		$—	$4
Non-utility property, less accumulated depreciation (g)(h)	295		313		465		492		98
Other assets	47		18		131		97		9
Total assets (a)	$342		$331		$596		$589		$111
Long-term debt due within one year		$—		$—		$—		$—	$2
Other liabilities	19		17		22		33		26
Long-term debt	—		—		—		—		56
Total liabilities (b)	$19		$17		$22		$33		$84


(a)	The assets of the Tax Equity Projects represent assets of a consolidated VIE that can be used only to settle obligations of the consolidated VIE.


(b)	The liabilities of the Tax Equity Projects represent liabilities of a consolidated VIE for which creditors do not have recourse to the general credit of the primary beneficiary.


(c)	Con Edison did not provide any financial or other support during the year that was not previously contractually required.


(d)	Great Valley Solar consists of the Great Valley Solar 1, Great Valley Solar 2, Great Valley Solar 3 and Great Valley Solar 4 projects, for which the noncontrolling interest of the tax equity investor was $57 million and $33 million at September 30, 2019 and December 31, 2018, respectively.


(e)	Copper Mountain - Mesquite Solar consists of the Copper Mountain Solar 4, Mesquite Solar 2 and Mesquite Solar 3 projects for which the noncontrolling interest of the tax equity investor was $115 million and $71 million at September 30, 2019 and December 31, 2018, respectively.


(f)	Noncontrolling interest of the third party was $7 million at December 31, 2018.


(g)	Non-utility property is reduced by accumulated depreciation of $7 million for Great Valley Solar and $10 million for Copper Mountain - Mesquite Solar at September 30, 2019.


(h)	Non-utility property is reduced by accumulated depreciation of $1 million for Great Valley Solar, $1 million for Copper Mountain - Mesquite Solar and $15 million for Texas Solar 4 at December 31, 2018.

Note ~~N —~~O – New Financial Accounting Standards

In May 2014, the Financial Accounting Standards Board (FASB) and the International Accounting Standards Board jointly issued a revenue recognition standard that will supersede the revenue recognition requirements within Accounting Standards Codification Topic 605, “Revenue Recognition,” and most industry-specific guidance under the Codification through Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers (Topic 606).” The purpose of the new guidance is to create a consistent framework for revenue recognition. The guidance clarifies how to measure and recognize revenue arising from customer contracts to depict the transfer of goods or services in an amount that reflects the consideration the entity expects to receive. Amendments were issued subsequently to clarify key areas including principal/agent considerations, performance obligations, licensing, sales taxes, noncash consideration, and contracts. The new standard is effective for reporting periods beginning after December 15, 2017. Early adoption is permitted for reporting periods beginning after December 15,June 2016, ~~however, the Companies plan to adopt the new standard for reporting periods beginning after December 15, 2017.~~

Under the new standard, companies may use either of the following transition methods: (i) a full retrospective approach reflecting the application of the standard in each prior reporting period with the option to elect certain practical expedients, or (ii) a modified retrospective approach with the cumulative effect of initially adopting ASU

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~~2014-09 recognized at the date of adoption (which includes additional footnote disclosures). The Companies anticipate using the modified retrospective approach.~~

~~The Companies have completed their analyses of the impact of the new standard on the majority of their various revenue streams.~~

The majority of the Companies’ sales are derived from tariffs to provide electric, gas, and steam service to customers. For such tariffs, the Companies expect that the revenue from contracts with customers under ASU 2014-09 will be equivalent to revenue from electricity, gas, or steam supplied in that period which is consistent with current practice. Consequently, the Companies do not anticipate that the new standard will materially impact the amount and/or timing of such revenues.

Con Edison has also completed its evaluation for the majority of the revenue at the Clean Energy Businesses, including revenue from the sale of energy-related products and services to retail customers, revenue from operating renewable and energy infrastructure projects, and revenue from the sale of renewable energy credits. For such revenues, Con Edison expects that the revenue from contracts with customers under ASU 2014-09 will not be materially different from revenue recorded consistent with current practice. Consequently, Con Edison does not anticipate that the new standard will materially impact the amount and/or timing of such revenues.

The Companies continue to review the potential impacts of the remaining revenue at the Utilities and the Clean Energy Businesses on the Companies' financial position, results of operations and liquidity as well as the additional disclosures and related controls required under the new standard, and anticipate completing such reviews during the fourth quarter of 2017.

In February 2016, the FASB issued amendments on financial reporting of leasing transactions through ASU No. 2016-02, “Leases (Topic 842)." The amendments require lessees to recognize assets and liabilities on the balance sheet and disclose key information about leasing arrangements. Lessees will need to recognize a right-of-use asset and a lease liability for virtually all of their leases (other than leases that meet the definition of a short-term lease). Lessor accounting is similar to the current model, but updated to align with certain changes to the lessee model. For income statement purposes, the pattern of expense recognition will be dependent on whether transactions are designated as operating leases or finance leases. The amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The amendments must be adopted using a modified retrospective transition and provide for certain practical expedients. Based on the existing portfolio of leases at implementation, for leases currently classified as operating leases, the Companies expect to recognize on the statements of financial position right-of-use assets and lease liabilities. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ results of operations and liquidity.

~~In January 2017,~~ the FASB issued amendments to the guidance for ~~Business Combinations~~recognition of credit losses for financial instruments through ASU ~~2017-01, “Business Combinations~~2016-13, “Financial Instruments-Credit Losses (Topic ~~805)~~326): ~~Clarifying the Definition~~Measurement of ~~a Business.~~Credit Losses on Financial Instruments.” The amendments replace the incurred loss impairment methodology which involved delayed recognition of credit losses. The amendments introduce an expected credit loss impairment model which requires immediate recognition of anticipated losses over the instrument’s life. A broader range of reasonable and supportable information must be considered in ~~this update clarify~~developing the ~~definition of a business~~credit loss estimates. The Companies' financial instruments that would be subject to the amendments include their accounts receivable - customers and ~~provide guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses.~~other receivables. For public entities, the amendments are effective, and the Companies plan to adopt the amendments, for reporting periods beginning after December 15, ~~2017. Early~~2019. The adoption ~~is permitted. The application~~ of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity. The Companies will implement additional internal controls related to the amendments, however the adoption of the amendments is not expected to require a change that will materially affect the Companies’ internal control over financial reporting.

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In January 2017, the FASB issued amendments to the guidance for the subsequent measurement of goodwill through ASU 2017-04, “Intangibles-Goodwill and Other (Topic 350): Simplifying the Test for Goodwill Impairment.” The amendments in this update simplify goodwill impairment testing by eliminating Step 2 of the goodwill impairment test wherein an entity has to compute the implied fair value of goodwill by performing procedures to determine the fair value of its assets and liabilities. Under the new guidance, an entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value up to the total amount of goodwill allocated to that reporting unit. For public entities, the amendments are effective for reporting periods beginning after December 15, 2019. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In February 2017, the FASB issued amendments to the guidance for other income through ASU 2017-05, “Other Income-Gains and Losses from the Derecognition of Nonfinancial Assets (Subtopic 610-20): Clarifying the Scope of Asset Derecognition Guidance and Accounting for Partial Sales of Nonfinancial Assets.” The amendments in this update clarify the scope of assets within Subtopic 610-20 and add guidance for partial sales of nonfinancial assets. The amendments are effective upon the adoption of ASU 2014-09, and therefore will be effective for reporting

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periods beginning after December 15, 2017. The Company is in the process of evaluating the potential impact of the new guidance on the Company’s financial position, results of operations and liquidity.

In March 2017, the FASB issued amendments to the guidance for retirement benefits through ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost.” The amendments in this update modify the presentation of net benefit cost, where the service component must be disaggregated from the other components of net benefit cost and be presented in the same line item as current employee compensation costs. The remaining components of the net benefit cost should be presented outside of income from operations. Additionally, the update allows only the service cost component to be eligible for capitalization. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

In March 2017, the FASB issued amendments to the guidance for debt securities through ASU 2017-08, “Receivables-Nonrefundable Fees and Other Costs (Subtopic 310-20): Premium Amortization on Purchased Callable Debt Securities.” The amendments in this update shorten the amortization period for certain callable debt securities held at a premium. The amendments do not require an accounting change for securities held at a discount; the discount continues to be amortized to maturity. For public entities, the amendments are effective for reporting periods beginning after December 15, 2018. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In May 2017, the FASB issued amendments to the guidance for stock compensation through ASU 2017-09, “Compensation-Stock Compensation (Topic 718): Scope of Modification Accounting.” The amendments in this update specify that changes to value, vesting conditions, or classification of an existing share-based payment award require application of modification accounting in Topic 718. For public entities, the amendments are effective for reporting periods beginning after December 15, 2017. Early adoption is permitted. The application of this guidance is not expected to have a material impact on the Companies’ financial position, results of operations and liquidity.

In August 2017, the FASB issued amendments to the guidance for derivatives and hedging through ASU 2017-12, “Derivatives and Hedging (Topic 815): Targeted Improvements to Accounting for Hedging Activities.” The amendments in this update provide greater clarification on hedge accounting for risk components, presentation and disclosure of hedging instruments, and overall targeted improvements to simplify hedge accounting. For public entities, the amendments are effective for reporting periods beginning after December 15, 2018 and interim periods within those fiscal years. Early adoption is permitted. The Companies are in the process of evaluating the potential impact of the new guidance on the Companies’ financial position, results of operations and liquidity.

~~Note O — Dispositions~~

~~Upton 2~~

In May 2017, Con Edison Development sold Upton 2, a development stage solar electric production project, for $11 million to Vistra Asset Co. and recorded a $1 million gain on sale ($0.7 million, net of taxes). In addition, Con Edison Development agreed to perform the engineering, procurement and construction for the 180 MW (AC) project, which is expected to be substantially completed in 2018.

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Item 2: Management’s Discussion and Analysis of Financial Condition and Results of Operations

This combined management’s discussion and analysis of financial condition and results of operations (MD&A) relates to the consolidated financial statements (the Third Quarter Financial Statements) included in this report of two separate registrants: Consolidated Edison, Inc. (Con Edison) and Consolidated Edison Company of New York, Inc. (CECONY). As used in this report, the term the “Companies” refers to Con Edison and CECONY. CECONY is a subsidiary of Con Edison and, as such, information in this management’s discussion and analysis about CECONY applies to Con Edison.

This MD&A should be read in conjunction with the Third Quarter Financial Statements and the notes thereto, the MD&A in Item 7 of the Companies’ combined Annual Report on Form 10-K for the year ended December 31, ~~2016~~2018 (File Nos. 1-14514 and 1-1217, the Form 10-K) and the MD&A in Part 1, Item 2 of the Companies' combined Quarterly ~~Reports~~Report on Form 10-Q for the quarterly periods ended March 31, ~~2017~~2019 and June 30, ~~2017~~2019 (File Nos. 1-14514 and 1-1217).

Information in any item of this report referred to in this discussion and analysis is incorporated by reference herein. The use of terms such as “see” or “refer to” shall be deemed to incorporate by reference into this discussion and analysis the information to which reference is made.

Con Edison, incorporated in New York State in 1997, is a holding company that owns all of the outstanding common stock of CECONY, Orange and Rockland Utilities, Inc. (O&R), Con Edison Clean Energy Businesses, Inc. and Con Edison Transmission, Inc. As used in this report, the term the “Utilities” refers to CECONY and O&R.

Con Edison’s principal business operations are those of CECONY, O&R, the Clean Energy Businesses and Con Edison Transmission. CECONY’s principal business operations are its regulated electric, gas and steam delivery businesses. O&R’s principal business operations are its regulated electric and gas delivery businesses. The Clean Energy Businesses develop, own and operate renewable and energy infrastructure projects and provide ~~energy-related~~energy-

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related products and services to wholesale and retail customers. Con Edison Transmission invests in electric transmission facilities and gas pipeline and storage facilities.

Con Edison seeks to provide shareholder value through continued dividend growth, supported by earnings growth in regulated utilities and contracted assets. The company invests to provide reliable, resilient, safe and clean energy critical for New York City’s growing economy. The company is an industry leading owner and operator of contracted, large-scale solar generation in the United States. Con Edison is a responsible neighbor, helping the communities it serves become more sustainable.

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CECONY

Electric

CECONY provides electric service to approximately ~~3.4~~3.5 million customers in all of New York City (except a part of Queens) and most of Westchester County, an approximately 660 square mile service area with a population of more than nine million.

During the summer of ~~2017,~~2019, electric peak demand in CECONY's service area was ~~12,321~~12,389 MW (which occurred on July ~~20, 2017)~~17, 2019). At design conditions, electric peak demand in the company's service area would have been approximately ~~13,270~~13,222 MW in ~~2017~~2019 compared to the company's forecast of ~~13,470~~13,270 MW. The ~~company's~~company decreased its five-year forecast of average annual ~~growth of the~~change in electric peak demand in its service area at design conditions isfrom approximately 0.1 percent ~~for 2018~~(for 2019 to ~~2022 (as compared~~2023) to approximately ~~0.2~~(0.1) percent ~~for 2017~~(for 2020 to ~~2021)~~2024).

Gas

CECONY delivers gas to approximately 1.1 million customers in Manhattan, the Bronx, parts of Queens and most of Westchester County.

In May ~~2017,~~2019, the company ~~decreased~~increased its five-year forecast of average annual growth of the peak gas demand in its service area at design conditions from approximately ~~2.3~~1.3 percent(for 2019 to 2023) to approximately 1.5 percent (for ~~2017~~2020 to ~~2021) to 1.6 percent (for 2018 to 2022)~~2024). The ~~decrease~~increase reflects ~~among other things, that~~increased applications for firm gas service in ~~rolling~~advance of the ~~forecast forward~~March 15, 2019 start of a ~~year, another year~~temporary moratorium on new applications in most of ~~oil-to-gas conversions has been completed and fewer opportunities to convert remain.~~Westchester County.

Steam

CECONY operates the largest steam distribution system in the United States by producing and delivering approximately ~~19,500~~20,445 MMlb of steam annually to approximately ~~1,640~~1,591 customers in parts of Manhattan.

In July 2019, the company's five-year forecast of average annual change in the peak steam demand in its service area at design conditions increased from approximately (0.5) percent (for 2019 to 2023) to (0.4) percent (for 2020 to 2024).

O&R

Electric

O&R and its utility subsidiary, Rockland Electric Company (RECO) (together referred to herein as O&R) provide electric service to approximately 0.3 million customers in southeastern New York and northern New Jersey, an approximately 1,300 square mile service area.

During the summer of ~~2017,~~2019, electric peak demand in O&R's service area was ~~1,410~~1,446 MW (which occurred on ~~June 13, 2017)~~July 21, 2019). At design conditions, electric peak demand in the company's service area would have been approximately ~~1,615~~1,543 MW in ~~2017~~2019 compared to the company's forecast of ~~1,625~~1,585 MW. The ~~company’s~~company increased its five-year forecast of average annual ~~growth of the~~change in electric peak demand in its service area at design conditions ~~is flat for 2018~~from approximately (0.3) percent (for 2019 to ~~2022 (as compared~~2023) to approximately ~~(0.1)~~(0.2) percent ~~for 2017~~(for 2020 to ~~2021)~~2024).

Gas

O&R delivers gas to over 0.1 million customers in southeastern New York.

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In May 2019, the company increased its five-year forecast of average annual growth of the peak gas demand in its service area at design conditions from approximately 0.6 percent (for 2019 to 2023) to 0.7 percent (for 2020 to 2024).

Clean Energy Businesses

Con Edison Clean Energy Businesses, Inc. has three wholly-owned subsidiaries: Consolidated Edison Development, Inc. (Con Edison Development), Consolidated Edison Energy, Inc. (Con Edison Energy) and Consolidated Edison Solutions, Inc. (Con Edison Solutions). Con Edison Clean Energy Businesses, Inc., together with these subsidiaries, ~~(which were formerly referred to as the competitive energy businesses),~~ are referred to in this report as the Clean Energy Businesses.

~~In September 2016, Con Edison sold the retail electric supply business of its~~ The Clean Energy Businesses develop, own and operate renewable and energy infrastructure projects and provide energy-related

products and services to ~~a subsidiary of Exelon Corporation for cash consideration of $235 million.~~wholesale and retail customers. In ~~addition, Con Edison received $23 million in cash as~~December 2018, a ~~working capital adjustment in February 2017.~~

~~In May 2017,~~ Con Edison Development sold a development-stage solar electric production project for $11 million and agreed to perform engineering, procurement and construction for the project. See Note O to the Third Quarter Financial Statements.subsidiary acquired Sempra Solar Holdings, LLC.

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Con Edison Transmission

Con Edison Transmission, Inc. invests in electric and gas transmission projects through its wholly-owned subsidiaries, Consolidated Edison Transmission, LLC (CET Electric) and Con Edison Gas Pipeline and Storage, LLC (CET Gas). CET Electric owns a 45.7 percent interest in New York Transco LLC (NY Transco), which owns and is proposing to build additional electric transmission assets in New York. CET Gas owns, through subsidiaries, a 50 percent interest in Stagecoach Gas Services, LLC, a joint venture that owns ~~operates~~ and ~~will further develop~~operates an existing gas pipeline and storage business located in northern Pennsylvania and southern New York. Also, CET Gas and CECONY own 71.2 percent and 28.8 percent interests, respectively, in Honeoye Storage Corporation which owns and operates a gas storage ~~business~~facility in upstate New York. In addition, CET Gas owns a 12.5 percent interest in Mountain Valley Pipeline LLC, a joint venture developing a proposed ~~300 mile~~300-mile gas transmission project in West Virginia and ~~Virginia (Mountain Valley Pipeline).~~Virginia. Con Edison Transmission, Inc., together with CET Electric and CET Gas, are referred to in this report as Con Edison Transmission.

In October 2017, FERC issued a Certificate of Public Convenience and Necessity for the Mountain Valley Pipeline. The project has an estimated total cost of $3,000 million to $3,500 million and an in-service date targeted for late 2018.

Certain financial data of Con Edison’s businesses are presented below:


	For the Three Months Ended September 30, 2017						For the Nine Months Ended September 30, 2017						At September 30, 2017			For the Three Months Ended September 30, 2019						For the Nine Months Ended September 30, 2019						At September 30, 2019
(Millions of Dollars, except percentages)	Operating Revenues			Net Income			Operating Revenues			Net Income			Assets			Operating Revenues			Net Income for Common Stock			Operating Revenues			Net Income for Common Stock			Assets
CECONY	$2,799	87	%	$401	88	%	$7,948	88	%	$883	87	%	$41,647	85	%	$2,877	86	%	$414	88	%	$8,248	86	%	$978	93	%	$44,808	80	%
O&R	234	7		22	5		667	7		53	5		2,832	6		241	7		25	5		678	7		60	6		2,935	5
Total Utilities	3,033	94		423	93		8,615	95		936	92		44,479	91		3,118	93		439	93		8,926	93		1,038	99		47,743	85
Clean Energy Businesses (a)	177	6		26	5		460	5		54	5		2,811	6		247	7		22	5		696	7		(19)	(2	)	6,376	12
Con Edison Transmission	1	—		9	2		1	—		25	2		1,210	2		1	—		14	2		3	—		38	4		1,559	3
Other (b)	—	—		(1)	—		(4)	—		5	1		746	1		(1)	—		(2)	—		(2)	—		(9)	(1	)	262	—
Total Con Edison	$3,211	100	%	$457	100	%	$9,072	100	%	$1,020	100	%	$49,246	100	%	$3,365	100	%	$473	100	%	$9,623	100	%	$1,048	100	%	$55,940	100	%

(a)

Net income for common stock from the Clean Energy Businesses includes for the nine months ended September 30, 2017 $1 million net after-tax gain related to the sale of a development stage solar electric production project (see Note O to the Third Quarter Financial Statements). Also includes for the three and nine months ended September 30, ~~2017 $4~~2019 includes $(17) million and $1$(41) million, respectively, of net after-tax mark-to-market ~~gains, respectively.~~losses and reflects $23 million (after-tax) and $60 million (after-tax), respectively, of income attributable to the non-controlling interest of a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. See Note N to the Third Quarter Financial Statements.


(b)	Other includes parent company and consolidation adjustments.

Results of Operations

Net income for common stock and earnings per share for the three and nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 were as follows:

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	For the Three Months Ended September 30,							For the Nine Months Ended September 30,							For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2017	2016	2017		2016			2017	2016	2017		2016			2019	2018	2019	2018	2019	2018	2019	2018
(Millions of Dollars, except per share amounts)	Net Income		Earnings per Share					Net Income		Earnings per Share					Net Income for Common Stock		Earnings per Share		Net Income for Common Stock		Earnings per Share
CECONY	$401	$388		$1.30		$1.27		$883	$859		$2.88		$2.87		$414	$431	$1.25	$1.38	$978	$969	$2.99	$3.12
O&R	22	27	0.07		0.09			53	55	0.18		0.18			25	21	0.07		60	52	0.18	0.17
Clean Energy Businesses (a)	26	78	0.08		0.26			54	120	0.18		0.40			22	27	0.07	0.10	(19)	58	(0.06)	0.19
Con Edison Transmission	9	10	0.03		0.03			25	11	0.08		0.04			14	13	0.04		38	35	0.11
Other (b)	(1)	(6)	—		(0.02		)	5	(6)	0.01		(0.02		)	(2)	(57)	(0.01)	(0.19)	(9)	(63)	(0.02)	(0.21)
Con Edison (c)	$457	$497		$1.48		$1.63		$1,020	$1,039		$3.33		$3.47		$473	$435	$1.42	$1.40	$1,048	$1,051	$3.20	$3.38

(a)

~~Includes $4 million or $0.01 a share and $(15) million or $(0.05) a share of net after-tax mark-to-market gains/(losses)~~Net income for common stock from the three months ended September 30, 2017 and 2016, respectively, and $1 million or $0.01 a share and $5 million or $0.02 a share of net after-tax mark-to-market gains/(losses) for the nine months ended September 30, 2017 and 2016, respectively. Also includes a $1 million or $0.00 a share net after-tax gain on the sale of a solar electric production project for the nine months ended September 30, 2017 (see Note O to the Third Quarter Financial Statements) and a $47 million or $0.15 a share of net gain related to the sale of the retail electric supply business, $5 million or $0.02 a share of net gain related to the acquisition of a solar electric production investmentClean Energy Businesses for the three and nine months ended September 30, ~~2016 and a $5~~2019 includes $(17) million or ~~$0.02~~$(0.05) a share and $(41) million or $(0.13) a share, respectively, of net ~~loss related~~after-tax mark-to-market losses and reflects $23 million or $0.07 a share (after-tax) and $60 million or $0.18 a share (after-tax), respectively, of income attributable to the ~~impairment~~non-controlling interest of a ~~solar~~tax equity investor in renewable electric production ~~investment~~projects accounted for under the HLBV method of accounting. See Note N to the Third Quarter Financial Statements. Net income for common stock from the Clean Energy Businesses for the three and nine months ended September 30, ~~2016.~~2018 includes $(2) million or $0.00 a share and $(3) million or $(0.01) a share, respectively, of net after-tax mark-to-market losses.

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(b)

Other includes parent company and consolidation adjustments. Includes $(42) million or $(0.14) a share of income tax expense resulting from a re-measurement of the company's deferred tax assets and liabilities following the issuance of proposed regulations relating to the TCJA for the three and nine months ended September 30, 2018. See Note I to the Third Quarter Financial Statements. Also includes for the three and nine months ended September 30, 2018 $10 million (net of tax) or $0.03 a share of transaction costs related to a Con Edison Development subsidiary’s agreement to purchase Sempra Solar Holdings, LLC.


(c)	Earnings per share on a diluted basis were ~~$1.48~~$1.42 a share and ~~$1.62~~$1.39 a share for the three months ended September 30, ~~2017~~2019 and ~~2016,~~2018, respectively, and ~~$3.31~~$3.19 a share and ~~$3.46~~$3.37 a share for the nine months ended September 30, ~~2017~~2019 and ~~2016,~~2018, respectively.

The ~~Companies’ results~~following tables present the estimated effect of ~~operations~~major factors on earnings per share and net income for common stock for the three and nine months ended September 30, ~~2017,~~2019 as compared with the 2016 periods, reflect changes in rate plans and regulatory charges and the impact of weather on steam revenues. The new electric rate plan of CECONY includes changes in the timing of recognition of annual revenues between quarters. Operations and maintenance expenses for CECONY for the three and nine months ended September 30, 2017 primarily reflect lower costs for pensions and other postretirement benefits. In addition, the Utilities' rate plans provide for revenues to cover expected changes in certain operating costs including depreciation, property taxes and other tax matters.2018 periods.

The following table presents the estimated effect on earnings per share and net income for the three and nine months ended September 30, 2017 period as compared with 2016 period, resulting from these and other major factors:

Three Months Variation Nine Months Variation
(Millions of Dollars, except per share amounts) Earnings
per Share
Variation Net Income
Variation Earnings
per Share
Variation Net Income
Variation
CECONY (a)
Changes in rate plans and regulatory charges (b) $0.12 $35 $0.29 $87
Weather impact on steam revenues —
(1) 0.01 4
Other operations and maintenance expenses (c) 0.07 22 0.24 73
Depreciation, property taxes and other tax matters (d) (0.10) (30) (0.36) (108)
Other (e) (0.06) (13) (0.17) (32)
Total CECONY 0.03 13 0.01 24
O&R (a)

Changes in rate plans and regulatory charges —
1 0.04 12
Other operations and maintenance expenses (f) (0.01) (2) (0.03) (9)
Depreciation and property taxes (0.01) (4) (0.02) (6)
Other (e) —
—
0.01 1
Total O&R (0.02) (5) —
(2)
Clean Energy Businesses

Operating revenues less energy costs (g) 0.10 32 0.10 31
Other operations and maintenance expenses (h) (0.08) (23) (0.10) (30)
Depreciation (0.02) (5) (0.05) (15)
Net interest expense (0.01) (3) (0.02) (6)
Other (e) (i) (0.17) (53) (0.15) (46)
Total Clean Energy Businesses (0.18) (52) (0.22) (66)
Con Edison Transmission (e) (j) —
(1) 0.04 14
Other, including parent company expenses (e) (k) 0.02 5 0.03 11
Total variations $(0.15) $(40) $(0.14) $(19)

~~(a)~~

Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans and the weather-normalization clause applicable to their gas businesses, revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. In general, the Utilities recover on a current basis the fuel, gas purchased for resale and purchased power costs they incur in supplying energy to their full-service customers. Accordingly, such costs do not generally affect the Companies' results of operations.

~~(b)~~

For the three and nine months ended September 30, 2017 as compared to the 2016 periods, reflects lower electric net base revenues of $(0.03) a share, resulting from the timing of recognition of annual revenues between quarters under CECONY's new electric rate plan. Also, for the three and nine months ended September 30, 2017 as compared with the 2016 periods, reflects higher electric net base revenues ($0.07 a share and $0.08 a share, respectively), resulting from the increased base rates under CECONY's new electric rate plan, higher gas net base revenues ($0.01 a share and $0.16 a share, respectively), incentives earned under the electric Earnings Adjustment Mechanisms of $0.02 a share, a property tax refund incentive of $0.01 a share and an increase to the regulatory reserve related to certain gas proceedings in 2016 ($0.02 a share and $0.03 a share, respectively). For the nine months ended September 30, 2017 as compared with the 2016 period, reflects growth in the number of gas customers of $0.03 a share.


~~(c)~~	~~Reflects lower pension and other postretirement benefits costs of $0.07 a share and $0.22 a share for the three and nine months ended September 30, 2017 as compared with the 2016 periods.~~


~~(d)~~	Reflects higher depreciation and amortization expense of $(0.04) a share and $(0.13) a share, property taxes of $(0.04) a share and $(0.13) a share, and income taxes of $(0.02) a share and $(0.10) a share for the three and nine months ended September 30, 2017 as compared with the 2016 periods.


~~(e)~~	~~Includes the impact of the dilutive effect of Con Edison's stock issuances.~~

~~(f)~~

Reflects higher pension costs of $(0.01) a share and $(0.02) a share for the three and nine months ended September 30, 2017 as compared with the 2016 periods. Also, for the nine months ended September 30, 2017 as compared with the 2016 period, reflects higher regulatory assessments and fees that are collected in revenues from customers and a higher reserve for injuries and damages of $(0.01) a share.

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~~(g)~~

Reflects higher revenues from renewable electric production projects and lower revenues and energy costs resulting from the retail electric supply business which was sold in September 2016. Includes $0.01 a share and $(0.05) a share of net after-tax mark-to-market gains/(losses) for the three months ended September 30, 2017 and 2016, respectively, and $0.01 a share and $0.02 a share of net after-tax mark-to-market gains for the nine months ended September 30, 2017 and 2016, respectively. Substantially all the mark-to-market effects in the 2016 periods were related to the retail electric supply business sold in September 2016.


~~(h)~~	Reflects Upton 2 engineering, procurement and construction costs ($(0.05) a share and $(0.06) a share, respectively) as well as increased energy service costs ($(0.02) a share and $(0.04) a share, respectively) for the three and nine months ended September 30, 2017 as compared with the 2016 periods.

~~(i)~~

Includes $0.02 a share of net after-tax gain related to the acquisition of a solar electric production investment for the three and nine months ended September 30, 2016, net of $(0.02) a share of impairment loss related to the solar electric production investment for the nine months ended September 30, 2016. Includes $0.15 a share of net after-tax gain related to the sale of the retail electric supply business for the three and nine months ended September 30, 2016.


~~(j)~~	~~Reflects income from equity investments.~~


~~(k)~~	~~Reflects higher state income tax benefits.~~



Variation for the Three Months Ended September 30, 2019 vs. 2018
	Earnings per Share	Net Income for Common Stock (Millions of Dollars)
CECONY (a)
Changes in rate plans	$0.11	$35	Reflects higher electric and gas net base revenues of $0.19 a share and $0.01 a share, respectively, due primarily to electric and gas base rates increases in January 2019 under the company's rate plans.
Weather impact on steam revenues	—	(1)
Operations and maintenance expenses	(0.11)	(34)	Reflects higher costs for pension and other postretirement benefits of $(0.04) a share, stock-based compensation of $(0.03) a share and uncollectibles of $(0.02) a share.
Depreciation, property taxes and other tax matters	(0.10)	(31)	Reflects higher property taxes of $(0.06) a share and higher depreciation and amortization expense of $(0.06) a share, offset, in part, by the reduction in the sales and use tax reserve upon conclusion of the audit assessment of $0.02 a share.
Other	(0.03)	14	Reflects primarily the dilutive effect of Con Edison's stock issuances of $(0.09) a share, offset, in part, by lower costs associated with components of pension and other postretirement benefits other than service cost of $0.05 a share.
Total CECONY	(0.13)	(17)
O&R (a)
Changes in rate plans	0.03	11	Reflects primarily an electric base rate increase under the company's new rate plan, effective January 1, 2019.
Operations and maintenance expenses	—	(1)
Depreciation, property taxes and other tax matters	(0.01)	(2)	Reflects higher depreciation and amortization expense.
Other	(0.02)	(4)	Reflects primarily the dilutive effect of Con Edison's stock issuances of $(0.01) a share.
Total O&R	—	4
Clean Energy Businesses
Operating revenues less energy costs	0.27	85	Reflects primarily higher revenues from renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC, including the consolidation of certain jointly-owned projects that were previously accounted for as equity investments of $0.30 a share, and lower gas purchased for resale due to lower purchased volume of $0.12 a share, offset, in part, by lower wholesale revenues of $(0.13) a share.
Operations and maintenance expenses	(0.01)	(2)	Reflects higher costs associated with additional renewable electric production projects in operation resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC. of $(0.03) a share, offset, in part, by lower energy services costs of $0.02 a share.
Depreciation and amortization	(0.08)	(26)	Reflects an increase in renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC.
Net interest expense	(0.12)	(35)	Reflects primarily an increase in debt resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC.
HLBV effects	(0.07)	(23)
Other	(0.02)	(4)	Reflects primarily the absence in 2019 of equity income from certain jointly-owned projects that were accounted for as equity investments in 2018 but consolidated after the December 2018 acquisition of Sempra Solar Holdings, LLC.
Total Clean Energy Businesses	(0.03)	(5)
Con Edison Transmission	—	1	Reflects income from equity investments.
Other, including parent company expenses	0.18	55
Total Reported (GAAP basis)	$0.02	$38

a. Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans and the weather-normalization clause applicable to their gas businesses, revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. In general, the utilities recover on a current basis the fuel, gas purchased for resale and purchased power costs they incur in supplying energy to their full-service customers. Accordingly, such costs do not generally affect Con Edison’s results of operations.

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Variation for the Nine Months Ended September 30, 2019 vs. 2018
	Earnings per Share	Net Income for Common Stock (Millions of Dollars)
CECONY (a)
Changes in rate plans	$0.59	$185	Reflects higher electric and gas net base revenues of $0.42 a share and $0.12 a share, respectively, due primarily to electric and gas base rates increases in January 2019 under the company's rate plans and growth in the number of gas customers of $0.02 a share.
Weather impact on steam revenues	(0.05)	(15)	Reflects the impact of warmer winter weather in 2019.
Operations and maintenance expenses	(0.23)	(71)	Reflects higher costs for pension and other postretirement benefits of $(0.11) a share, stock-based compensation of $(0.07) a share and regulatory assessments and fees that are collected in revenues from customers of $(0.05) a share.
Depreciation, property taxes and other tax matters	(0.38)	(121)	Reflects higher property taxes of $(0.19) a share, higher depreciation and amortization expense of $(0.17) a share and the absence of New York State sales and use tax refunds received in 2018 of $(0.04) a share; offset, in part, by the reduction in the sales and use tax reserve upon conclusion of the audit assessment of $0.02 a share.
Other	(0.06)	31	Reflects primarily the dilutive effect of Con Edison's stock issuances of $(0.16) a share and higher interest expense on long-term debt of $(0.09) a share, offset, in part, by lower costs associated with components of pension and other postretirement benefits other than service cost of $0.14 a share.
Total CECONY	(0.13)	9
O&R (a)
Changes in rate plans	0.03	10	Reflects an electric base rate increase of $0.05 a share, offset, in part, by a gas base rate decrease of $(0.02) a share under the company's new rate plans, effective January 1, 2019.
Operations and maintenance expenses	0.02	6	Reflects primarily a reduction of a regulatory asset associated with certain site investigation and environmental remediation costs in 2018.
Depreciation, property taxes and other tax matters	(0.02)	(5)	Reflects higher depreciation and amortization expense.
Other	(0.02)	(3)	Reflects primarily the dilutive effect of Con Edison's stock issuances of $(0.01) a share.
Total O&R	0.01	8
Clean Energy Businesses
Operating revenues less energy costs	0.44	137	Reflects primarily higher revenues from renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC, including the consolidation of certain jointly-owned projects that were previously accounted for as equity investments of $0.68 a share, offset, in part, by lower engineering, procurement and construction services revenues of $(0.22) a share.
Operations and maintenance expenses	0.14	43	Reflects primarily lower engineering, procurement and construction costs of $0.20 a share and lower energy services costs of $0.02 a share, offset, in part, by higher costs associated with additional renewable electric production projects in operation resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC. of $(0.08) a share.
Depreciation and amortization	(0.27)	(84)	Reflects an increase in renewable electric production projects resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC.
Net interest expense	(0.31)	(96)	Reflects primarily an increase in debt resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC.
HLBV effects	(0.18)	(60)
Other	(0.07)	(17)	Reflects primarily the absence in 2019 of equity income from certain jointly-owned projects that were accounted for as equity investments in 2018 but consolidated after the December 2018 acquisition of Sempra Solar Holdings, LLC.
Total Clean Energy Businesses	(0.25)	(77)
Con Edison Transmission	—	3	Reflects income from equity investments.
Other, including parent company expenses	0.19	54
Total Reported (GAAP basis)	$(0.18)	$(3)

a. Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans and the weather-normalization clause applicable to their gas businesses, revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. In general, the utilities recover on a current basis the fuel, gas purchased for resale and purchased power costs they incur in supplying energy to their full-service customers. Accordingly, such costs do not generally affect Con Edison’s results of operations.

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The Companies’ other operations and maintenance expenses for the three and nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 were as follows:


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		For the Three Months Ended September 30,		For the Nine Months Ended September 30,
(Millions of Dollars)	2017	2016	2017	2016	2019	2018	2019	2018
CECONY
Operations	$386	$381	$1,147	$1,109	$414	$393	$1,190	$1,186
Pensions and other postretirement benefits	51	87	152	261	34	18	100	53
Health care and other benefits	45	47	127	124	46		126	132
Regulatory fees and assessments (a)	142	135	355	361	134	132	356	335
Other	67	74	211	250	84	77	250	220
Total CECONY	691	724	1,992	2,105	712	666	2,022	1,926
O&R	80	77	236	220	81	80	225	234
Clean Energy Businesses(b)	79	40	174	124	53	50	168	226
Con Edison Transmission	3	1	7	1	2	3	7	7
Other ~~(b)~~(c)	(1)	(2)	(3)		(1)	(2)	—	(4)
Total other operations and maintenance expenses	$852	$840	$2,406	$2,447	$847	$797	$2,422	$2,389


(a)	Includes Demand Side Management, System Benefit Charges and Public Service Law 18A assessments which are collected in revenues.


(b)	The decrease in operations and maintenance for the nine months ended September 30, 2019 compared with the 2018 period is due primarily to lower engineering, procurement and construction costs.


(c)	Includes parent company and consolidation adjustments.

A discussion of the results of operations by principal business segment for the three and nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 follows. For additional business segment financial information, see Note JK to the Third Quarter Financial Statements.

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~~Three Months Ended September 30, 2017 Compared with Three Months Ended September 30, 2016~~

The Companies’ results of operations ~~in 2017 compared with 2016 were:~~for the three months ended September 30, 2019 and 2018 were as follows:


	CECONY			O&R			Clean Energy Businesses			Con Edison Transmission			Other (a)			Con Edison (b)			CECONY		O&R		Clean Energy Businesses		Con Edison Transmission		Other (a)		Con Edison (b)
(Millions of Dollars)	Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		2019	2018	2019	2018	2019	2018	2019	2018	2019	2018	2019	2018
Operating revenues	$(29)	(1.0	)%	$(6)	(2.5	)%	$(173)	(49.4	)%	$1	—	%	$1	Large		$(206)	(6.0	)%	$2,877	$2,899	$241	$246	$247	$181	$1	$1	$(1)	$1	$3,365	$3,328
Purchased power	(95)	(19.2	)	(9)	(13.0	)	(234)	Large		—	—		—	—		(338)	(42.4	)	423	472	61	73	—	—	—	—	(1)	—	483	545
Fuel	1	3.4		—	—		—	—		—	—		—	—		1	3.4		31	39	—	—	—	—	—	—	—	—	31	39
Gas purchased for resale	24	70.6		2	25.0		8	20.5		—	—		—	—		34	42.0		52	66	10	12	36	85	—	—	—	1	98	164
Other operations and maintenance	(33)	(4.6	)	3	3.9		39	97.5		2	Large		1	(50.0	)	12	1.4		712	666	81	80	53	50	2	3	(1)	(2)	847	797
Depreciation and amortization	22	7.9		1	5.9		8	72.7		—	—		1	Large		32	10.5		346	322	22	19	53	18	—	—	—	1	421	360
Taxes, other than income taxes	18	3.6		—	—		(2)	(40.0	)	—	—		—	—		16	3.0		590	570	21	20	5	3	—	—	2	4	618	597
Gain on sale of retail electric supply business (2016)	—	—		—	—		(104)	Large		—	—		—	—		(104)	Large
Operating income	34	4.4		(3)	(6.3	)	(96)	(76.8	)	(1)	Large		(1)	(50.0	)	(67)	(7.1	)	723	764	46	42	100	25	(1)	(2)	(1)	(3)	867	826
Other income less deductions	(2)	Large		(1)	Large		(9)	(33.3	)	1	5.0		1	Large		(10)	(20.4	)	(9)	(33)	(3)	(5)	1	18	27	24	(2)	(15)	14	(11)
Net interest expense	3	1.9		—	—		5	71.4		1	33.3		(2)	(40.0	)	7	3.9		181	175	10	10	61	13	7	5	3	2	262	205
Income before income tax expense	29	4.7		(4)	(10.0	)	(110)	(75.9	)	(1)	(6.3	)	2	50.0		(84)	(10.4	)	533	556	33	27	40	30	19	17	(6)	(20)	619	610
Income tax expense	16	7.1		1	7.7		(58)	(86.6	)	—	—		(3)	Large		(44)	(14.0	)	119	125	8	6	(12)	3	5	4	(4)	37	116	175
Net income	$13	3.4	%	$(5)	(18.5	)%	$(52)	(66.7	)%	$(1)	(10.0	)%	$5	83.3	%	$(40)	(8.0	)%	$414	$431	$25	$21	$52	$27	$14	$13	$(2)	$(57)	$503	$435
Income attributable to non-controlling interest																			—	—	—	—	30	—	—	—	—	—	30	—
Net income for common stock																			$414	$431	$25	$21	$22	$27	$14	$13	$(2)	$(57)	$473	$435


(a)	Includes parent company and consolidation adjustments.


(b)	Represents the consolidated results of operations of Con Edison and its businesses.

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CECONY


	For the Three Months Ended September 30, 2017				For the Three Months Ended September 30, 2016					For the Three Months Ended September 30, 2019				For the Three Months Ended September 30, 2018
(Millions of Dollars)	Electric	Gas	Steam	2017 Total	Electric	Gas	Steam	2016 Total	2017-2016 Variation	Electric	Gas	Steam	2019 Total	Electric	Gas	Steam	2018 Total	2019-2018 Variation
Operating revenues	$2,469	$268	$62	$2,799	$2,557	$208	$63	$2,828	$(29)	$2,544	$275	$58	$2,877	$2,571	$264	$64	$2,899	$(22)
Purchased power	393	—	7	400	486	—	9	495	(95)	418	—	5	423	465	—	7	472	(49)
Fuel	24	—	6	30	21	—	8	29	1	27	—	4	31	34	—	5	39	(8)
Gas purchased for resale	—	58	—	58	—	34	—	34	24	—	52	—	52	—	66	—	66	(14)
Other operations and maintenance	547	104	40	691	578	102	44	724	(33)	565	102	45	712	518	101	47	666	46
Depreciation and amortization	232	47	21	300	217	41	20	278	22	266	58	22	346	248	52	22	322	24
Taxes, other than income taxes	418	71	31	520	414	59	29	502	18	465	87	38	590	456	79	35	570	20
Operating income	$855	$(12)	$(43)	$800	$841	$(28)	$(47)	$766	$34	$803	$(24)	$(56)	$723	$850	$(34)	$(52)	$764	$(41)

Electric

CECONY’s results of electric operations for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$2,469	$2,557	$(88)	$2,544	$2,571	$(27)
Purchased power	393	486	(93)	418	465	(47)
Fuel	24	21	3	27	34	(7)
Other operations and maintenance	547	578	(31)	565	518	47
Depreciation and amortization	232	217	15	266	248	18
Taxes, other than income taxes	418	414	4	465	456	9
Electric operating income	$855	$841	$14	$803	$850	$(47)

CECONY’s electric sales and deliveries for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Millions of kWh Delivered							Revenues in Millions (a)					Millions of kWh Delivered						Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended					For the Three Months Ended						For the Three Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation	Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential/Religious (b)	3,237	3,653	(416	)	(11.4	)%		$805	$883	$(78)	(8.8	)%	3,687	3,777	(90)	(2.4	)%		$923	$988	$(65)	(6.6	)%
Commercial/Industrial	2,570	2,749	(179	)	(6.5	)		534	551	(17)	(3.1	)	2,831	2,706	125	4.6			557	542	15	2.8
Retail choice customers	7,510	8,136	(626	)	(7.7	)		867	918	(51)	(5.6	)	7,339	7,756	(417)	(5.4	)		854	910	(56)	(6.2	)
NYPA, Municipal Agency and other sales	2,705	2,764	(59	)	(2.1	)		207	204	3	1.5		2,756	2,758	(2)	(0.1	)		219	225	(6)	(2.7	)
Other operating revenues (c)	—	—	—		—			56	1	55	Large		—	—	—	—			(9)	(94)	85	(90.4	)
Total	16,022	17,302	(1,280	)	(7.4	)%	(d)	$2,469	$2,557	$(88)	(3.4	)%	16,613	16,997	(384)	(2.3	)%	(d)	$2,544	$2,571	$(27)	(1.1	)%


(a)	Revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved.


(b)	“Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.


(c)	Other electric operating revenues generally reflect changes in the revenue decoupling mechanism current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with ~~the revenue decoupling mechanism and~~ other provisions of the company’s rate plans.


(d)	After adjusting for variations, primarily weather and billing days, electric delivery volumes in CECONY’s service area ~~decreased 1.4~~increased 0.7 percent in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

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Operating revenues decreased ~~$88~~$27 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to lower purchased power expenses ($9347 million) and fuel expenses ($7 million), offset, in part, by ~~higher~~an increase in revenues from the ~~electric~~ rate plan ($2721 million).

Purchased power expenses decreased ~~$93~~$47 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to lower unit costs ($82 million), offset, in part, by higher purchased volumes ($6635 million) ~~and unit costs ($27 million)~~.

Fuel expenses ~~increased $3~~decreased $7 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to ~~higher~~lower unit costs ($68 million), offset, in part, by ~~lower~~higher purchased volumes from the company's electric generating facilities ($31 million).

Other operations and maintenance expenses ~~decreased $31~~increased $47 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~lower~~higher costs for pension and other postretirement benefits ($~~38 million) and environmental costs ($6~~18 million), ~~offset by higher surcharges~~stock-based compensation ($9 million), reserve for ~~assessments and fees that are collected in revenues from customers~~uncollectibles ($6 million) and ~~uncollectible expense~~municipal infrastructure support ($53 million).

Depreciation and amortizationincreased ~~$15~~$18 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased $4$9 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher property taxes ($1119 million) and payroll taxes ($2 million), offset, in part, by the reduction in the sales and use tax reserve upon conclusion of the audit assessment ($5 million), higher deferral of under-collected property taxes ($4 million) and lower state and local taxes ($52 million).

Gas

CECONY’s results of gas operations for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$268	$208	$60	$275	$264	$11
Gas purchased for resale	58	34	24	52	66	(14)
Other operations and maintenance	104	102	2	102	101	1
Depreciation and amortization	47	41	6	58	52	6
Taxes, other than income taxes	71	59	12	87	79	8
Gas operating income	$(12)	$(28)	$16	$(24)	$(34)	$10

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:

Table of Contents


	Thousands of Dt Delivered							Revenues in Millions (a)					Thousands of Dt Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended					For the Three Months Ended							For the Three Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential	4,731	4,335	396		9.1	%		$104	$88	$16	18.2	%	4,032	4,469	(437	)	(9.8	)%		$103	$118	$(15)	(12.7	)%
General	4,292	3,963	329		8.3			49	41	8	19.5		4,097	4,191	(94	)	(2.2	)		45	54	(9)	(16.7	)
Firm transportation	8,766	8,305	461		5.6			67	53	14	26.4		9,071	9,211	(140	)	(1.5	)		71		—	—
Total firm sales and transportation	17,789	16,603	1,186		7.1		(b)	220	182	38	20.9		17,200	17,871	(671	)	(3.8	)	(b)	219	243	(24)	(9.9	)
Interruptible sales (c)	2,108	1,664	444		26.7			8	4	4	Large		1,974	1,481	493		33.3			6		—	—
NYPA	10,148	12,800	(2,652	)	(20.7	)		1		—	—		12,329	12,815	(486	)	(3.8	)		1		—	—
Generation plants	24,068	35,745	(11,677	)	(32.7	)		7		—	—		19,558	29,128	(9,570	)	(32.9	)		7	9	(2)	(22.2	)
Other	4,487	4,975	(488	)	(9.8	)		6		—	—		4,604	3,953	651		16.5			6		—	—
Other operating revenues (d)	—	—	—		—			26	8	18	Large		—	—	—		—			36	(1)	37	Large
Total	58,600	71,787	(13,187	)	(18.4	)%		$268	$208	$60	28.8	%	55,665	65,248	(9,583	)	(14.7	)%		$275	$264	$11	4.2	%


(a)	Revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.

~~Table of Contents~~


(b)	After adjusting for variations, primarily billing days, firm gas sales and transportation volumes in the company’s service area increased ~~6.0~~12.1 percent in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period, reflecting primarily increased volumes attributable to the growth in the number of gas customers.


(c)	Includes ~~1,535~~1,064 thousands and ~~915~~681 thousands of Dt for the ~~2017~~2019 and ~~2016~~2018 periods, respectively, which are also reflected in firm transportation and other.


(d)	Other gas operating revenues generally reflect changes in the revenue decoupling mechanism and weather normalization clause current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with other provisions of the company’s rate plans.

Operating revenues increased ~~$60~~$11 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher~~an increase in revenues from the ~~gas~~ rate plan ~~and growth~~($28 million), offset, in ~~the number of customers ($29 million) and higher~~part, by lower gas purchased for resale expense ($2414 million).

Gas purchased for resale ~~increased $24~~ decreased $14 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to ~~higher~~lower unit costs ($2011 million) and purchased volumes ($43 million).

Other operations and maintenance expenses increased $2$1 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher stock-based compensation ($2 million) and municipal infrastructure support costs ($2 million), offset, in part, by surcharges for assessments and fees that ~~were~~are collected in revenues from ~~customers.~~customers ($3 million).

Depreciation and amortization increased $6 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher gas utility plant balances.

Taxes, other than income taxes increased ~~$12~~$8 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher property taxes ($67 million) and lower deferral of under-collected property taxes ($2 million), ~~state~~offset, in part, by the reduction in the sales and ~~local taxes ($4 million) and payroll taxes~~use tax reserve upon conclusion of the audit assessment ($1 million).

Steam

CECONY’s results of steam operations for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:

Table of Contents


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$62	$63	$(1)	$58	$64	$(6)
Purchased power	7	9	(2)	5	7	(2)
Fuel	6	8	(2)	4	5	(1)
Other operations and maintenance	40	44	(4)	45	47	(2)
Depreciation and amortization	21	20	1	22		—
Taxes, other than income taxes	31	29	2	38	35	3
Steam operating income	$(43)	$(47)	$4	$(56)	$(52)	$(4)

CECONY’s steam sales and deliveries for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Millions of Pounds Delivered							Revenues in Millions						Millions of Pounds Delivered							Revenues in Millions
	For the Three Months Ended							For the Three Months Ended						For the Three Months Ended							For the Three Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation		Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation		Percent Variation
General	13	10	3		30.0	%		$2			$—	—	%	6	12	(6	)	(50.0	)%		$2			$—	—	%
Apartment house	748	776	(28	)	(3.6	)		15		—		—		722	781	(59	)	(7.6	)		13	16	(3)		(18.8	)
Annual power	2,439	2,950	(511	)	(17.3	)		42	49	(7)		(14.3	)	2,443	2,711	(268	)	(9.9	)		36	45	(9)		(20.0	)
Other operating revenues (a)	—	—	—		—			3	(3)	6		Large		—	—	—		—			7	1	6		Large
Total	3,200	3,736	(536	)	(14.3	)%	(b)	$62	$63	$(1)		(1.6	)%	3,171	3,504	(333	)	(9.5	)%	(b)	$58	$64	$(6)		(9.4	)%


(a)	Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.


(b)	After adjusting for variations, primarily weather and billing days, steam sales and deliveries decreased ~~8.6~~7.0 percent in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

~~Table of Contents~~

Operating revenues decreased $1$6 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to a higher reserve related to steam earnings sharing ($4 million), lower purchased power expenses ($2 million) and ~~lower~~ fuel expenses ($21 million)~~, offset in part by a property tax refund incentive ($3 million)~~.

Purchased power ~~expenses~~ decreased $2 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to lower unit costs ($1 million) and purchased volumes ($1 million).

Fuelexpensesdecreased $1 million in the three months ended September 30, 2019 compared with the 2018 period due to lower unit costs.

Other operations and maintenance expenses decreased $2 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016 period due to lower unit costs ($1 million) and purchased volumes from the company's steam generating facilities ($1 million).~~

~~Other operations and maintenance~~ ~~expenses decreased $4 million in the three months ended September 30, 2017 compared with the 2016~~2018 period due primarily to ~~lower~~the absence of property damage, clean-up and other response costs related to a steam main rupture in 2018 ($9 million), offset, in part, by higher municipal infrastructure support ~~costs.~~costs ($3 million), costs for pension and other postretirement benefits ($2 million) and stock-based compensation ($1 million).

~~Depreciation and amortization~~ ~~increased~~ ~~$1 million~~ ~~in the three months ended September 30, 2017 compared with the 2016 period due primarily to higher steam utility plant balances.~~

Taxes, other than income taxes ~~increased $2 million in the three months ended September 30, 2017 compared with the 2016 period due primarily to higher property taxes.~~

~~Other Income (Deductions)~~

~~Other income (deductions) decreased $2 million in the three months ended September 30, 2017 compared with the 2016 period due primarily to a decrease in investment and other income.~~

~~Net Interest Expense~~

~~Net interest expense~~ increased $3 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher ~~long-term debt balances in the 2017 period.~~property taxes.

Other Income ~~Tax Expense~~(Deductions)

~~Income taxes~~Other income (deductions) increased ~~$16~~$24 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher~~lower costs associated with components of pension and other postretirement benefits other than service cost.

Net Interest Expense

Net interest expense increased $6 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to an increase in interest accrued on the TCJA related regulatory liability.

Table of Contents

Income Tax Expense

Income taxes decreased $6 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to lower income before income tax expense ($115 million), ~~a decrease~~lower state income taxes ($1 million) and an increase in the amortization of excess deferred federal income taxes due to the TCJA ($4 million), offset, in part, by lower tax benefits in 2019 for plant-related flow through items ($~~7 million), offset in part by higher research and development tax credits ($~~2 million) and higher non-deductible business expenses in the 2018 federal tax return due to the TCJA ($3 million). CECONY deferred as a regulatory liability its estimated net benefits for the 2018 period under the TCJA and continued to defer its estimated net benefits in 2019 for only its electric service. See “Other Regulatory Matters” in Note B to the Third Quarter Financial Statements.

O&R


	For the Three Months Ended September 30, 2017			For the Three Months Ended September 30, 2016				For the Three Months Ended September 30, 2019			For the Three Months Ended September 30, 2018
(Millions of Dollars)	Electric	Gas	2017 Total	Electric	Gas	2016 Total	2017-2016 Variation	Electric	Gas	2019 Total	Electric	Gas	2018 Total	2019-2018 Variation
Operating revenues	$206	$28	$234	$213	$27	$240	$(6)	$210	$31	$241	$212	$34	$246	$(5)
Purchased power	60	—	60	69	—	69	(9)	61	—	61	73	—	73	(12)
Gas purchased for resale	—	10	10	—	8	8	2	—	10	10	—	12	12	(2)
Other operations and maintenance	63	17	80	63	14	77	3	63	18	81	60	20	80	1
Depreciation and amortization	13	5	18	12	5	17	1	16	6	22	14	5	19	3
Taxes, other than income taxes	14	7	21	14	7	21	—	14	7	21	13	7	20	1
Operating income	$56	$(11)	$45	$55	$(7)	$48	$(3)	$56	$(10)	$46	$52	$(10)	$42	$4

Electric

O&R’s results of electric operations for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:



	For the Three Months Ended
(Millions of Dollars)	September 30, 2019	September 30, 2018	Variation
Operating revenues	$210	$212	$(2)
Purchased power	61	73	(12)
Other operations and maintenance	63	60	3
Depreciation and amortization	16	14	2
Taxes, other than income taxes	14	13	1
Electric operating income	$56	$52	$4

Table of Contents

For the Three Months Ended

(Millions of Dollars) September 30, 2017 September 30, 2016 Variation
Operating revenues $206 $213 $(7)
Purchased power 60 69 (9)
Other operations and maintenance 63 63 —
Depreciation and amortization 13 12 1
Taxes, other than income taxes 14 14 —
Electric operating income $56 $55
$1

O&R’s electric sales and deliveries for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Millions of kWh Delivered							Revenues in Millions (a)					Millions of kWh Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended					For the Three Months Ended							For the Three Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential/Religious (b)	500	585	(85	)	(14.5	)%		$105	$109	$(4)	(3.7	)%	586	595	(9	)	(1.5	)%		$106	$115	$(9)	(7.8	)%
Commercial/Industrial	206	216	(10	)	(4.6	)		34	35	(1)	(2.9	)	235	219	16		7.3			36	34	2	5.9
Retail choice customers	818	925	(107	)	(11.6	)		64	70	(6)	(8.6	)	796	864	(68	)	(7.9	)		62	67	(5)	(7.5	)
Public authorities	31	31	—		—			3	2	1	50.0		30	32	(2	)	(6.3	)		2	4	(2)	(50.0	)
Other operating revenues (c)	—	—	—		—			—	(3)	3	Large		—	—	—		—			4	(8)	12	Large
Total	1,555	1,757	(202	)	(11.5	)%	(d)	$206	$213	$(7)	(3.3	)%	1,647	1,710	(63	)	(3.7	)%	(d)	$210	$212	$(2)	(0.9	)%


(a)	O&R’s New York electric delivery revenues are subject to a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. O&R’s electric sales in New Jersey are not subject to a decoupling mechanism, and as a result, changes in such volumes do impact revenues.


(b)	“Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.


(c)	Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan.


(d)	After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased ~~3.4~~0.8 percent in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

Operating revenues decreased $7$2 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to lower purchased power expenses ($912 million), offset, in part, by higher revenues from the New York electric rate plan ($316 million).

Purchased power expenses decreased $9$12 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to lower unit costs ($11 million) and purchased volumes ($101 million).

Other operations and maintenance expenses increased $3 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to the deferral as a regulatory asset of costs for storm preparation in 2018 ($5 million), ~~offset by~~ higher ~~unit~~storm-related costs ($1 million), higher uncollectible accounts ($1 million), and higher stock-based compensation ($1 million), offset, in part, by the reduction of a regulatory asset associated with certain site investigation and remediation costs in 2018 ($6 million).

Depreciation and amortization ~~expenses~~ increased $2 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased $1 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher ~~electric utility plant balances.~~property taxes.

Gas

O&R’s results of gas operations for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$28	$27	$1	$31	$34	$(3)
Gas purchased for resale	10	8	2	10	12	(2)
Other operations and maintenance	17	14	3	18	20	(2)
Depreciation and amortization	5		—	6	5	1
Taxes, other than income taxes	7		—	7		—
Gas operating income	$(11)	$(7)	$(4)	$(10)			$—

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O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Thousands of Dt Delivered							Revenues in Millions (a)					Thousands of Dt Delivered							Revenues in Millions (a)
	For the Three Months Ended							For the Three Months Ended					For the Three Months Ended							For the Three Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential	579	550	29		5.3	%		$11	$9	$2	22.2	%	621	605	16		2.6	%		$11	$13	$(2)	(15.4	)%
General	198	177	21		11.9			2		—	—		161	202	(41	)	(20.3	)		1	3	(2)	(66.7	)
Firm transportation	898	884	14		1.6			8		—	—		851	795	56		7.0			6	8	(2)	(25.0	)
Total firm sales and transportation	1,675	1,611	64		4.0		(b)	21	19	2	10.5		1,633	1,602	31		1.9		(b)	18	24	(6)	(25.0	)
Interruptible sales	819	893	(74	)	(8.3	)		1	—	1	—		798	772	26		3.4			1		—	—
Generation plants	5	3	2		66.7			—	—	—	—		6	1	5		Large			—	—	—	—
Other	74	70	4		5.7			—	—	—	—		74	62	12		19.4			1	—	1	—
Other gas revenues	—	—	—		—			6	8	(2)	(25.0	)	—	—	—		—			11	9	2	22.2
Total	2,573	2,577	(4	)	(0.2	)%		$28	$27	$1	3.7	%	2,511	2,437	74		3.0	%		$31	$34	$(3)	(8.8	)%


(a)	Revenues from New York gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.


(b)	After adjusting for weather and other variations, total firm sales and transportation volumes increased ~~3.1~~5.2 percent in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

Operating revenues ~~increased $1~~ decreased $3 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher~~lower gas purchased for resale ($2 million)~~, offset by~~ and lower revenues from the New York gas rate plan ($1 million).

Gas purchased for resale decreased $2 million in the three months ended September 30, 2019 compared with the 2018 period due to lower purchased volumes ($1 million) and unit costs ($1 million).

Other operations and maintenance expenses decreased $2 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to the reduction of a regulatory asset associated with certain site investigation and remediation costs in 2018.

Depreciation and amortization increased $1 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to higher gas utility plant balances.

Income Tax Expense

Income taxes increased $2 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016 period due to higher purchased volumes ($3 million), offset by lower unit costs ($1 million).~~

~~Other operations and maintenance~~ ~~expenses increased $3 million in the three months ended September 30, 2017 compared with the 2016~~2018 period due primarily to higher ~~pension costs.~~

~~Income Tax Expense~~

Income taxes increased $1 million in the three months ended September 30, 2017 compared with the 2016 period due primarily to the absence in 2017 of a tax benefit from a corporate-owned life insurance policy in 2016 ($2 million), offset in part by lower income before income tax expense ($12 million). O&R deferred as a regulatory liability its estimated net benefits for the 2018 period under the TCJA. See “Other Regulatory Matters” in Note B to the Third Quarter Financial Statements.

Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$177	$350	$(173)	$247	$181	$66
Purchased power	—	234	(234)
Gas purchased for resale	47	39	8	36	85	(49)
Other operations and maintenance	79	40	39	53	50	3
Depreciation and amortization	19	11	8	53	18	35
Taxes, other than income taxes	3	5	(2)	5	3	2
Gain on sale of retail electric supply business (2016)	—	(104)	104
Operating income	$29	$125	$(96)	$100	$25	$75

Operating revenues ~~decreased $173~~ increased $66 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~lower~~higher renewable electric ~~retail~~production project revenues ~~of $256 million~~resulting from the ~~sale~~December 2018 acquisition of Sempra Solar Holdings, LLC, including the ~~retail~~consolidation of certain jointly-owned projects that were

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previously accounted for as equity method investments ($126 million). Wholesale revenues decreased ($55 million) due to lower sales volumes, energy services revenues decreased ($12 million) and net mark-to-market values increased ($7 million).

Gas purchased for resale decreased $49 million in the three months ended September 30, 2019 compared with the 2018 period due to lower purchased volumes.

Other operations and maintenance expenses increased $3 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to higher costs associated with additional renewable electric ~~supply business~~production projects in operation resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC ($12 million), offset, in part, by lower energy services costs ($9 million).

Depreciation and amortization increased $35 million in the three months ended September ~~2016. Renewable revenues increased $56 million~~30, 2019 compared with the 2018 period due primarily to an increase in renewable electric production projects ~~in operation and revenues~~resulting from the ~~engineering, procurement and construction~~December 2018 acquisition of ~~Upton~~Sempra Solar Holdings, LLC (including the consolidation of certain jointly-owned projects that the Clean Energy Businesses previously accounted for as equity method investments).

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2 (see Note O to the Third Quarter Financial Statements). Energy services revenues increased $9 million. Wholesale revenues increased $10 million due to higher sales volumes. Net mark-to-market values increased $32 million, due primarily to the sale of the retail electric supply business, of which $24 million in gains are reflected in purchased power costs and $8 million in gains are reflected in revenues.

~~Purchased power~~ expenses decreased $234 million in the three months ended September 30, 2017 compared with the 2016 period due primarily to lower electric costs due to the sale of the retail electric supply business in September 2016 ($210 million) and changes in mark-to-market values ($24 million).

~~Gas purchased for resale~~ ~~increased $8 million in the three months ended September 30, 2017 compared with the 2016 period due to higher purchased volumes.~~

~~Other operations and maintenance~~ expenses increased $39 million in the three months ended September 30, 2017 compared with the 2016 period due primarily to Upton 2 engineering, procurement and construction costs (see Note O to the Third Quarter Financial Statements) and an increase in energy services costs.

~~Depreciation and amortization~~ ~~increased $8 million in the three months ended September 30, 2017 compared with the 2016 period due to an increase in solar electric production projects in operation during 2017.~~

Taxes, other than income taxes ~~decreased~~ increased $2 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily ~~due~~ to ~~lower gross receipts tax from the sale of the retail electric supply business.~~higher property taxes.

Other Income (Deductions)

G~~ain on sale of retail electric supply business was $104~~Other income (deductions) decreased $17 million in the three months ended September 30, ~~2016 reflecting~~2019 compared with the ~~sale~~2018 period due primarily to the absence in 2019 of equity income from certain jointly-owned projects that were accounted for as equity investments in 2018 but consolidated after the ~~Clean Energy Businesses' retail electric supply business.~~December 2018 acquisition of Sempra Solar Holdings, LLC.

~~Other Income (Deductions)~~Net Interest Expense

~~Other income (deductions) decreased $9~~Net interest expense increased $48 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to an increase in debt resulting from the ~~gain related~~December 2018 acquisition of Sempra Solar Holdings, LLC, including $825 million that was borrowed to fund a portion of the purchase price, $576 million of Sempra Solar Holdings, LLC subsidiaries' project debt that was outstanding at the time of the acquisition and the consolidation of ~~a solar electric production investment in 2016.~~$506 million of project debt of certain jointly-owned projects that the Clean Energy Businesses previously accounted for as equity method investments.

~~Net Interest~~Income Tax Expense

~~Net interest expense increased $5~~Income taxes decreased $15 million in the three months ended September 30, ~~2017~~2019 compared with the ~~2016 period due primarily to increased debt on solar electric production projects.~~

~~Income Tax Expense~~

~~Income taxes decreased $58 million in the three months ended September 30, 2017 compared with the 2016~~2018 period due primarily to lower income before income tax expense (excluding income attributable to non-controlling interest) ($444 million), higher renewable energy ~~tax~~ credits ($3 million), lower state income taxes ($1 million) and adjustments for prior period federal income tax returns primarily due to increased research and development credits ($14 million), offset, in part, by an increase in uncertain tax positions ($7 million).

Income Attributable to Non-Controlling Interest

Income attributable to non-controlling interest increased $30 million in the ~~increase~~three months ended September 30, 2019 compared with the 2018 period due primarily to the income attributable in the 2019 period to a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. See Note N to the Third Quarter Financial Statements.

Con Edison Transmission

Income Tax Expense

Income taxes increased $1 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to higher income before income tax expense.

Other

Income Tax Expense

Income taxes decreased $41 million in the three months ended September 30, 2019 compared with the 2018 period due primarily to the absence of the TCJA re-measurement of deferred tax assets with Con Edison’s 2017 federal net operating loss carryforward into 2018 ($42 million), offset, in part, by higher state income taxes ~~in 2016 as a result of the sale of the retail electric supply business that increased the Clean Energy Businesses’ state apportionment factor on its cumulative temporary differences~~ ($131 million).

~~Other~~

~~For Con Edison, “Other” includes parent company and consolidation adjustments.~~

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~~Nine Months Ended September 30, 2017 Compared with Nine Months Ended September 30, 2016~~

The Companies’ results of operations ~~in 2017 compared with 2016 were:~~for the nine months ended September 30, 2019 and 2018 were as follows:


	CECONY			O&R			Clean Energy Businesses			Con Edison Transmission			Other (a)			Con Edison (b)			CECONY		O&R		Clean Energy Businesses		Con Edison Transmission		Other (a)			Con Edison (b)
(Millions of Dollars)	Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		Increases (Decreases) Amount	Increases (Decreases) Percent		2019	2018	2019	2018	2019	2018	2019	2018	2019	2018		2019	2018
Operating revenues	$207	2.7	%	$37	5.9	%	$(538)	(53.9	)%	$1	—	%	$(3)	Large		$(296)	(3.2	)%	$8,248	$8,121	$678	$691	$696	$573	$3	$3	$(2)		$—	$9,623	$9,388
Purchased power	(106)	(8.7	)	(6)	(3.9	)	(679)	Large		—	—		(3)	Large		(794)	(38.8	)	1,058	1,117	146	167	—	2	—	—	(1)	1		1,203	1,287
Fuel	36	27.1		—	—		—	—		—	—		—	—		36	27.1		163	201	—	—	—	—	—	—	—	—		163	201
Gas purchased for resale	155	71.4		20	62.5		89	Large		—	—		—	—		264	82.5		445	457	68	60	159	219	—	—	(1)	—		671	736
Other operations and maintenance	(113)	(5.4	)	16	7.3		50	40.3		6	Large		—	—		(41)	(1.7	)	2,022	1,926	225	234	168	226	7	7	—	(4)		2,422	2,389
Depreciation and amortization	66	8.0		3	6.0		24	80.0		—	—		—	—		93	10.3		1,020	949	63	57	169	55	1	1	—	(1)		1,253	1,061
Taxes, other than income taxes	77	5.3		2	3.3		(4)	(25.0	)	—	—		(1)	Large		74	4.9		1,715	1,621	63	63	17	12	—	—	5	11		1,800	1,707
Gain on sale of retail electric supply business (2016) and solar electric production project (2017)	—	—		—	—		(103)	Large		—	—		—	—		(103)	Large
Operating income	92	5.1		2	1.8		(121)	(65.8	)	(5)	Large		1	Large		(31)	(1.5	)	1,825	1,850	113	110	183	59	(5)	(5)	(5)	(7)		2,111	2,007
Other income less deductions	4	Large		(1)	Large		(2)	(5.7	)	37	Large		(1)	—		37	60.7		(31)	(99)	(8)	(15)	3	34	76	67	(9)	(16)		31	(29)
Net interest expense	12	2.7		(1)	(3.6	)	11	47.8		8	Large		(2)	(18.2	)	28	5.4		545	508	30	29	170	39	18	14	9	7		772	597
Income before income tax expense	84	6.2		2	2.3		(134)	(68.4	)	24	Large		2	(20.0	)	(22)	(1.3	)	1,249	1,243	75	66	16	54	53	48	(23)	(30)		1,370	1,381
Income tax expense	60	12.2		4	12.5		(68)	(89.5	)	10	Large		(9)	Large		(3)	(0.5	)	271	274	15	14	(44)	(4)	15	13	(14)	33		243	330
Net income	$24	2.8	%	$(2)	(3.6	)%	$(66)	(55.0	)%	$14	Large		$11	Large		$(19)	(1.8	)%	$978	$969	$60	$52	$60	$58	$38	$35	$(9)	$(63)		$1,127	$1,051
Income attributable to non-controlling interest																			—	—	—	—	79	—	—	—	—	—		79	—
Net income for common stock																			$978	$969	$60	$52	$(19)	$58	$38	$35	$(9)	$(63)		$1,048	$1,051


(a)	Includes parent company and consolidation adjustments.


(b)	Represents the consolidated results of operations of Con Edison and its businesses.

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CECONY


	For the Nine Months Ended September 30, 2017				For the Nine Months Ended September 30, 2016					For the Nine Months Ended September 30, 2019				For the Nine Months Ended September 30, 2018
(Millions of Dollars)	Electric	Gas	Steam	2017 Total	Electric	Gas	Steam	2016 Total	2017-2016 Variation	Electric	Gas	Steam	2019 Total	Electric	Gas	Steam	2018 Total	2019-2018 Variation
Operating revenues	$6,079	$1,421	$448	$7,948	$6,222	$1,113	$406	$7,741	$207	$6,174	$1,605	$469	$8,248	$6,107	$1,540	$474	$8,121	$127
Purchased power	1,084	—	26	1,110	1,191	—	25	1,216	(106)	1,033	—	25	1,058	1,091	—	26	1,117	(59)
Fuel	95	—	74	169	81	—	52	133	36	74	—	89	163	118	—	83	201	(38)
Gas purchased for resale	—	372	—	372	—	217	—	217	155	—	445	—	445	—	457	—	457	(12)
Other operations and maintenance	1,528	330	134	1,992	1,659	307	139	2,105	(113)	1,582	306	134	2,022	1,480	315	131	1,926	96
Depreciation and amortization	690	137	64	891	645	118	62	825	66	785	168	67	1,020	732	152	65	949	71
Taxes, other than income taxes	1,205	220	98	1,523	1,159	198	89	1,446	77	1,326	272	117	1,715	1,265	247	109	1,621	94
Operating income	$1,477	$362	$52	$1,891	$1,487	$273	$39	$1,799	$92	$1,374	$414	$37	$1,825	$1,421	$369	$60	$1,850	$(25)

Electric

CECONY’s results of electric operations for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Nine Months Ended			For the Nine Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$6,079	$6,222	$(143)	$6,174	$6,107	$67
Purchased power	1,084	1,191	(107)	1,033	1,091	(58)
Fuel	95	81	14	74	118	(44)
Other operations and maintenance	1,528	1,659	(131)	1,582	1,480	102
Depreciation and amortization	690	645	45	785	732	53
Taxes, other than income taxes	1,205	1,159	46	1,326	1,265	61
Electric operating income	$1,477	$1,487	$(10)	$1,374	$1,421	$(47)

CECONY’s electric sales and deliveries for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Millions of kWh Delivered							Revenues in Millions (a)					Millions of kWh Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended					For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential/Religious (b)	7,576	8,130	(554	)	(6.8	)%		$1,925	$2,017	$(92)	(4.6	)%	8,203	8,374	(171	)	(2.0	)%		$2,060	$2,211	$(151)	(6.8	)%
Commercial/Industrial	6,965	7,220	(255	)	(3.5	)		1,393	1,381	12	0.9		7,574	7,343	231		3.1			1,405	1,433	(28)	(2.0	)
Retail choice customers	19,748	20,404	(656	)	(3.2	)		2,092	2,114	(22)	(1.0	)	18,968	19,996	(1,028	)	(5.1	)		1,879	2,030	(151)	(7.4	)
NYPA, Municipal Agency and other sales	7,548	7,641	(93	)	(1.2	)		483	474	9	1.9		7,477	7,747	(270	)	(3.5	)		511	509	2	0.4
Other operating revenues (c)	—	—	—		—			186	236	(50)	(21.2	)	—	—	—		—			319	(76)	395	Large
Total	41,837	43,395	(1,558	)	(3.6	)%	(d)	$6,079	$6,222	$(143)	(2.3	)%	42,222	43,460	(1,238	)	(2.8	)%	(d)	$6,174	$6,107	$67	1.1	%


(a)	Revenues from electric sales are subject to a revenue decoupling mechanism, as a result of which delivery revenues generally are not affected by changes in delivery volumes from levels assumed when rates were approved.


(b)	“Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.


(c)	Other electric operating revenues generally reflect changes in the revenue decoupling mechanism current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with ~~the revenue decoupling mechanism and~~ other provisions of the company’s rate plans.


(d)	After adjusting for variations, primarily weather and billing days, electric delivery volumes in CECONY’s service area decreased ~~0.9~~1.0 percent in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

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Operating revenues ~~decreased $143~~ increased $67 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to an increase in revenues from the rate plan ($161 million), offset, in part, by lower purchased power ~~costs~~expenses ($~~107~~58 million)~~. The lower revenues reflected the decline in surcharges for assessments~~ and ~~fees that were collected in revenues from customers~~fuel expenses ($1344 million).

Purchased power expenses decreased ~~$107~~$58 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to lower unit costs ($152 million), offset, in part, by higher purchased volumes ($9594 million) ~~and unit costs ($12 million)~~.

Fuel expenses ~~increased $14~~decreased $44 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to ~~higher~~lower unit costs ($1240 million) and purchased volumes from the company’s electric generating facilities ($24 million).

Other operations and maintenance expenses ~~decreased $131~~increased $102 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~lower~~higher costs for pension and other postretirement benefits ($~~114~~49 million), surcharges for assessments and fees that are collected in revenues from customers ($~~13 million), environmental costs ($17~~36 million) and ~~stock based~~higher stock-based compensation ($624 million)~~, offset by higher costs for municipal infrastructure support ($20 million)~~.

Depreciation and amortization increased ~~$45~~$53 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased ~~$46~~$61 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher property taxes ($4353 million), the absence of a New York State sales and use tax refund received in 2018 ($14 million) and ~~the absence in 2017~~lower deferral of ~~a favorable state audit settlement in 2016~~under-collected property taxes ($5 million), offset, in part, by the reduction in the sales and use tax reserve upon conclusion of the audit assessment ($6 million) and lower state and local taxes ($45 million).

Gas

CECONY’s results of gas operations for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Nine Months Ended			For the Nine Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$1,421	$1,113	$308	$1,605	$1,540	$65
Gas purchased for resale	372	217	155	445	457	(12)
Other operations and maintenance	330	307	23	306	315	(9)
Depreciation and amortization	137	118	19	168	152	16
Taxes, other than income taxes	220	198	22	272	247	25
Gas operating income	$362	$273	$89	$414	$369	$45

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CECONY’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Thousands of Dt Delivered							Revenues in Millions (a)					Thousands of Dt Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended					For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential	39,814	35,565	4,249		11.9	%		$613	$506	$107	21.1	%	41,035	43,731	(2,696	)	(6.2	)%		$724	$728	$(4)	(0.5	)%
General	23,427	20,962	2,465		11.8			255	200	55	27.5		25,018	25,894	(876	)	(3.4	)		299	298	1	0.3
Firm transportation	53,952	51,333	2,619		5.1			390	332	58	17.5		60,590	61,628	(1,038	)	(1.7	)		444	448	(4)	(0.9	)
Total firm sales and transportation	117,193	107,860	9,333		8.7		(b)	1,258	1,038	220	21.2		126,643	131,253	(4,610	)	(3.5	)	(b)	1,467	1,474	(7)	(0.5	)
Interruptible sales (c)	6,526	7,587	(1,061	)	(14.0	)		30	29	1	3.4		7,375	4,956	2,419		48.8			34	31	3	9.7
NYPA	30,233	31,970	(1,737	)	(5.4	)		2	2	—	—		30,296	27,528	2,768		10.1			2	2	—	—
Generation plants	48,989	70,895	(21,906	)	(30.9	)		19	19	—	—		41,545	55,949	(14,404	)	(25.7	)		18	20	(2)	(10.0	)
Other	16,756	16,442	314		1.9			24	25	(1)	(4.0	)	16,058	15,399	659		4.3			24	24	—	—
Other operating revenues (d)	—	—	—		—			88	—	88	—		—	—	—		—			60	(11)	71	Large
Total	219,697	234,754	(15,057	)	(6.4	)%		$1,421	$1,113	$308	27.7	%	221,917	235,085	(13,168	)	(5.6	)%		$1,605	$1,540	$65	4.2	%


(a)	Revenues from gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.


(b)	After adjusting for variations, primarily billing days, firm gas sales and transportation volumes in the company’s service area increased ~~6.4~~1.9 percent in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period, reflecting primarily increased volumes attributable to the growth in the number of gas customers.


(c)	Includes ~~3,563~~3,797 thousands and ~~3,940~~1,798 thousands of Dt for the ~~2017~~2019 and ~~2016~~2018 periods, respectively, which are also reflected in firm transportation and other.


(d)	Other gas operating revenues generally reflect changes in the revenue decoupling mechanism and weather normalization clause current asset or regulatory liability and changes in regulatory assets and liabilities in accordance with other provisions of the company’s rate plans.

Operating revenues increased ~~$308~~$65 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher~~an increase in revenues from the ~~gas~~ rate plan ~~and growth~~($83 million), offset, in ~~the number of customers ($133 million) and increased~~part, by lower gas purchased for resale expense ($~~155~~12 million).

Gas purchased for resale ~~increased $155~~ decreased $12 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to ~~higher~~lower unit costs ($~~151~~13 million) ~~and~~, offset, in part, by higher purchased volumes ($41 million).

Other operations and maintenance expenses ~~increased $23~~decreased $9 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher pension and other postretirement benefits costs ($7 million), health and life expenses ($5 million),~~lower surcharges for assessments and fees that are collected in revenues from customers ($312 million) and ~~costs for~~equipment maintenance ~~of gas mains~~expenses ($24 million), offset, in part, by higher stock-based compensation ($5 million).

Depreciation and amortization increased ~~$19~~$16 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher gas utility plant balances.

Taxes, other than income taxes increased ~~$22~~$25 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher property taxes ($1227 million), the absence of a New York State sales and use tax refund received in 2018 ($3 million) and higher state and local taxes ($61 million), offset, in part, by higher deferral of under-collected property taxes ($4 million) and ~~payroll taxes~~the reduction in the sales and use tax reserve upon conclusion of the audit assessment ($31 million).

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Steam

CECONY’s results of steam operations for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Nine Months Ended			For the Nine Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$448	$406	$42	$469	$474	$(5)
Purchased power	26	25	1	25	26	(1)
Fuel	74	52	22	89	83	6
Other operations and maintenance	134	139	(5)	134	131	3
Depreciation and amortization	64	62	2	67	65	2
Taxes, other than income taxes	98	89	9	117	109	8
Steam operating income	$52	$39	$13	$37	$60	$(23)

CECONY’s steam sales and deliveries for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Millions of Pounds Delivered							Revenues in Millions					Millions of Pounds Delivered							Revenues in Millions
	For the Nine Months Ended							For the Nine Months Ended					For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
General	364	345	19		5.5	%		$20	$18	$2	11.1	%	394	442	(48	)	(10.9	)%		$20	$23	$(3)	(13.0	)%
Apartment house	4,248	4,251	(3	)	(0.1	)		119	107	12	11.2		4,331	4,670	(339	)	(7.3	)		120	129	(9)	(7.0	)
Annual power	10,074	10,640	(566	)	(5.3	)		300	284	16	5.6		10,383	11,313	(930	)	(8.2	)		304	333	(29)	(8.7	)
Other operating revenues (a)	—	—	—		—			9	(3)	12	Large		—	—	—		—			25	(11)	36	Large
Total	14,686	15,236	(550	)	(3.6	)%	(b)	$448	$406	$42	10.3	%	15,108	16,425	(1,317	)	(8.0	)%	(b)	$469	$474	$(5)	(1.1	)%


(a)	Other steam operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plan.


(b)	After adjusting for variations, primarily weather and billing days, steam sales and deliveries decreased 3.5 percent in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

Operating revenues ~~increased $42~~ decreased $5 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to the impact of warmer winter weather ($21 million) and lower purchased power expenses ($1 million), offset, in part, by certain rate plan reconciliations ($12 million) and higher fuel expenses ($~~22 million), the weather impact on revenues ($~~6 million)~~, lower regulatory reserve related to steam earnings sharing ($7 million), a property tax refund incentive ($3 million), and higher purchased power costs ($1 million)~~.

Purchased power expenses ~~increased~~decreased $1 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to ~~higher~~lower unit ~~costs ($5 million), offset by lower purchased volumes ($4 million).~~costs.

Fuel expenses increased ~~$22~~$6 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to higher unit costs ($239 million), offset, in part, by lower purchased volumes from the company’s steam generating facilities ($13 million).

Other operations and maintenance expenses ~~decreased $5~~increased $3 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~lower equipment maintenance expenses.~~higher municipal infrastructure support costs ($6 million), higher costs for pension and other postretirement benefits ($5 million) and stock-based compensation ($2 million), offset, in part, by the absence of property damage, clean-up and other response costs related to a steam main rupture in 2018 ($7 million).

Depreciation and amortization increased $2 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher steam utility plant balances.

Taxes, other than income taxes increased $9$8 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher property ~~taxes ($7 million)~~taxes.

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Other Income (Deductions)

Other income (deductions) increased $68 million in the nine months ended September 30, 2019 compared with the 2018 period due primarily to lower costs associated with components of pension and ~~state and local taxes ($1 million).~~other postretirement benefits other than service cost.

Net Interest Expense

Net interest expense increased ~~$12~~$37 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher interest expense for long-term ($10 million) and short-term ($7 million) debt, ~~balances~~an increase in interest accrued on the ~~2017 period.~~TCJA related regulatory liability ($9 million) and interest accrued on the system benefit charge liability ($6 million).

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Income Tax Expense

Income taxes ~~increased $60~~decreased $3 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher~~an increase in the amortization of excess deferred federal income ~~before income tax expense~~taxes due to the TCJA ($335 million)~~, a decrease in tax benefits for plant-related flow through items ($27 million), lower~~ and higher research and development ~~tax~~ credits ($~~10 million) and a higher reserve for injuries and damages ($9~~1 million), offset, in part, by lower ~~state income taxes~~tax benefits in 2019 for plant-related flow through items ($71 million), and higher ~~research and development tax credits included~~non-deductible business expenses in ~~Con Edison's filing of its 2016 consolidated~~the 2018 federal tax return due to the TCJA ($3 million). CECONY deferred as a regulatory liability its estimated net benefits for the 2018 period under the TCJA and continued to defer its estimated net benefits in ~~September 2017 ($5 million), a decrease~~2019 for only its electric service. See “Other Regulatory Matters” in ~~bad debt expense ($2 million) and a decrease in uncertain tax positions ($1 million).~~Note B to the Third Quarter Financial Statements.

O&R


	For the Nine Months Ended September 30, 2017			For the Nine Months Ended September 30, 2016				For the Nine Months Ended September 30, 2019			For the Nine Months Ended September 30, 2018
(Millions of Dollars)	Electric	Gas	2017 Total	Electric	Gas	2016 Total	2017-2016 Variation	Electric	Gas	2019 Total	Electric	Gas	2018 Total	2019-2018 Variation
Operating revenues	$495	$172	$667	$497	$133	$630	$37	$493	$185	$678	$505	$186	$691	$(13)
Purchased power	148	—	148	154	—	154	(6)	146	—	146	167	—	167	(21)
Gas purchased for resale	—	52	52	—	32	32	20	—	68	68	—	60	60	8
Other operations and maintenance	185	51	236	180	40	220	16	173	52	225	178	56	234	(9)
Depreciation and amortization	38	15	53	37	13	50	3	46	17	63	41	16	57	6
Taxes, other than income taxes	41	21	62	40	20	60	2	40	23	63	40	23	63	—
Operating income	$83	$33	$116	$86	$28	$114	$2	$88	$25	$113	$79	$31	$110		$3

Electric

O&R’s results of electric operations for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Nine Months Ended			For the Nine Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$495	$497	$(2)	$493	$505	$(12)
Purchased power	148	154	(6)	146	167	(21)
Other operations and maintenance	185	180	5	173	178	(5)
Depreciation and amortization	38	37	1	46	41	5
Taxes, other than income taxes	41	40	1	40		—
Electric operating income	$83	$86	$(3)	$88	$79	$9

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O&R’s electric sales and deliveries for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Millions of kWh Delivered							Revenues in Millions (a)					Millions of kWh Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended					For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential/Religious (b)	1,208	1,307	(99	)	(7.6	)%		$242	$240	$2	0.8	%	1,339	1,348	(9	)	(0.7	)%		$243	$260	$(17)	(6.5	)%
Commercial/Industrial	574	607	(33	)	(5.4	)		88	89	(1)	(1.1	)	621	609	12		2.0			87	91	(4)	(4.4	)
Retail choice customers	2,255	2,434	(179	)	(7.4	)		155	166	(11)	(6.6	)	2,194	2,274	(80	)	(3.5	)		147	158	(11)	(7.0	)
Public authorities	79	76	3		3.9			7	6	1	16.7		80	104	(24	)	(23.1	)		7	10	(3)	(30.0	)
Other operating revenues (c)	—	—	—		—			3	(4)	7	Large		—	—	—		—			9	(14)	23	Large
Total	4,116	4,424	(308	)	(7.0	)%	(d)	$495	$497	$(2)	(0.4	)%	4,234	4,335	(101	)	(2.3	)%	(d)	$493	$505	$(12)	(2.4	)%


(a)	O&R’s New York electric delivery revenues are subject to a revenue decoupling mechanism, as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved. O&R’s electric sales in New Jersey are not subject to a decoupling mechanism, and as a result, changes in such volumes do impact revenues.


(b)	“Residential/Religious” generally includes single-family dwellings, individual apartments in multi-family dwellings, religious organizations and certain other not-for-profit organizations.


(c)	Other electric operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s electric rate plan.


(d)	After adjusting for weather and other variations, electric delivery volumes in O&R’s service area decreased ~~2.2~~1.7 percent in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

Operating revenues decreased $2$12 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to lower purchased power ~~expense ($6 million) and lower revenues from rental property ($1 million), offset by higher revenues from the New York electric rate plan ($6 million).~~expenses.

Purchased power expenses decreased $6$21 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to lower unit costs ($22 million), offset, in part, by higher purchased volumes ($~~5 million) and unit costs ($~~1 million).

Other operations and maintenance expenses decreased $5 million in the nine months ended September 30, 2019 compared with the 2018 period due primarily to the reduction of a regulatory asset associated with certain site investigation and remediation costs in 2018.

Depreciation and amortization increased $5 million in the nine months ended September 30, ~~2017~~2019 compared with the 2016 period due primarily to operating costs related to weather events in 2017 ($2 million), higher surcharges for assessments and fees that are collected in revenues from customers ($1 million) and a higher reserve for injuries and damages ($1 million).

~~Depreciation and amortization~~ ~~increased $1 million in the nine months ended September 30, 2017 compared with the 2016~~2018 period due primarily to higher electric utility plant balances.

~~Taxes, other than income taxes~~ ~~increased $1 million in the nine months ended September 30, 2017 compared with the 2016 period due primarily to higher property taxes.~~

Gas

O&R’s results of gas operations for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Nine Months Ended			For the Nine Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$172	$133	$39	$185	$186	$(1)
Gas purchased for resale	52	32	20	68	60	8
Other operations and maintenance	51	40	11	52	56	(4)
Depreciation and amortization	15	13	2	17	16	1
Taxes, other than income taxes	21	20	1	23		—
Gas operating income	$33	$28	$5	$25	$31	$(6)

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O&R’s gas sales and deliveries, excluding off-system sales, for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:


	Thousands of Dt Delivered							Revenues in Millions (a)					Thousands of Dt Delivered							Revenues in Millions (a)
	For the Nine Months Ended							For the Nine Months Ended					For the Nine Months Ended							For the Nine Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation		Percent Variation			September 30, 2019	September 30, 2018	Variation	Percent Variation
Residential	5,556	5,266	290		5.5	%		$79	$55	$24	43.6	%	6,875	6,503	372		5.7	%		$98	$96	$2	2.1	%
General	1,447	1,224	223		18.2			16	10	6	60.0		1,608	1,502	106		7.1			18		—	—
Firm transportation	6,543	7,188	(645	)	(9.0	)		50	49	1	2.0		6,430	6,867	(437	)	(6.4	)		44	57	(13)	(22.8	)
Total firm sales and transportation	13,546	13,678	(132	)	(1.0	)	(b)	145	114	31	27.2		14,913	14,872	41		0.3		(b)	160	171	(11)	(6.4	)
Interruptible sales	2,966	3,020	(54	)	(1.8	)		5	2	3	Large		2,690	2,842	(152	)	(5.3	)		4	5	(1)	(20.0	)
Generation plants	6	15	(9	)	(60.0	)		—	—	—	—		6	1	5		Large			—	—	—	—
Other	589	583	6		1.0			1	—	1	—		637	636	1		0.2			1		—	—
Other gas revenues	—	—	—		—			21	17	4	23.5	%	—	—	—		—			20	9	11	Large
Total	17,107	17,296	(189	)	(1.1	)%		$172	$133	$39	29.3	%	18,246	18,351	(105	)	(0.6	)%		$185	$186	$(1)	(0.5	)%


(a)	Revenues from New York gas sales are subject to a weather normalization clause and a revenue decoupling mechanism as a result of which delivery revenues are generally not affected by changes in delivery volumes from levels assumed when rates were approved.


(b)	After adjusting for weather and other variations, total firm sales and transportation volumes increased ~~0.1~~1.8 percent in the nine months ended September 30, ~~2017~~2019 compared with ~~2016~~2018 period.

Operating revenues ~~increased $39~~ decreased $1 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~an increase in gas purchased for resale ($20 million) and higher~~lower revenues from the New York gas rate plan ($147 million), offset, by an increase in gas purchased for resale ($8 million).

Gas purchased for resale increased ~~$20~~$8 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due to higher unit costs ($6 million) and purchased volumes ($122 million) ~~and unit costs ($8 million)~~.

Other operations and maintenance expenses ~~increased $11~~decreased $4 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher pension costs.~~the reduction of a regulatory asset associated with certain site investigation and remediation costs in 2018.

Depreciation and amortization ~~increased $2 million in the nine months ended September 30, 2017 compared with the 2016 period due primarily to higher gas utility plant balances.~~

~~Taxes, other than income taxes~~increased $1 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher ~~property taxes.~~gas utility plant balances.

Income Tax Expense

Income taxes increased $4$1 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher income before income tax expense ($12 million), ~~a decrease~~offset, in ~~tax benefits for plant-related flow through items~~part, by an increase in amortization of excess deferred federal income taxes due to TCJA ($1 million) ~~and the absence in 2017 of a tax benefit from a corporate-owned life insurance policy in 2016 ($2 million)~~.

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Clean Energy Businesses

The Clean Energy Businesses’ results of operations for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period iswere as follows:


	For the Nine Months Ended			For the Nine Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	September 30, 2019	September 30, 2018	Variation
Operating revenues	$460	$998	$(538)	$696	$573	$123
Purchased power	(3)	676	(679)	—	2	(2)
Gas purchased for resale	161	72	89	159	219	(60)
Other operations and maintenance	174	124	50	168	226	(58)
Depreciation and amortization	54	30	24	169	55	114
Taxes, other than income taxes	12	16	(4)	17	12	5
Gain on sale of retail electric supply business (2016) and solar electric production project (2017) (a)	(1)	(104)	103
Operating income	$63	$184	$(121)	$183	$59	$124

~~(a) See Note O to the Third Quarter Financial Statements.~~

Operating revenues ~~decreased $538~~ increased $123 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to higher renewable electric production project revenues resulting from the December 2018

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acquisition of Sempra Solar Holdings, LLC, including the consolidation of certain jointly-owned projects that were previously accounted for as equity method investments ($286 million), offset, in part, by lower engineering, procurement and construction services revenues due to the completion in 2018 of a solar electric production project developed for another company ($92 million). Wholesale revenues decreased ($66 million) due to lower sales volumes, energy services revenues decreased ($16 million) and net mark-to-market values increased ($12 million).

Purchased power expenses decreased $2 million in the nine months ended September 30, 2019 compared with the 2018 period due primarily to the absence in the 2019 period of the true-ups relating to the retail electric supply business sold in 2016.

Gas purchased for resale decreased $60 million in the nine months ended September 30, 2019 compared with the 2018 period due primarily to lower purchased volumes.

Other operations and maintenance expenses decreased $58 million in the nine months ended September 30, 2019 compared with the 2018 period due primarily to lower engineering, procurement and construction costs ($82 million) and lower energy services costs ($10 million), offset, in part, by higher costs associated with additional renewable electric ~~retail revenues of $781 million~~production projects in operation resulting from the ~~sale~~December 2018 acquisition of Sempra Solar Holdings, LLC ($34 million).

Depreciation and amortization increased $114 million in the ~~retail electric supply business in~~nine months ended September ~~2016. Renewable revenues increased $112 million~~30, 2019 compared with the 2018 period due primarily to an increase in renewable electric production projects ~~in operation and revenues~~resulting from the ~~engineering, procurement and construction~~December 2018 acquisition of ~~Upton 2 (see Note O to~~Sempra Solar Holdings, LLC (including the ~~Third Quarter Financial Statements).~~consolidation of certain jointly-owned projects that the Clean Energy ~~services revenues~~Businesses previously accounted for as equity method investments).

Taxes, other than income taxes increased $21 million. Wholesale revenues increased $105 million due to higher sales volumes. Net mark-to-market values decreased $6 million of which $11 million in losses are reflected in purchased power costs and $5 ~~million in gains are reflected in revenues.~~

~~Purchased power~~ ~~expenses decreased $679~~ million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~lower electric costs due to the sale of the retail electric supply business in September 2016 ($689 million) offset by changes in mark-to-market values ($11 million).~~higher property taxes.

~~Gas purchased for resale~~ ~~increased $89~~Other Income (Deductions)

Other income (deductions) decreased $31 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~higher purchased volumes.~~the absence in 2019 of equity income from certain jointly-owned projects that were accounted for as equity investments in 2018 but consolidated after the December 2018 acquisition of Sempra Solar Holdings, LLC.

~~Other operations and maintenance~~ ~~expenses~~Net Interest Expense

Net interest expense increased ~~$50~~$131 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~Upton 2 engineering, procurement and construction costs (see Note O to the Third Quarter Financial Statements) and~~ an increase in ~~energy services costs.~~debt resulting from the December 2018 acquisition of Sempra Solar Holdings, LLC, including $825 million that was borrowed to fund a portion of the purchase price, $576 million of Sempra Solar Holdings, LLC subsidiaries' project debt that was outstanding at the time of the acquisition and the consolidation of $506 million of project debt of certain jointly-owned projects that the Clean Energy Businesses previously accounted for as equity method investments.

~~Depreciation and amortization~~ ~~increased $24~~Income Tax Expense

Income taxes decreased $40 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016 period due to an increase in solar electric production projects in operation during 2017.~~

~~Taxes, other than income taxes~~ ~~decreased $4 million in the nine months ended September 30, 2017 compared with the 2016 period due to lower gross receipts tax from the sale of the retail electric supply business in September 2016.~~

G~~ain on sale of retail electric supply business~~ ~~was $104 million in the nine months ended September 30, 2016 reflecting the sale of the Clean Energy Businesses' retail electric supply business.~~

~~Other Income (Deductions)~~

~~Other income (deductions) decreased $2 million in the nine months ended September 30, 2017 compared with the 2016 period due primarily to earnings from equity investments.~~

~~Net Interest Expense~~

~~Net interest expense increased $11 million in the nine months ended September 30, 2017 compared with the 2016 period due primarily to increased debt on solar electric production projects.~~

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~~Income Tax Expense~~

~~Income taxes decreased $68 million in the nine months ended September 30, 2017 compared with the 2016~~2018 period due primarily to lower income before income tax expense (excluding income attributable to non-controlling interest) ($5425 million), higher renewable energy ~~tax~~ credits ($17 million) ~~and the increase to deferred~~, lower state income taxes ($4 million) and adjustments for prior period federal income tax returns primarily due to increased research and development credits ($11 million), offset, in ~~2016 as a result of the sale of the retail electric supply business that increased the Clean Energy Businesses’ state apportionment factor on its cumulative temporary differences~~part, by an increase in uncertain tax positions ($137 million).

~~Con Edison Transmission~~Income Attributable to Non-Controlling Interest

~~Other operations and maintenance~~Income attributable to non-controlling interest increased $6$79 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~CET having no employees or other direct costs until January 1, 2017.~~the income attributable in the 2019 period to a tax equity investor in renewable electric production projects accounted for under the HLBV method of accounting. See Note N to the Third Quarter Financial Statements.

~~Net Interest Expense~~Con Edison Transmission

~~Net interest expense~~Other Income (Deductions)

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Other income (deductions) increased $8$9 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period due primarily to ~~a new debt issuance~~increased earnings from equity investments in ~~2016.~~Mountain Valley Pipeline, LLC.

~~Other~~ Income ~~(Deductions)~~Tax Expense

~~Other income (deductions)~~Income taxes increased ~~$37~~$2 million in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016 period due primarily to earnings from equity investments in Stagecoach Gas Services, LLC, substantially all of which were made in June 2016.~~

~~Income Tax Expense~~

~~Income taxes increased $10 million in the nine months ended September 30, 2017 compared with the 2016~~2018 period due primarily to higher income before income tax expense.

Other

~~For~~Income Tax Expense

Income taxes decreased $47 million in the nine months ended September 30, 2019 compared with the 2018 period due primarily to the absence of the TCJA re-measurement of deferred tax assets associated with Con ~~Edison, “Other” includes parent company~~Edison’s 2017 federal net operating loss carryforward into 2018 ($42 million) and ~~consolidation adjustments.~~lower state income taxes ($5 million).

Liquidity and Capital Resources

The Companies’ liquidity reflects cash flows from operating, investing and financing activities, as shown on their respective consolidated statement of cash flows and as discussed below.

~~Changes in the~~

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The Companies’ cash, ~~and~~ temporary cash investments and restricted cash resulting from operating, investing and financing activities for the nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 are summarized as follows:


	For the Nine Months Ended September 30,						For the Nine Months Ended September 30,
	Con Edison			CECONY			CECONY		O&R		Clean Energy Businesses		Con Edison Transmission			Other (a)		Con Edison (b)
(Millions of Dollars)	2017	2016	Variation	2017	2016	Variation	2019	2018	2019	2018	2019	2018	2019		2018	2019	2018	2019	2018
Operating activities	$2,227	$2,336	$(109)	$1,790	$2,017	$(227)	$1,490	$1,085	$168	$102	$285	$(7)	$150		$114	$(133)	$306	$1,960	$1,600
Investing activities	(2,572)	(3,717)	1,145	(2,197)	(1,943)	(254)	(2,437)	(2,498)	(163)	(147)	(142)	(195)	(143)		(106)	1	(1)	(2,884)	(2,947)
Financing activities	(362)	583	(945)	(278)	(891)	613	144	700	(20)	22	(79)	198	(9)		(8)	135	(164)	171	748
Net change for the period	(707)	(798)	91	(685)	(817)	132	(803)	(713)	(15)	(23)	64	(4)	(2)		—	3	141	(753)	(599)
Balance at beginning of period	776	944	(168)	702	843	(141)	818	730	52	47	126	56	2		2	8	9	1,006	844
Balance at end of period(c)	$69	$146	$(77)	$17	$26	$(9)	$15	$17	$37	$24	$190	$52		$—	$2	$11	$150	$253	$245
Less: Change in cash balances held for sale	—	(4)	4	—	—	—
Balance at end of period excluding held for sale	$69	$150	$(81)	$17	$26	$(9)

(a) Includes parent company and consolidation adjustments.

(b) Represents the consolidated results of operations of Con Edison and its businesses.

(c) See "Reconciliation of Cash, Temporary Cash Investments and Restricted Cash" in Note A to the Third Quarter Financial Statements.

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Cash Flows from Operating Activities

The Utilities’ cash flows from operating activities reflect primarily their energy sales and deliveries and cost of operations. The volume of energy sales and deliveries is affected primarily by factors external to the Utilities, such as growth of customer demand, weather, market prices for energy and economic conditions. Measures that promote distributed energy resources, such as distributed generation, demand reduction and energy efficiency, also affect the volume of energy sales and deliveries. Under the revenue decoupling mechanisms in the Utilities’ New York electric and gas rate plans, changes in delivery volumes from levels assumed when rates were approved may affect the timing of cash flows, but generally not net income. The prices at which the Utilities provide energy to their customers are determined in accordance with their rate plans. In general, changes in the Utilities’ cost of purchased power, fuel and gas may affect the timing of cash flows, but not net income, because the costs are recovered in accordance with rate plans. Pursuant to their rate plans, the Utilities have recovered from customers a portion of the tax liability they will pay in the future as a result of temporary differences between the book and tax basis of assets and liabilities. These temporary differences affect the timing of cash flows, but not net income, as the Companies are required to record deferred tax assets and liabilities at the current corporate tax rate for the temporary differences. For the Utilities, credits to their customers of the net benefits of the TCJA, including the reduction of the corporate tax rate to 21 percent, decrease cash flows from operating activities. See “Other Regulatory Matters” in Note B to the Third Quarter Financial Statements.

Net income is the result of cash and non-cash (or accrual) transactions. Only cash transactions affect the Companies’ cash flows from operating activities. Principal non-cash charges or credits include depreciation, deferred income tax expense, ~~and~~ amortizations of certain regulatory assets and ~~liabilities.~~liabilities, and accrued unbilled revenue. Non-cash charges or credits may also be accrued under the revenue decoupling and cost reconciliation mechanisms in the Utilities’ New York electric and gas rate plans.

Net cash flows from operating activities for the nine months ended September 30, ~~2017~~2019 for Con Edison and CECONY were ~~$109~~$360 million and ~~$227~~$405 million ~~lower,~~higher, respectively, than in the ~~2016~~2018 period. The ~~change~~changes in net cash flows for Con Edison and CECONY ~~reflects~~reflect primarily ~~higher cash paid for income taxes~~a change in the ~~2017 period as compared with the 2016 period~~timing of ~~$110~~pension and retiree benefit contributions ($122 million and ~~$226~~$114 million, ~~respectively,~~respectively), lower storm restoration costs ($185 million and $124 million, respectively), lower MTA power reliability costs ($123 million and $123 million, respectively), reimbursement received for Puerto Rico related restoration costs ($95 million and $95 million, respectively), and for CECONY, lower net payments of ~~refunds received. The~~ income tax ~~refund received~~to affiliated companies ($255 million), offset, in ~~2016 reflected~~part, by higher TCJA net benefits provided to customers in the ~~extension of bonus depreciation in late 2015, resulting in a refund of the 2015 estimated federal tax payments.~~2019 period ($289 million and $287 million, respectively).

The change in net cash flows also reflects the timing of payments for and recovery of energy costs. This timing is reflected within changes to accounts receivable – customers and recoverable and refundable energy costs within other regulatory assets and liabilities and accounts payable balances.

~~The changes in regulatory assets primarily reflect changes in deferred pension costs in accordance with the accounting rules for retirement benefits.~~

Cash Flows Used in Investing Activities

Net cash flows used in investing activities for Con Edison and CECONY were ~~$1,145~~$63 million ~~lower~~ and ~~$254~~$61 million ~~higher,~~lower, respectively, for the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period. The change for Con Edison reflects primarily ~~lower new~~a decrease in non-utility construction expenditures at the Clean Energy Businesses ($50 million), the proceeds from the sale of a property formerly used by CECONY in its operations ($48 million) and a decrease in utility construction expenditures at CECONY ($44 million), offset, in part, by increases in investments in electric and gas transmission projects at Con Edison Transmission ($36 million), cost of removal less salvage at CECONY ($~~1,011~~31 million) and ~~renewable electric production projects ($240 million), and a decrease~~an increase in non-utility construction expenditures ($148 million), offset in part by lower proceeds from sale of assets ($216 million). The change for CECONY primarily reflects absence of proceeds from the transfer of assets to NY Transco in 2016 ($122 million) and increased utility construction expenditures at O&R ($8815 million).

Cash Flows from Financing Activities

Net cash flows from financing activities for Con Edison and CECONY were ~~$945~~$577 million ~~lower~~ and ~~$613~~$556 million ~~higher,~~lower, respectively, in the nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period.

In ~~August 2017,~~May 2019, Con Edison entered into a forward sale agreement relating to 5,800,000 shares of its common stock. In June 2019, the company issued 4,750,000 shares for $400 million upon physical settlement of shares subject to the forward sale agreement. Con Edison used the proceeds to invest in CECONY for funding of its capital requirements and other general corporate purposes. At September 30, 2019, 1,050,000 shares remain subject to the forward sale agreement. The company expects the remaining shares under the forward sale agreement to settle by December 28, 2020. See Note C to the Third Quarter Financial Statements.

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In March 2019, Con Edison issued ~~4.1~~5,649,369 shares of its common stock for $425 million ~~common~~upon physical settlement of the remaining shares ~~resulting in net proceeds of $343 million, after issuance expenses, that were invested by~~subject to its November 2018 forward sale agreements. Con Edison used the proceeds to invest in its subsidiaries ~~principally CECONY and the Clean Energy Businesses,~~ for funding of their ~~construction expenditures~~capital requirements and to repay short-term debt incurred for ~~other general corporate purposes.~~that purpose.

In February 2019, Con Edison borrowed $825 million under a two-year variable-rate term loan to fund the repayment of a 6-month variable-rate term loan. In June ~~2017,~~2019, Con Edison pre-paid $150 million of the amount borrowed.

In May 2019, CECONY issued ~~$500~~$700 million aggregate principal amount of ~~3.875~~4.125 percent debentures, due ~~2047,~~2049, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes.

In ~~March 2017, Con Edison~~April 2019, CECONY redeemed at maturity $475 million of 6.65 percent 10-year debentures.

In June 2018, CECONY issued ~~$400~~$640 million aggregate principal amount of ~~2.00 percent~~ debentures, due ~~2020,~~2021, at a variable interest rate of 0.40 percent above three-month LIBOR and ~~prepaid~~called for redemption on various dates in July and August 2018 the ~~June 2016 $400~~$636 million ~~variable rate term loan that was~~of CECONY’s tax-exempt debt for which the interest rates were to ~~mature in 2018.~~be determined pursuant to periodic auctions.

~~Also, in March 2017, a Con Edison Development subsidiary~~In May 2018, CECONY issued ~~$97~~$700 million aggregate principal amount of ~~4.45~~4.50 percent ~~senior notes,~~debentures, due ~~2042, secured by the company’s Upton County Solar project.~~

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~~In June 2016, CECONY issued $550~~2058, and $300 million aggregate principal amount of ~~3.85~~3.80 percent debentures, due ~~2046,~~2028, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes.

In ~~September 2016,~~April 2018, CECONY redeemed at maturity ~~$400~~$600 million of ~~5.50~~5.85 percent 10-year debentures.

In ~~June 2016, a Con Edison Solutions subsidiary borrowed $2 million pursuant~~September 2019, O&R agreed to ~~a loan agreement with a New Jersey utility. The borrowing matures~~issue in ~~2026, bears interest of 11.18 percent and may be repaid in cash or project Solar Renewable Energy Certificates.~~

~~In May 2016, Con Edison issued approximately 10 million common shares resulting in net proceeds, after issuance expenses, of $702 million and $500~~November 2019 $43 million aggregate principal amount of ~~2.00~~3.73 percent debentures, due ~~2021,~~2049 and to issue in December 2019 $44 million aggregate principal amount of 2.94 percent debentures, due 2029 and $38 million aggregate principal amount of 3.46 percent debentures, due 2039.

In August and December 2018, O&R issued $150 million aggregate principal amount of 4.35 percent debentures, due 2048.

In September 2018, O&R redeemed at maturity $50 million of 6.15 percent 10-year debentures.

In October 2019, a Con Edison Development subsidiary issued $303 million aggregate principal amount of 3.82 percent senior notes, due 2038, secured by the company's Panoche Valley and Wistaria Solar renewable electric production projects.

In May 2019, a Con Edison Development subsidiary borrowed $464 million at a variable-rate, due 2026, secured by equity interests in solar electric production projects, the net proceeds from the sale of which were used to repay borrowings from Con Edison and for other general corporate purposes. Con Edison used a portion of the repayment to pre-pay $150 million of an $825 million two-year variable-rate term loan and the remainder to repay short-term borrowings and for other general corporate purposes. The company has entered into fixed-rate interest rate swaps in connection with this borrowing. See Note L to the ~~acquisition by a CET Gas subsidiary of a 50 percent equity interest in a gas pipeline and storage joint venture (see "Con Edison Transmission", above) and for general corporate purposes.~~Third Quarter Financial Statements.

In ~~May 2016,~~September 2018, a Con Edison Development subsidiary issued ~~$95~~$140 million aggregate principal amount of ~~4.07~~4.41 percent ~~senior notes,~~Senior Notes, due ~~2036,~~2028, secured by five of the ~~company's California Holdings 3 solar project.~~company’s wind electric production projects.

~~In February 2016, a Con Edison Development subsidiary issued $218 million aggregate principal amount of 4.21 percent senior notes, due 2041, secured by the company's Texas Solar 7 solar project.~~

Con Edison’s cash flows from financing for the nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 also reflect the proceeds, and reduction in cash used for reinvested dividends, resulting from the issuance of common shares under the company’s dividend reinvestment, stock purchase and long-term incentive plans of ~~$74~~$76 million and ~~$77~~$75 million, respectively.

Cash flows used in financing activities of the Companies also reflect commercial paper issuances and repayments. The commercial paper amounts outstanding at September 30, ~~2017~~2019 and ~~2016~~2018 and the average daily balances for the nine months ended September 30, ~~2017~~2019 and ~~2016~~2018 for Con Edison and CECONY were as follows:

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	2017		2016		2019		2018
(Millions of Dollars, except Weighted Average Yield)	Outstanding at September 30,	Daily average	Outstanding at September 30,	Daily average	Outstanding at September 30,	Daily average	Outstanding at September 30,	Daily average
Con Edison	$356	$645	$601	$813	$1,300	$1,122	$1,352	$830
CECONY	$147	$323	$480	$385	$930	$743	$1,004	$447
Weighted average yield	1.3	1.1	0.7	0.6	2.3	2.6	2.3	2.1

Capital Requirements and Resources

~~Con Edison has decreased its estimates~~Capital Requirements

The capital expenditures reflected in the October 2019 Joint Proposal for ~~capital requirements for the retirement of long-term securities for 2018 from $1,688 million to $1,288 million. The decrease reflects the $400 million prepayment of a variable~~new CECONY electric and gas rate ~~term loan that was to mature~~plans (see “Rate Plans” in ~~2018. See~~ Note CB to the Third Quarter Financial ~~Statements.~~Statements) were:

~~For each of the Companies, the ratio of earnings~~



(Millions of Dollars)	2020	2021	2022
Electric	$2,135	$2,137	$1,917
Gas	$1,073	$1,055	$989

Contractual Obligations

Con Edison’s material obligations to ~~fixed charges (Securities~~make payments pursuant to contracts totaled $52,720 million and ~~Exchange Commission (SEC) basis) for the nine months ended~~$49,264 million at September 30, ~~2017~~2019 and ~~2016 and the twelve months ended~~ December 31, ~~2016 was:~~2018, respectively. The increase at September 30, 2019 is due primarily to increases in long-term debt ($1,288 million) and interest on long-term debt ($828 million). See "Cash Flows from Financing Activities,” above.

Ratio of Earnings to Fixed Charges

For the Nine Months Ended September 30, 2017 For the Nine Months Ended September 30, 2016 For the Twelve Months Ended December 31, 2016
Con Edison 3.8 4.0 3.6
CECONY 3.9 3.8 3.6

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Capital Resources

For each of the Companies, the common equity ratio at September 30, ~~2017~~2019 and December 31, ~~2016~~2018 was:


	Common Equity Ratio (Percent of total capitalization)		Common Equity Ratio (Percent of total capitalization)
	September 30, 2017	December 31, 2016	September 30, 2019	December 31, 2018
Con Edison	50.8	49.3	50.8	49.0
CECONY	50.9	49.5	50.1	48.6

~~Other Changes in~~ Assets, Liabilities and ~~Liabilities~~Equity

The ~~following table shows changes in certain~~Companies' assets, liabilities, and ~~liabilities~~equity at September 30, ~~2017, compared with~~2019 and December 31, ~~2016.~~

2018 are summarized as follows.

Con Edison CECONY
(Millions of Dollars)
2017 vs. 2016
Variation
2017 vs. 2016
Variation
Assets
Prepayments $433 $398
Non-utility property, less accumulated depreciation 204 —
Regulatory asset - Unrecognized pension and other postretirement costs (248) (254)
Liabilities
Pension and retiree benefits $(404) $(394)
Deferred income taxes and unamortized investment tax credits 539 610
System benefit charge 194 175



	CECONY		O&R		Clean Energy Businesses		Con Edison Transmission			Other (a)		Con Edison (b)
(Millions of Dollars)	2019	2018	2019	2018	2019	2018	2019		2018	2019	2018	2019	2018
ASSETS
Current assets	$3,005	$3,357	$255	$263	$458	$372		$—	$32	$(137)	$(160)	$3,581	$3,864
Investments	436	385	26	25	—	—	1,528		1,362	(7)	(6)	1,983	1,766
Net plant	36,885	35,374	2,299	2,210	4,033	4,148	17		17	—	—	43,234	41,749
Other noncurrent assets	4,482	3,992	355	394	1,885	1,736	14		14	406	405	7,142	6,541
Total Assets	$44,808	$43,108	$2,935	$2,892	$6,376	$6,256	$1,559		$1,425	$262	$239	$55,940	$53,920

LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	$3,813	$4,200	$410	$392	$1,819	$1,608	$94		$5	$83	$2	$6,219	$6,207
Noncurrent liabilities	12,892	12,322	1,060	1,094	44	(32)	82		66	(28)	(71)	14,050	13,379
Long-term debt	14,024	13,676	694	694	2,124	2,330	500		500	195	295	17,537	17,495
Equity	14,079	12,910	771	712	2,389	2,350	883		854	12	13	18,134	16,839
Total Liabilities and Equity	$44,808	$43,108	$2,935	$2,892	$6,376	$6,256	$1,559		$1,425	$262	$239	$55,940	$53,920

(a) Includes parent company and consolidation adjustments.

~~Prepayments~~

~~The increase in prepayments for~~(b) Represents the consolidated results of operations of Con Edison and its businesses.

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CECONY

Current assets at September 30, 2019 were $352 million lower than at December 31, 2018. The change in current assets reflects a decrease in cash and temporary cash investments primarily ~~the portion allocable~~due to the ~~2017 fourth quarter of CECONY's~~ July ~~2017~~2019 payment of ~~its~~ New York City semi-annual property ~~taxes.~~

~~Non-Utility Property, Less Accumulated Depreciation~~

taxes ($803 million) and a decrease in other receivables ($107 million). The decrease in other receivables reflects primarily the receipt of payments related to costs for aid provided by CECONY for the restoration of power in Puerto Rico in the aftermath of the September 2017 hurricanes ($95 million). These decreases are offset, in part, by an increase in ~~non-utility~~prepayments reflecting primarily the July 2019 payment of New York City semi-annual property ~~less~~taxes, offset, in part, by three months of amortization, while the December 2018 balance reflects the amortization of the entire previous semi-annual payment ($499 million).

Investments at September 30, 2019 were $51 million higher than at December 31, 2018. The change in investments reflects primarily an increase in supplemental retirement income plan assets. See Note E to the Third Quarter Financial Statements.

Net plant at September 30, 2019 was $1,511 million higher than at December 31, 2018. The change in net plant reflects primarily an increase in electric ($1,141 million) and gas ($717 million) plant balances, offset, in part, by an increase in accumulated depreciation ~~for Con Edison reflects the completion of construction of Con Edison Development's Upton County Solar renewable electric production project (see Con Edison Development, below)~~($516 million).

Other noncurrent assets at September 30, 2019 were $490 million higher than at December 31, 2018. The change in other noncurrent assets reflects primarily the adoption of ASU No. 2016-02, “Leases (Topic 842)” ($610 million). See Note I to the Third Quarter Financial Statements. The change also reflects primarily an increase in the regulatory asset for deferred derivative losses ($79 million), property tax reconciliation ($64 million) and MTA power reliability deferral ($16 million) which reflects costs incurred and deferred as a regulatory asset in the 2019 period. See “Other Regulatory ~~Asset for Unrecognized Pension and Other Postretirement Costs and Liability for Pension and Retiree Benefits~~

~~The~~Matters” in Note B to the Third Quarter Financial Statements. These increases are offset, in part, by a decrease in the regulatory asset for unrecognized pension and other postretirement costs ~~and the liability for pension and retiree benefits reflects~~to reflect the final actuarial valuation, as measured at December 31, 2018, of the pension and other retiree benefit plans in accordance with the accounting rules for retirement benefits ($295 million). See Notes B, E and F to the Third Quarter Financial Statements. The change in the regulatory asset also reflects the year's amortization of accounting costs.

Current liabilities at September 30, 2019 were $387 million lower than at December 31, 2018. The change in current liabilities reflects primarily a decrease in notes payable ($262 million) (see Note D to the Third Quarter Financial Statements) and lower debt due within one year as of September 30, 2019 ($125 million).

Noncurrent liabilities at September 30, 2019 were $570 million higher than at December 31, 2018. The change in noncurrent liabilities reflects primarily the adoption of ASU No. 2016-02, “Leases (Topic 842)” ($595 million). See Note I to the Third Quarter Financial Statements. The change also reflects an increase in deferred income taxes and unamortized investment tax credits ($343 million), which reflects primarily the accelerated method/life of tax depreciation, repair deductions and the prepayment of New York City property taxes. See Note J to the Third Quarter Financial Statements. These increases are offset, in part, by a decrease in the liability for pension and retiree benefits ($375 million), which primarily reflects contributions to the pension and other retiree benefit plans made by the Utilities in 2019 and the final actuarial valuation, as measured at December 31, ~~2016,~~2018, of the plans in accordance with the accounting rules for retirement benefits. See Notes E and F to the Third Quarter Financial Statements.

Long-term debt at September 30, 2019 was $348 million higher than at December 31, 2018. The change in long-term debt reflects primarily the May 2019 issuance of $700 million of debentures offset, in part, by the reclassification of $350 million of long-term debt due June 2020 to long-term debt due within one year. See "Liquidity and Capital Resources - Cash Flows From Financing Activities" above and Note C to the Third Quarter Financial Statements.

Equity at September 30, 2019 was $1,169 million higher than at December 31, 2018. The change in equity reflects primarily capital contributions from parent ($875 million) in 2019 and net income for the nine months ended September 30, 2019 ($978 million), offset, in part, by common stock dividends to parent ($685 million) in 2019.

O&R

Current assets at September 30, 2019 were $8 million lower than at December 31, 2018. The change in current assets reflects primarily a decrease in cash and temporary cash investments ($14 million) and customer accounts

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receivables, less allowance for uncollectible accounts ($11 million). These decreases are offset, in part, by an increase in prepayments reflecting primarily the property tax payments made in the third quarter of 2019 that are amortized by year end ($18 million).

Net plant at September 30, 2019 was $89 million higher than at December 31, 2018. The change in net plant reflects primarily an increase in electric ($64 million) and gas ($47 million) plant balances, offset, in part, by an increase in accumulated depreciation ($29 million).

Other noncurrent assets at September 30, 2019 were $39 million lower than at December 31, 2018. The change in other noncurrent assets reflects primarily a decrease in the regulatory asset for unrecognized pension and other postretirement costs to reflect the final actuarial valuation, as measured at December 31, 2018, of the pension and other retiree benefit plans in accordance with the accounting rules for retirement benefits ($25 million). The change in the regulatory asset also reflects the ~~year’s~~year's amortization of accounting costs. The change also reflects a decrease in the regulatory asset for deferred storm costs ($7 million), environmental remediation costs ($5 million) and property tax reconciliation ($5 million).

Current liabilities at September 30, 2019 were $18 million higher than at December 31, 2018. The change in current liabilities reflects primarily an increase in accounts payable.

Noncurrent liabilities at September 30, 2019 were $34 million lower than at December 31, 2018. The change in noncurrent liabilities reflects primarily a decrease in the liability for pension and retiree benefits that primarily reflects ~~in part~~ contributions to the pension and other retiree benefit plans made by the Utilities in ~~2017.~~2019. See Notes E and F to the Third Quarter Financial Statements.

~~Deferred Income Taxes~~Equity at September 30, 2019 was $59 million higher than at December 31, 2018. The change in equity reflects primarily net income for the nine months ended September 30, 2019 ($60 million), a capital contribution from parent ($30 million) in 2019 and ~~Unamortized Investment Tax Credits~~

~~The~~an increase in other comprehensive income ($5 million), offset, in part, by common stock dividends to parent ($35 million) in 2019.

Clean Energy Businesses

Current assets at September 30, 2019 were $86 million higher than at December 31, 2018. The change in current assets reflects primarily increases in restricted cash and accrued unbilled revenue.

Net plant at September 30, 2019 was $115 million lower than at December 31, 2018. The change in net plant reflects primarily depreciation during the ~~liability for deferred income taxes and unamortized~~nine months ended September 30, 2019, investment tax credits and the reduction in the capitalized asset and related liability for ~~Con Edison and CECONY~~asset retirement obligations for certain property leased by renewable electric production projects, offset, in part, by additional capital expenditures.

Other noncurrent assets at September 30, 2019 were $149 million higher than at December 31, 2018. The change in other noncurrent assets reflects primarily ~~bonus depreciation in 2017, partially offset by~~ the ~~increase in deferred income tax assets associated with the federal tax attribute carryforwards related to the net operating loss and general business tax credits.~~adoption of ASU No. 2016-02, “Leases (Topic 842).” See Note I to the Third Quarter Financial Statements.

~~System Benefit Charge~~Current liabilities at September 30, 2019 were $211 million higher than at December 31, 2018. The change in current liabilities reflects primarily the reclassification of the PG&E-related project debt from long-term debt to long-term debt due within one year ($990 million), offset, in part, by the repayment of a borrowing under a 6-month term loan agreement ($825 million). See Note C to the Third Quarter Financial Statements.

Noncurrent liabilities at September 30, 2019 were $76 million higher than at December 31, 2018. The change in noncurrent liabilities reflects primarily the adoption of ASU No. 2016-02 “Leases (Topic 842)” ($222 million), offset, in part, by the reduction in the capitalized asset and related liability for asset retirement obligations for certain property leased by renewable electric production projects ($98 million) and an increase in deferred income taxes and unamortized investment tax credits ($81 million), which reflects primarily the ~~liability~~accelerated method/life of tax depreciation and additional unamortized investment tax credits on renewable energy projects. See Note I to the Third Quarter Financial Statements.

Long-term debt at September 30, 2019 was $206 million lower than at December 31, 2018. The change in long-term debt reflects primarily the reclassification of the PG&E-related project debt to long-term debt due within one year ($990 million), offset, in part, by an $825 million borrowing from parent company of the proceeds of parent

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company's February 2019 two-year variable-rate term loan agreement, $450 million of which was repaid to parent company, and a borrowing of $464 million, due 2026, secured by equity interests in solar electric production projects. See Note C to the Third Quarter Financial Statements.

Equity at September 30, 2019 was $39 million higher than at December 31, 2018. The change in equity reflects primarily an increase in noncontrolling interest ($62 million), offset, in part, by a net loss for the ~~system benefit charge~~nine months ended September 30, 2019 ($19 million).

CET

Current assets at September 30, 2019 were $32 million lower than at December 31, 2018. The change in current assets reflects ~~amounts collected~~an increased investment in Mountain Valley Pipeline, LLC and a NY Transco transmission project. See "Con Edison Transmission" below.

Investments at September 30, 2019 were $166 million higher than at December 31, 2018. The change in investments reflects primarily increased investment in Mountain Valley Pipeline, LLC and a NY Transco transmission project.

Equity at September 30, 2019 was $29 million higher than at December 31, 2018. The change in equity reflects primarily net income for the nine months ended September 30, 2019 ($38 million), offset, in part, by ~~the Utilities from their customers that will be required~~common stock dividends to ~~be paid to NYSERDA.~~parent ($9 million) in 2019.

Off-Balance Sheet Arrangements

In May 2019, Con Edison entered into a forward sale agreement which met the SEC definition of an off-balance sheet arrangement. See Note C to the Third Quarter Financial Statements. None of the Companies’ other transactions, agreements or other contractual arrangements ~~meets~~meet the SEC definition of off-balance sheet arrangements.

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Regulatory Matters

In March 2017, the NYSPSC issued an order that changes the way distributed energy resources are compensated and begins to phase out net energy metering. In New York, net energy metering compensates kilowatt-hours exported to the electric distribution system at the full service rate (that is production plus delivery plus taxes and fees). To provide a gradual transition, the NYSPSC allowed all existing resources to keep their current rate treatment and will delay making significant changes to policies affecting new residential and small commercial rooftop solar until 2020. Larger installations, including new commercial and industrial projects and new community solar projects, will be paid for the value of their exports to the electricity distribution system. The new policy establishes a 2 percent limit on bill increases, reducing the shifting of avoided distribution costs to non-participating residential customers that would have occurred under net energy metering.

In October 2017, the Environmental Defense Fund and the Natural Resources Defense Council requested the NYSPSC to prohibit CECONY from recovering costs under the company’s 20-year transportation contract for 250,000 dekatherms per day of capacity on the Mountain Valley Pipeline unless CECONY demonstrates compliance with a public interest standard.

For ~~additional~~ information about the Utilities’ regulatory matters, see Note B to the Third Quarter Financial Statements.

Environmental Matters

In May ~~2017,~~2019, New York City enacted a ~~transformer failure at a~~law designed to reduce greenhouse gas (GHG) emissions from large buildings 40 percent from 2005 levels by 2030. Building owners may achieve compliance through operational changes, building retrofits, the purchase of greenhouse gas offsets, the purchase of renewable energy credits and the use of clean distributed energy resources. CECONY ~~substation discharged thousands of gallons of transformer oil into~~is unable to predict the ~~soil. Some~~impact on it of the ~~transformer oil, which contained small amounts~~implementation of ~~polychlorinated biphenyls (PCBs), leaked into the East River. The company,~~this law.

In June 2019, the U.S. ~~Coast Guard,~~Environmental Protection Agency announced its Affordable Clean Energy (ACE) rule in conjunction with the repeal of its Clean Power Plan. In September 2019, Con Edison, as part of a coalition of public and private electric utilities, filed a petition in the United States Court of Appeals for the District of Columbia Circuit to challenge the Environmental Protection Agency’s ACE rule and the repeal of the Clean Power Plan. The ACE rule could have potential cost implications for the utilities because it has the effect of limiting flexibility to use measures such as emissions trading and averaging to cost-effectively meet emissions limits. The ACE rule could also adversely impact initiatives to develop renewable energy sources and promote the use of electric vehicles.

In July 2019, New York State enacted a law that establishes a program requiring 70 percent of the electricity procured by load serving entities regulated by the NYSPSC to be produced by renewable energy systems by 2030, and requiring the statewide electrical demand system to have zero emissions by 2040. The law also codifies state targets for energy efficiency (end-use energy savings of 185 trillion British thermal units below 2025 energy-use forecast), offshore wind (9,000 megawatts (MW) by 2035), solar (6,000 MW by 2025) and energy storage (3,000 MW by 2030). In addition, the law establishes a climate action council to recommend measures to attain the law’s GHG limits, including measures to reduce emissions by displacing fossil-fuel fired electricity with renewable electricity or energy efficiency. The law requires the New York State Department of Environmental Conservation to issue regulations establishing statewide GHG emissions limits that are 60 percent of 1990 emissions levels by 2030 and ~~other agencies responded~~15 percent of 1990 emissions by 2050. The Utilities are unable to predict the ~~incident. The company has replaced the transformer, and is continuing to remediate and monitor the site, the costs of which are not expected to have a material adverse effect~~impact on its financial condition, results of operations or liquidity. In connection with the incident, the company may incur monetary sanctions of more than $0.1 million for violations of certain provisions regulating the discharge of materials into, and for the protectionthem of the ~~environment.~~implementation of this law.

In June 2017, CECONY received a notice of potential liability from the U.S. Environmental Protection Agency (EPA) with respect to the Newtown Creek site that was listed in 2010 on the EPA’s National Priorities List of Superfund sites. The EPA has identified fourteen potentially responsible parties (PRPs) with respect to the site, including CECONY, and has indicated that it will notify the company as additional PRPs are identified and notified by the EPA. Newtown Creek and its tributaries (collectively, Newtown Creek) form a 3.8 mile border between Brooklyn and Queens, New York. Currently, the predominant land use around Newtown Creek includes industrial, petroleum, recycling, manufacturing and distribution facilities and warehouses. Other uses include trucking, concrete manufacture, transportation infrastructure and a wastewater treatment plant. Newtown Creek is near several residential neighborhoods. Six PRPs, not including CECONY, pursuant to an administrative settlement agreement and order on consent the EPA issued to them in 2011, have been performing a remedial investigation of the site. The EPA indicated that sampling events have shown the sediments in Newtown Creek to be contaminated with a wide variety of hazardous substances including PCBs, metals, pesticides, polycyclic aromatic hydrocarbons and volatile organic contaminants. The EPA also indicated that it has reason to believe that hazardous substances have come to be released from CECONY facilities into Newtown Creek. The EPA’s current schedule anticipates completion of a feasibility study for the site by late 2018 and issuance of its record of decision selecting a remedy for the site by late 2020. CECONY is unable to estimate its exposure to liability for the Newtown Creek site.

In the fourth quarter of 2016, CECONY and another utility responded to a reported dielectric fluid leak at a New Jersey marina on the Hudson River associated with one or two underwater transmission lines, the New Jersey portion of which is owned and operated by the other utility and the New York portion of which is owned and operated by CECONY. During the third quarter of 2017, after the marina owner had cleared substantial debris from its collapsed pier, a dielectric fluid leak was found and repaired on one of the underwater transmission lines. In the fourth quarter of 2017, it is anticipated that sediment regrading will be completed in underwater areas of the marina that had been disturbed during the leak search and repair efforts. Monitoring also will be conducted to evaluate whether any further action is necessary. CECONY expects that, consistent with the cost allocation provisions of their prior arrangements for the transmission lines, the costs to respond to the incident and repair the line, net of any recovery from the marina owner, will be shared by CECONY and the other utility. At September 30, 2017, the response and repair costs amounted to approximately $27 million, including those costs incurred by CECONY and those costs which the company has been notified have been incurred by the other utility and the U.S. Coast Guard.

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CECONY does not expect that its ultimate share of the costs to respond to the discharge and repair the transmission line will have a material adverse effect on its financial condition, results of operation or liquidity.

For additional information about the Companies’ environmental matters, see Note G to the Third Quarter Financial Statements.

~~Con Edison Development~~Clean Energy Businesses

The following table provides information about the Clean Energy Businesses' renewable electric production projects ~~Con Edison Development owned~~that are in operation and/or in construction at September 30, ~~2017:~~2019:

Project Name
Production
Technology
Generating
Capacity (a)
(MW AC)
Purchased Power Agreement (PPA)Term (In Years) (b)
Actual/Expected
In-Service Date (c)
Location
(State)
Wholly owned projects

Pilesgrove Solar 18 (d) 2011 New Jersey
Flemington Solar Solar 8 (d) 2011 New Jersey
Frenchtown I, II and III Solar 14 (d) 2011-13 New Jersey
PA Solar Solar 10 2012 Pennsylvania
California Solar 2 (e) Solar 80 20 2014-16 California
Oak Tree Wind Wind 20 20 2014 South Dakota
Texas Solar 3 Solar 6 25 2015 Texas
Texas Solar 5 (e) Solar 95 25 2015 Texas
Campbell County Wind Wind 95 30 2015 South Dakota
Texas Solar 7 (e) Solar 106 25 2016 Texas
California Solar 3 (e) Solar 110 20 2016 California
Adams Wind (e) Wind 23 7 2016 Minnesota
Valley View (e) Wind 10 14 2016 Minnesota
Coram (e) Wind 102 16 2016 California
Upton County Solar (e) Solar 158 25 2017 Texas
Projects of less than 5 MW Solar / Wind 25 Various Various Various
Jointly owned projects (e) (f)

California Solar Solar 55 25 2012-13 California
Mesquite Solar 1 Solar 83 20 2013 Arizona
Copper Mountain Solar 2 Solar 75 25 2013-15 Nevada
Copper Mountain Solar 3 Solar 128 20 2014-15 Nevada
Broken Bow II Wind 38 25 2014 Nebraska
Texas Solar 4 Solar 32 25 2014 Texas
Total MW (AC) in Operation
1,291

Panoche Valley Solar 240 20 2018 California
Total MW (AC) in Construction
240

Total MW (AC), All Projects
1,531



Project Name	Generating Capacity (MW AC)	Power Purchase Agreement (PPA) Term (In Years) (a)	Actual/Expected In-Service Date (b)	Location (State)	PPA Counterparty (c)
Utility Scale
Solar
PJM assets	53	(d)	2011/2013	New Jersey/Pennsylvania	Various
New England assets	24	Various	2011/2017	Massachusetts/Rhode Island	Various
California Solar (e) (g)	110	25	2012/2013	California	PG&E
Mesquite Solar 1 (e) (g)	165	20	2013	Arizona	PG&E
Copper Mountain Solar 2 (e) (g)	150	25	2013/2015	Nevada	PG&E
Copper Mountain Solar 3 (e) (g)	255	20	2014/2015	Nevada	SCPPA
California Solar 2 (e)	80	20	2014/2016	California	SCE/PG&E
Texas Solar 4 (e)	40	25	2014	Texas	City of San Antonio
Texas Solar 5 (e)	95	25	2015	Texas	City of San Antonio
Texas Solar 7 (e)	106	25	2016	Texas	City of San Antonio
California Solar 3 (e)	110	20	2016/2017	California	SCE/PG&E
Upton Solar (e)	158	25	2017	Texas	City of Austin
Panoche Valley	140	20	2017/2018	California	SCE
Copper Mountain Solar 1 (e)	58	12	2018	Nevada	PG&E
Copper Mountain Solar 4 (f) (e)	94	20	2018	Nevada	SCE
Mesquite Solar 2 (f) (e)	100	18	2018	Arizona	SCE
Mesquite Solar 3 (f) (e)	150	23	2018	Arizona	WAPA (Navy)
Great Valley Solar (f) (e)	200	17	2018	California	MCE/SMUD/PG&E/SCE
Wistaria Solar	100	20	2018	California	SCE
Other	26	Various	Various	Various	Various
Total Solar	2,214
Wind
Broken Bow II (e)	75	25	2014	Nebraska	NPPD
Wind Holdings (e)	180	Various	Various	Various	NWE/Basin Electric
Adams Rose Wind	23	7	2016	Minnesota	Dairyland
Coram Wind (e)	102	16	2016	California	PG&E
Other	22	Various	Various	Various	Various
Total Wind	402
Total MW (AC) in Operation	2,616
Total MW (AC) in Construction	18
Total MW (AC) Utility Scale	2,634
Behind the Meter
Total MW (AC) in Operation	46
Total MW (AC) in Construction	8
Total MW Behind the Meter	54


(a)	Represents Power Purchase Agreement (PPA) contractual term or remaining term from Con Edison Development’s date of acquisition.


(b)	Represents Actual/Expected In-Service Date or Con Edison Development's date of acquisition.


(c)	PPA Counterparties include: Pacific Gas and Electric Company (PG&E), Southern California Public Power Authority (SCPPA), Southern California Edison Company (SCE), Western Area Power Administration (WAPA), Marin Clean Energy (MCE), Sacramento Municipal Utility District (SMUD), Nebraska Public Power District (NPPD) and NorthWestern Energy (NWE)


(d)	Solar renewable energy credit hedges are in place, in lieu of PPAs, through 2022.


(e)	Project has been pledged as security for project debt financing.


(f)	Projects are financed with tax equity. See Note N to the Third Quarter Financial Statements.


(g)	Acquired remaining 50% interest in projects/portfolios in 2018.

~~(a) Represents~~

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Con Edison ~~Development’s ownership interest in~~Development

In January 2019, PG&E filed for reorganization under Chapter 11 of the ~~project.~~

~~(b) Represents PPA contractual term or remaining term from~~U.S. Bankruptcy Code. The output of Con Edison ~~Development’s date~~Development renewable electric production projects with an aggregate of ~~acquisition.~~

~~(c) Represents Actual/Expected In-Service Date or~~680 MW (AC) of generating capacity (PG&E Projects) is sold to PG&E under long-term power purchase agreements (PG&E PPAs). At September 30, 2019, Con Edison’s consolidated balance sheet included $827 million of net non-utility plant relating to the PG&E Projects, $1,075 million of intangible assets relating to the PG&E PPAs, $287 million of net non-utility plant of additional projects that secure the related project debt and $1,012 million of non-recourse related project debt. The PG&E bankruptcy is an event of default under the PG&E PPAs. Pursuant to the related project debt agreements, distributions from the related projects to Con Edison ~~Development's date of acquisition.~~

~~(d) Have Solar Renewable Energy Credit hedges in place, in lieu of PPAs, out to 2020.~~

~~(e) Project has~~Development have been ~~pledged to secure financing~~suspended. Unless the lenders for the ~~project.~~

~~(f) All of~~related project debt otherwise agree, the ~~jointly-owned projects~~lenders may, upon written notice, declare principal and interest on the related project debt to be due and payable immediately and, if such amounts are ~~50 percent owned, except for Texas Solar 4 (which is 80 percent owned).~~not timely paid, foreclose on the related projects. See “Long-Lived and Intangible Assets” in Note MA and Note C to the Third

Quarter Financial Statements.

Con Edison Development's renewable electric production volumes ~~generated~~ for the three and nine months ended September 30, ~~2017~~2019 compared with the ~~2016~~2018 period were:

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	Millions of kWh Generated										Millions of kWh
	For the Three Months Ended					For the Nine Months Ended					For the Three Months Ended					For the Nine Months Ended
Description	September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation	Percent Variation		September 30, 2019	September 30, 2018	Variation	Percent Variation
Renewable electric production projects
Solar	668	458	210	45.9	%	1,679	1,215	464	38.2	%	1,710	752	958	Large		4,443	2,087	2,356	Large
Wind	217	137	80	58.4	%	734	464	270	58.2	%	317	245	72	29.4	%	978	776	202	26.0	%
Total	885	595	290	48.7	%	2,413	1,679	734	43.7	%	2,027	997	1,030	Large		5,421	2,863	2,558	89.3	%

Con Edison Transmission

CET Electric

In April 2019, the New York Independent System Operator (NYISO) selected a transmission project that was jointly proposed by National Grid and NY Transco ($600 million estimated cost, excluding certain interconnection costs that are not yet determined) that would increase transmission capacity by 1,850 MW between upstate and downstate when combined with another developer’s project that was also selected by the NYISO. The siting, construction and operation of the projects will require approvals and permits from appropriate governmental agencies and authorities, including the NYSPSC. The NYISO indicated it will work with the developers to enter into agreements for the development and operation of the projects, including a schedule for entry into service by December 2023.

CET Gas

In October 2019, the operator of the Mountain Valley Pipeline, which is being constructed by a joint venture in which CET Gas has a 12.5 percent ownership interest, indicated that it now expects a late 2020 full in-service date for the project at an overall project cost of $5,300 million to $5,500 million, excluding allowance for funds used during construction. CET Gas, as it is permitted to do under the joint venture agreement, plans to limit its cash contributions to the joint venture to approximately $530 million, in which case its ownership interest in the joint venture would be reduced to approximately 10 percent (based on the current project cost estimate). At September 30, 2019, CET Gas’s cash contributions to the joint venture amounted to $488 million.

Financial and Commodity Market Risks

The Companies are subject to various risks and uncertainties associated with financial and commodity markets. The most significant market risks include interest rate risk, commodity price risk ~~credit risk~~ and investment risk.

Interest Rate Risk

The Companies’ interest rate risk relates primarily to variable rate debt and to new debt financing needed to fund capital requirements, including the construction expenditures of the Utilities and maturing debt securities. Con Edison and its ~~businesses~~subsidiaries manage interest rate risk through the issuance of mostly fixed-rate debt with varying maturities and through opportunistic refinancing of debt. The Clean Energy Businesses also use interest rate swaps. See Note L to the Third Quarter Financial Statements. Con Edison and CECONY estimate that at September 30, ~~2017,~~2019, a 10 percent increase in interest rates applicable to its variable rate debt would result in an increase in annual interest expense of ~~$2 million.~~$7 million and $4 million, respectively. Under CECONY’s current electric, gas

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and steam rate plans, variations in actual variable rate tax-exempt debt interest expense are reconciled to levels reflected in rates.

Commodity Price Risk

Con Edison’s commodity price risk relates primarily to the purchase and sale of electricity, gas and related derivative instruments. The Utilities and the Clean Energy Businesses apply risk management strategies to mitigate their related exposures. See Note KL to the Third Quarter Financial Statements.

Con Edison estimates that, as of September 30, ~~2017,~~2019, a 10 percent decline in market prices would result in a decline in fair value of ~~$66~~$83 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which ~~$60~~$78 million is for CECONY and $6$5 million is for O&R. Con Edison expects that any such change in fair value would be largely offset by directionally opposite changes in the cost of the electricity and gas purchased. In accordance with provisions approved by state regulators, the Utilities generally recover from customers the costs they incur for energy purchased for their customers, including gains and losses on certain derivative instruments used to hedge energy purchased and related costs.

The Clean Energy Businesses use a value-at-risk (VaR) model to assess the market price risk of their portfolio of electricity and gas commodity fixed-price purchase and sales commitments, physical forward contracts, generating assets and commodity derivative instruments. VaR represents the potential change in fair value of the portfolio due to changes in market prices, for a specified time period and confidence level. These businesses estimate VaR across their portfolio using a delta-normal variance/covariance model with a 95 percent confidence level, ~~and~~ compare the measured VaR results against performance due to actual prices and stress test the portfolio each quarter using an assumed 30 percent price change from forecast. Since the VaR calculation involves complex methodologies and estimates and assumptions that are based on past experience, it is not necessarily indicative of future results. VaR for the portfolio, assuming a one-day holding period, for the nine months ended September 30, ~~2017~~2019 and the year ended December 31, ~~2016,~~2018, respectively, was as follows:


95% Confidence Level, One-Day Holding Period	September 30, 2017		December 31, 2016	September 30, 2019		December 31, 2018
	(Millions of Dollars)			(Millions of Dollars)
Average for the period		$—	$2		$—		$—
High	1		4	1		1
Low	—		1	—		—

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~~Credit Risk~~

Investment Risk

The Companies’ investment risk relates to the investment of plan assets for their pension and other postretirement benefit plans and to the investments of ~~the Clean Energy Businesses and~~ Con Edison Transmission that are accounted for under the equity method.

The Companies’ current investment policy for pension plan assets includes investment targets of 5345 to 6355 percent ~~equities~~equity securities, 33 to 43 percent debt securities and 3510 to 4914 percent ~~fixed income and other securities.~~real estate. At September 30, ~~2017,~~2019, the pension plan investments consisted of 5850 percent equity securities, 39 percent debt securities and 4211 percent ~~fixed income and other securities.~~real estate.

For the Utilities’ pension and other postretirement benefit plans, regulatory accounting treatment is generally applied in accordance with the accounting rules for regulated operations. In accordance with the Statement of Policy issued by the NYSPSC and its current electric, gas and steam rate plans, CECONY defers for payment to or recovery from customers the difference between the pension and other postretirement benefit expenses and the amounts for such expenses reflected in rates. Generally, O&R also defers such difference pursuant to its rate plans.

Material Contingencies

For information about the PG&E bankruptcy, see “Long-Lived and Intangible Assets” in Note A and Note C to the Third Quarter Financial Statements. For information concerning potential liabilities arising from the Companies’ other material contingencies, see "Other Regulatory Matters" in Note B and Notes G and H to the Third Quarter Financial Statements.

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Item 3: Quantitative and Qualitative Disclosures About Market Risk

For information about the Companies’ primary market risks associated with activities in derivative financial instruments, other financial instruments and derivative commodity instruments, see “Financial and Commodity Market Risks,” in Part I, Item 2 of this report, which information is incorporated herein by reference.

Item 4: Controls and Procedures

The Companies maintain disclosure controls and procedures designed to provide reasonable assurance that the information required to be disclosed in the reports that they submit to the Securities and Exchange Commission (SEC) is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Securities Exchange Act of 1934, as amended, is accumulated and communicated to the issuer’s management, including its principal executive and principal financial officers, or persons performing similar functions, as appropriate to allow timely decisions regarding required disclosure. For each of the Companies, its management, with the participation of its principal executive officer and principal financial officer, has evaluated its disclosure controls and procedures as of the end of the period covered by this report and, based on such evaluation, has concluded that the controls and procedures are effective to provide such reasonable assurance. Reasonable assurance is not absolute assurance, however, and there can be no assurance that any design of controls or procedures would be effective under all potential future conditions, regardless of how remote.

There was no change in the Companies’ internal control over financial reporting that occurred during the Companies’ most recent fiscal quarter that has materially affected, or is reasonably likely to materially affect, the Companies’ internal control over financial reporting.

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Part II Other Information

Item 1: Legal Proceedings

For information about certain legal proceedings affecting the Companies, see the information on the PG&E

bankruptcy under "Long-Lived and Intangible Assets" in Note A and Note C, "Other Regulatory Matters" in Note B and Notes G and H to the financial statements in Part I, Item 1 of this report, ~~and "Environmental Matters" in Part I, Item 2 of this report,~~ which information is incorporated herein by reference.

Item 1A: Risk Factors

There were no material changes in the Companies’ risk factors compared to those disclosed in Item 1A of the Form 10-K.

Item 6: Exhibits

Con Edison



Exhibit 10.1	~~Exhibit 10.1.1~~	~~Amendment to the~~ Consolidated Edison, ~~Retirement Plan.~~Inc. Supplemental Defined Contribution Pension Plan
Exhibit ~~10.1.2~~ 31.1.1	~~Amendment to the Consolidated Edison Retirement Plan.~~
~~Exhibit 12.1~~	~~Statement of computation of Con Edison’s ratio of earnings to fixed charges for the nine-month periods ended September 30, 2017 and 2016, and the 12-month period ended December 31, 2016.~~
~~Exhibit 31.1.1~~	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer.
Exhibit 31.1.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer.
Exhibit 32.1.1	Section 1350 Certifications – Chief Executive Officer.
Exhibit 32.1.2	Section 1350 Certifications – Chief Financial Officer.
Exhibit 101.INS	XBRL Instance ~~Document.~~Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
Exhibit 101.SCH	XBRL Taxonomy Extension Schema.
Exhibit 101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
Exhibit 101.DEF	XBRL Taxonomy Extension Definition Linkbase.
Exhibit 101.LAB	XBRL Taxonomy Extension Label Linkbase.
Exhibit 101.PRE	XBRL Taxonomy Extension Presentation Linkbase.

CECONY



Exhibit ~~10.2.1~~ 31.2.1	~~CECONY Supplemental Medical Benefits.~~
~~Exhibit 12.2~~	~~Statement of computation of CECONY’s ratio of earnings to fixed charges for the nine-month periods ended September 30, 2017 and 2016, and the 12-month period ended December 31, 2016.~~
~~Exhibit 31.2.1~~	Rule 13a-14(a)/15d-14(a) Certifications – Chief Executive Officer.
Exhibit 31.2.2	Rule 13a-14(a)/15d-14(a) Certifications – Chief Financial Officer.
Exhibit 32.2.1	Section 1350 Certifications – Chief Executive Officer.
Exhibit 32.2.2	Section 1350 Certifications – Chief Financial Officer.
Exhibit 101.INS	XBRL Instance ~~Document.~~Document - the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.
Exhibit 101.SCH	XBRL Taxonomy Extension Schema.
Exhibit 101.CAL	XBRL Taxonomy Extension Calculation Linkbase.
Exhibit 101.DEF	XBRL Taxonomy Extension Definition Linkbase.
Exhibit 101.LAB	XBRL Taxonomy Extension Label Linkbase.
Exhibit 101.PRE	XBRL Taxonomy Extension Presentation Linkbase.

Pursuant to Item 601(b)(4)(iii)(A) of Regulation S-K, instruments defining the rights of holders of long-term debt of Con Edison’s subsidiaries other than CECONY, the total amount of which does not exceed ten percent of the total assets of Con Edison and its subsidiaries on a consolidated basis, are not filed as exhibits to Con Edison’s Form 10-K or Form 10-Q. Con Edison agrees to furnish to the SEC upon request a copy of any such instrument.

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Signatures

Pursuant to the requirements of the Securities Exchange Act of 1934, each Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.



	Consolidated Edison, Inc.
	Consolidated Edison Company of New York, Inc.

Date: November ~~2, 2017~~4, 2019	By	/s/ Robert Hoglund
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

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	For the Three Months Ended September 30,
	�� Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016
Beginning balance as of July 1,	$(10)	$5	$(6)	$2
Included in earnings	7	(4)	1	—
Included in regulatory assets and liabilities	(13)	(5)	(8)	(3)
Sales	—	4	—	—
Settlements	(4)	1	(1)	1
Ending balance as of September 30,	$(20)	$1	$(14)		$—



Project Name (a)	Generating Capacity (b) (MW AC)	Power Purchase Agreement Term (in Years)	Year of Initial Investment	Location	Maximum Exposure to Loss (Millions of Dollars) (c)
Copper Mountain Solar 3	128	20	2014	Nevada	$175
Mesquite Solar 1	83	20	2013	Arizona	102
Copper Mountain Solar 2	75	25	2013	Nevada	83
California Solar	55	25	2012	California	64
Broken Bow II	38	25	2014	Nebraska	44
Texas Solar 4	32	25	2014	Texas	47



	Three Months Variation		Nine Months Variation
(Millions of Dollars, except per share amounts)	Earnings per Share Variation	Net Income Variation	Earnings per Share Variation	Net Income Variation
CECONY (a)
Changes in rate plans and regulatory charges (b)	$0.12	$35	$0.29	$87
Weather impact on steam revenues	—	(1)	0.01	4
Other operations and maintenance expenses (c)	0.07	22	0.24	73
Depreciation, property taxes and other tax matters (d)	(0.10)	(30)	(0.36)	(108)
Other (e)	(0.06)	(13)	(0.17)	(32)
Total CECONY	0.03	13	0.01	24
O&R (a)
Changes in rate plans and regulatory charges	—	1	0.04	12
Other operations and maintenance expenses (f)	(0.01)	(2)	(0.03)	(9)
Depreciation and property taxes	(0.01)	(4)	(0.02)	(6)
Other (e)	—	—	0.01	1
Total O&R	(0.02)	(5)	—	(2)
Clean Energy Businesses
Operating revenues less energy costs (g)	0.10	32	0.10	31
Other operations and maintenance expenses (h)	(0.08)	(23)	(0.10)	(30)
Depreciation	(0.02)	(5)	(0.05)	(15)
Net interest expense	(0.01)	(3)	(0.02)	(6)
Other (e) (i)	(0.17)	(53)	(0.15)	(46)
Total Clean Energy Businesses	(0.18)	(52)	(0.22)	(66)
Con Edison Transmission (e) (j)	—	(1)	0.04	14
Other, including parent company expenses (e) (k)	0.02	5	0.03	11
Total variations	$(0.15)	$(40)	$(0.14)	$(19)



	Ratio of Earnings to Fixed Charges
	For the Nine Months Ended September 30, 2017	For the Nine Months Ended September 30, 2016	For the Twelve Months Ended December 31, 2016
Con Edison	3.8	4.0	3.6
CECONY	3.9	3.8	3.6



Project Name	Production Technology	Generating Capacity (a) (MW AC)	Purchased Power Agreement (PPA)Term (In Years) (b)	Actual/Expected In-Service Date (c)	Location (State)
Wholly owned projects
Pilesgrove	Solar	18	(d)	2011	New Jersey
Flemington Solar	Solar	8	(d)	2011	New Jersey
Frenchtown I, II and III	Solar	14	(d)	2011-13	New Jersey
PA Solar	Solar	10		2012	Pennsylvania
California Solar 2 (e)	Solar	80	20	2014-16	California
Oak Tree Wind	Wind	20	20	2014	South Dakota
Texas Solar 3	Solar	6	25	2015	Texas
Texas Solar 5 (e)	Solar	95	25	2015	Texas
Campbell County Wind	Wind	95	30	2015	South Dakota
Texas Solar 7 (e)	Solar	106	25	2016	Texas
California Solar 3 (e)	Solar	110	20	2016	California
Adams Wind (e)	Wind	23	7	2016	Minnesota
Valley View (e)	Wind	10	14	2016	Minnesota
Coram (e)	Wind	102	16	2016	California
Upton County Solar (e)	Solar	158	25	2017	Texas
Projects of less than 5 MW	Solar / Wind	25	Various	Various	Various
Jointly owned projects (e) (f)
California Solar	Solar	55	25	2012-13	California
Mesquite Solar 1	Solar	83	20	2013	Arizona
Copper Mountain Solar 2	Solar	75	25	2013-15	Nevada
Copper Mountain Solar 3	Solar	128	20	2014-15	Nevada
Broken Bow II	Wind	38	25	2014	Nebraska
Texas Solar 4	Solar	32	25	2014	Texas
Total MW (AC) in Operation		1,291
Panoche Valley	Solar	240	20	2018	California
Total MW (AC) in Construction		240
Total MW (AC), All Projects		1,531

For the Three Months Ended September 30, 2019

(Millions of Dollars)

Con Edison

Operating lease cost

Operating lease cash flows