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~~JUNE 30, ~~2017~~2018



¨	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

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)	Yes x	No ¨
Consolidated Edison Company of New York, Inc. (CECONY)	Yes x	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	Yes x	No ¨
CECONY	Yes x	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 filer x	Accelerated filer ¨	Non-accelerated filer ¨
Smaller reporting company ¨	Emerging growth company ¨
CECONY
Large accelerated filer ¨	Accelerated filer ¨	Non-accelerated filer x
Smaller reporting company ¨	Emerging growth company ¨

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 ¨	No x
CECONY	Yes ¨	No x

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As of ~~October~~July 31, ~~2017,~~2018, Con Edison had outstanding ~~310,068,797~~311,102,989 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
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
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~~2017
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	3942
ITEM 3	Quantitative and Qualitative Disclosures About Market Risk	6973
ITEM 4	Controls and Procedures	6973
PART II—Other Information		7074
ITEM 1	Legal Proceedings	7074
ITEM 1A	Risk Factors	7074
ITEM 6	Exhibits	7074
	Signatures	7175

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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 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 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.

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Consolidated Edison, Inc.

CONSOLIDATED INCOME STATEMENT (UNAUDITED)


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		For the Three Months Ended June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars/ Except Per Share Data)
(Millions of Dollars/Except Share Data)					2018	2017	2018	2017
OPERATING REVENUES
Electric	$2,675	$2,769	$6,573	$6,717	$1,951	$1,965	$3,828	$3,899
Gas	296	235	1,593	1,246	489	435	1,428	1,297
Steam	62	63	448	406	96	88	410	385
Non-utility	178	350	458	999	160	145	394	280
TOTAL OPERATING REVENUES	3,211	3,417	9,072	9,368	2,696	2,633	6,060	5,861
OPERATING EXPENSES
Purchased power	460	798	1,253	2,047	388	408	742	793
Fuel	30	29	169	133	38	38	162	139
Gas purchased for resale	115	81	584	320	194	149	572	470
Other operations and maintenance	852	840	2,406	2,447	756	732	1,592	1,471
Depreciation and amortization	337	305	998	905	354	332	702	662
Taxes, other than income taxes	544	528	1,597	1,523	540	511	1,110	1,052
TOTAL OPERATING EXPENSES	2,338	2,581	7,007	7,375	2,270	2,170	4,880	4,587
Gain on sale of retail electric supply business and solar electric production project	—	104	1	104	—	1	—	1
OPERATING INCOME	873	940	2,066	2,097	426	464	1,180	1,275
OTHER INCOME (DEDUCTIONS)
Investment income	20	20	59	27	36	34	57	53
Other income	20	31	43		6	3	11	9
Allowance for equity funds used during construction	3	3	8	7	3	2	7	5
Other deductions	(4)	(5)	(12)	(16)	(48)	(46)	(92)	(89)
TOTAL OTHER INCOME	39	49	98	61
TOTAL OTHER INCOME (DEDUCTIONS)					(3)	(7)	(17)	(22)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	912	989	2,164	2,158	423	457	1,163	1,253
INTEREST EXPENSE
Interest on long-term debt	183	174	539	504	190	179	380	356
Other interest	4	5	11	17	9	3	16	7
Allowance for borrowed funds used during construction	(2)	(1)	(5)	(4)	(2)	(2)	(5)	(3)
NET INTEREST EXPENSE	185	178	545	517	197	180	391	360
INCOME BEFORE INCOME TAX EXPENSE	727	811	1,619	1,641	226	277	772	893
INCOME TAX EXPENSE	270	314	599	602	38	102	156	330
NET INCOME	$457	$497	$1,020	$1,039	$188	$175	$616	$563
Net income per common share—basic	$1.48	$1.63	$3.33	$3.47	$0.60	$0.57	$1.98	$1.84
Net income per common share—diluted	$1.48	$1.62	$3.31	$3.46	$0.60	$0.57	$1.98	$1.84
DIVIDENDS DECLARED PER COMMON SHARE	$0.69	$0.67	$2.07	$2.01	$0.72	$0.69	$1.43	$1.38
AVERAGE NUMBER OF SHARES OUTSTANDING—BASIC (IN MILLIONS)	307.8	304.5	306.2	299.1	310.8	305.4	310.6	305.3
AVERAGE NUMBER OF SHARES OUTSTANDING—DILUTED (IN MILLIONS)	309.3	305.9	307.7	300.5	311.9	306.8	311.7	306.7

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,		For the Three Months Ended June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars)
(Millions of Dollars)					2018	2017	2018	2017
NET INCOME	$457	$497	$1,020	$1,039	$188	$175	$616	$563
OTHER COMPREHENSIVE INCOME, NET OF TAXES
Pension and other postretirement benefit plan liability adjustments, net of taxes	1			2	2	1	6	—
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1			2	2	1	6	—
COMPREHENSIVE INCOME	$458	$498	$1,021	$1,041	$190	$176	$622	$563

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 Six Months Ended June 30,
	2017	2016
	(Millions of Dollars)
(Millions of Dollars)			2018	2017
OPERATING ACTIVITIES
Net income	$1,020	$1,039	$616	$563
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	998	905	702	662
Deferred income taxes	626	524	155	359
Rate case amortization and accruals	(93)	(157)	(56)	(62)
Common equity component of allowance for funds used during construction	(8)	(7)	(7)	(5)
Net derivative gains	(4)	(7)	2
Gain on sale of retail electric supply business and solar electric production project	(1)	(104)
Unbilled revenue and net unbilled revenue deferrals			113	18
Gain on sale of solar electric production project			—	(1)
Other non-cash items, net	(1)	99	(55)	(61)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	1	(138)	5	128
Materials and supplies, including fuel oil and gas in storage	2	15	16	(18)
Other receivables and other current assets	(39)	90	(68)	12
Income taxes receivable	33	100
Taxes receivable			49	29
Prepayments	(433)	(403)	(36)
Accounts payable	(54)	142	(61)	(94)
Pensions and retiree benefits obligations, net	305	464	171	213
Pensions and retiree benefits contributions	(462)	(510)	(368)	(283)
Accrued taxes	(21)	(21)	(63)	(22)
Accrued interest	59	66	(4)	(18)
Superfund and environmental remediation costs, net	(9)	68	(6)
Distributions from equity investments	87	45	54	52
System benefit charge	194	193	94	132
Deferred charges, noncurrent assets and other regulatory assets	(18)	(104)	(233)	(45)
Deferred credits and other regulatory liabilities	(40)	116	244	(17)
Other current and noncurrent liabilities	85	(79)	(224)	72
NET CASH FLOWS FROM OPERATING ACTIVITIES	2,227	2,336	1,040	1,574
INVESTING ACTIVITIES
Utility construction expenditures	(2,148)	(2,057)	(1,602)	(1,425)
Cost of removal less salvage	(185)	(149)	(121)	(122)
Non-utility construction expenditures	(288)	(436)	(109)	(225)
Investments in electric and gas transmission projects	(29)	(1,040)	(51)	(16)
Investments in/acquisitions of renewable electric production projects	(1)	(241)	—	(1)
Proceeds from the transfer of assets to NY Transco	—	122
Proceeds from sale of assets	34	250	—	34
Restricted cash	13	(21)
Other investing activities	32	(145)	17	24
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,572)	(3,717)	(1,866)	(1,731)
FINANCING ACTIVITIES
Net payment of short-term debt	(698)	(928)
Net issuance/(payment) of short-term debt			292	(18)
Issuance of long-term debt	997	1,765	1,640	997
Retirement of long-term debt	(429)	(407)	(619)	(426)
Debt issuance costs	(12)	(16)	(16)	(11)
Common stock dividends	(600)	(570)	(420)	(398)
Issuance of common shares - public offering	343	702
Issuance of common shares for stock plans	37	38	26	25
Distribution to noncontrolling interest	—	(1)
NET CASH FLOWS (USED IN)/FROM FINANCING ACTIVITIES	(362)	583
CASH AND TEMPORARY CASH INVESTMENTS:
NET CASH FLOWS FROM FINANCING ACTIVITIES			903	169
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(707)	(798)	77	12
BALANCE AT BEGINNING OF PERIOD	776	944	844	830
BALANCE AT END OF PERIOD	$69	$146	$921	$842
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	$389	$372
Income taxes	$(34)	$(144)	$(2)	$(35)
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$352	$242	$333	$308
Issuance of common shares for dividend reinvestment	$35	$35	$24	$23
Software licenses acquired but unpaid as of end of period			$94	��

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)			June 30, 2018	December 31, 2017
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$69	$776	$866	$797
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 $64 and $63 in 2018 and 2017, respectively			1,097	1,103
Other receivables, less allowance for uncollectible accounts of $7 and $8 in 2018 and 2017, respectively			264	160
Taxes receivable			27	76
Accrued unbilled revenue	411	447	382	598
Fuel oil, gas in storage, materials and supplies, at average cost	337	339	318	334
Prepayments	592	159	214	178
Regulatory assets	109	100	90	67
Restricted cash	41	54	55	47
Other current assets	199	151	123	177
TOTAL CURRENT ASSETS	3,096	3,406	3,436	3,537
INVESTMENTS	1,977	1,921	2,057	2,001
UTILITY PLANT, AT ORIGINAL COST
Electric	28,595	27,747	29,702	28,994
Gas	7,972	7,524	8,690	8,256
Steam	2,458	2,421	2,496	2,473
General	2,891	2,719	3,167	3,008
TOTAL	41,916	40,411	44,055	42,731
Less: Accumulated depreciation	8,904	8,541	9,385	9,063
Net	33,012	31,870	34,670	33,668
Construction work in progress	1,415	1,175	1,714	1,605
NET UTILITY PLANT	34,427	33,045	36,384	35,273
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 $233 and $201 in 2018 and 2017, respectively			1,791	1,776
Construction work in progress	615	689	592	551
NET PLANT	36,728	35,216	38,767	37,600
OTHER NONCURRENT ASSETS
Goodwill	428		428
Intangible assets, less accumulated amortization of $12 and $6 in 2017 and 2016, respectively	114	124
Intangible assets, less accumulated amortization of $19 and $15 in 2018 and 2017, respectively			127	131
Regulatory assets	6,769	7,024	4,097	4,266
Other deferred charges and noncurrent assets	134	136	152	148
TOTAL OTHER NONCURRENT ASSETS	7,445	7,712	4,804	4,973
TOTAL ASSETS	$49,246	$48,255	$49,064	$48,111

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)			June 30, 2018	December 31, 2017
LIABILITIES AND SHAREHOLDERS’ EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$687	$39	$1,815	$1,298
Notes payable	356	1,054	869	577
Accounts payable	1,057	1,147	1,130	1,286
Customer deposits	344	352	349	346
Accrued taxes	43	64	45	108
Accrued interest	209	150	139	143
Accrued wages	105	101	108	105
Fair value of derivative liabilities	70	77	40	17
Regulatory liabilities	58	128	60	101
System benefit charge	628	434	629	535
Other current liabilities	358	297	272	386
TOTAL CURRENT LIABILITIES	3,915	3,843	5,456	4,902
NONCURRENT LIABILITIES
Provision for injuries and damages	164	160	159	153
Pensions and retiree benefits	1,443	1,847	959	1,443
Superfund and other environmental costs	745	753	728	737
Asset retirement obligations	256	246	320	314
Fair value of derivative liabilities	83	40	28	38
Deferred income taxes and unamortized investment tax credits	10,744	10,205	5,710	5,495
Regulatory liabilities	1,873	1,905	4,551	4,577
Other deferred credits and noncurrent liabilities	262	215	273	296
TOTAL NONCURRENT LIABILITIES	15,570	15,371	12,728	13,053
LONG-TERM DEBT	14,651	14,735	15,225	14,731
EQUITY
Common shareholders’ equity	15,102	14,298	15,648	15,418
Noncontrolling interest	8		7
TOTAL EQUITY (See Statement of Equity)	15,110	14,306	15,655	15,425
TOTAL LIABILITIES AND EQUITY	$49,246	$48,255	$49,064	$48,111

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)	Common Stock		Additional Paid-In Capital	Retained Earnings	Treasury Stock		Capital Stock Expense	Accumulated Other Comprehensive Income/(Loss)	Noncontrolling Interest	Total	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					Shares	Amount			Shares	Amount
BALANCE AS OF DECEMBER 31, 2015	293	$32	$5,030	$9,123	23	$(1,038)	$(61)	$(34)	$9	$13,061
BALANCE AS OF DECEMBER 31, 2017											310	$34	$6,298	$10,235	23	$(1,038)	$(85)	$(26)	$7	$15,425
Net income				310						310				616						616
Common stock dividends				(197)						(197)				(444)						(444)
Issuance of common shares for stock plans	1		28							28	1		52							52
Other comprehensive income										—								6		6
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
BALANCE AS OF JUNE 30, 2018											311	$34	$6,350	$10,407	23	$(1,038)	$(85)	$(20)	$7	$15,655

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 June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars)
(Millions of Dollars)					2018	2017	2018	2017
OPERATING REVENUES
Electric	$2,469	$2,557	$6,079	$6,222	$1,807	$1,817	$3,536	$3,610
Gas	268	208	1,421	1,113	435	388	1,276	1,153
Steam	62	63	448	406	96	88	410	386
TOTAL OPERATING REVENUES	2,799	2,828	7,948	7,741	2,338	2,293	5,222	5,149
OPERATING EXPENSES
Purchased power	400	495	1,110	1,216	343	363	645	710
Fuel	30	29	169	133	38		162	139
Gas purchased for resale	58	34	372	217	118	84	391	314
Other operations and maintenance	691	724	1,992	2,105	629	602	1,260	1,229
Depreciation and amortization	300	278	891	825	316	296	626	591
Taxes, other than income taxes	520	502	1,523	1,446	512	487	1,051	1,003
TOTAL OPERATING EXPENSES	1,999	2,062	6,057	5,942	1,956	1,870	4,135	3,986
OPERATING INCOME	800	766	1,891	1,799	382	423	1,087	1,163
OTHER INCOME (DEDUCTIONS)
Investment and other income	2	4	9	6	4	3	8	7
Allowance for equity funds used during construction	3	2	7	6	3	2	6	5
Other deductions	(5)	(4)	(10)		(42)	(40)	(81)	(78)
TOTAL OTHER INCOME	—	2	6	2
TOTAL OTHER INCOME (DEDUCTIONS)					(35)	(35)	(67)	(66)
INCOME BEFORE INTEREST AND INCOME TAX EXPENSE	800	768	1,897	1,801	347	388	1,020	1,097
INTEREST EXPENSE
Interest on long-term debt	155	150	456	440	162	151	324	301
Other interest	4	5	11	14	7	4	12	8
Allowance for borrowed funds used during construction	(2)	(1)	(4)	(3)	(2)	(1)	(4)	(3)
NET INTEREST EXPENSE	157	154	463	451	167	154	332	306
INCOME BEFORE INCOME TAX EXPENSE	643	614	1,434	1,350	180	234	688	791
INCOME TAX EXPENSE	242	226	551	491	31	91	150	309
NET INCOME	$401	$388	$883	$859	$149	$143	$538	$482

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,		For the Three Months Ended June 30,		For the Six Months Ended June 30,
	2017	2016	2017	2016
	(Millions of Dollars)
(Millions of Dollars)					2018	2017	2018	2017
NET INCOME	$401	$388	$883	$859	$149	$143	$538	$482
OTHER COMPREHENSIVE INCOME, NET OF TAXES					1	—	1	—
Pension and other postretirement benefit plan liability adjustments, net of taxes	1	—	1
TOTAL OTHER COMPREHENSIVE INCOME, NET OF TAXES	1	—	1
COMPREHENSIVE INCOME	$402	$388	$884	$860	$150	$143	$539	$482

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 Six Months Ended June 30,
	2017	2016
	(Millions of Dollars)
(Millions of Dollars)			2018	2017
OPERATING ACTIVITIES
Net income	$883	$859	$538	$482
PRINCIPAL NON-CASH CHARGES/(CREDITS) TO INCOME
Depreciation and amortization	891	825	626	591
Deferred income taxes	566	569	149	326
Rate case amortization and accruals	(107)	(170)	(65)	(72)
Common equity component of allowance for funds used during construction	(7)	(6)	(6)	(5)
Unbilled revenue and net unbilled revenue deferrals			36	18
Other non-cash items, net	(14)	7	(13)	(36)
CHANGES IN ASSETS AND LIABILITIES
Accounts receivable – customers	18	(79)	14	125
Materials and supplies, including fuel oil and gas in storage	(18)	15	10	(4)
Other receivables and other current assets	29	18	(74)	56
Accounts receivable from affiliated companies	12	38	(149)	17
Prepayments	(398)	(351)	(17)	(20)
Accounts payable	(20)	82	(71)	(60)
Accounts payable to affiliated companies	1	8	9	3
Pensions and retiree benefits obligations, net	274	439	157	191
Pensions and retiree benefits contributions	(416)	(472)	(367)	(281)
Superfund and environmental remediation costs, net	(7)	76	(9)	(4)
Accrued taxes	(18)	(17)	(66)	(17)
Accrued taxes to affiliated companies	(119)	(2)	(72)	(119)
Accrued interest	61	43	(1)	—
System benefit charge	175	176	86	120
Deferred charges, noncurrent assets and other regulatory assets	(60)	(153)	(164)	(72)
Deferred credits and other regulatory liabilities	77	165	229	11
Other current and noncurrent liabilities	(13)	(53)	(125)	(16)
NET CASH FLOWS FROM OPERATING ACTIVITIES	1,790	2,017	655	1,234
INVESTING ACTIVITIES
Utility construction expenditures	(2,020)	(1,932)	(1,509)	(1,341)
Cost of removal less salvage	(179)	(146)	(118)	(119)
Proceeds from the transfer of assets to NY Transco	—	122
Restricted cash	2	13
NET CASH FLOWS USED IN INVESTING ACTIVITIES	(2,197)	(1,943)	(1,627)	(1,460)
FINANCING ACTIVITIES
Net payment of short-term debt	(453)	(553)
Net issuance of short-term debt			400	150
Issuance of long-term debt	500	550	1,640	500
Retirement of long-term debt	—	(400)	(600)	—
Debt issuance costs	(7)	(6)	(16)	(6)
Capital contribution by parent	279	76	70	45
Dividend to parent	(597)	(558)	(423)	(398)
NET CASH FLOWS USED IN FINANCING ACTIVITIES	(278)	(891)
CASH AND TEMPORARY CASH INVESTMENTS:
NET CASH FLOWS FROM FINANCING ACTIVITIES			1,071	291
CASH, TEMPORARY CASH INVESTMENTS, AND RESTRICTED CASH:
NET CHANGE FOR THE PERIOD	(685)	(817)	99	65
BALANCE AT BEGINNING OF PERIOD	702	843	730	704
BALANCE AT END OF PERIOD	$17	$26	$829	$769
SUPPLEMENTAL DISCLOSURE OF CASH INFORMATION
Cash paid/(received) during the period for:
Interest	$388	$386	$324	$296
Income taxes	$96	$(130)	$227	$86
SUPPLEMENTAL DISCLOSURE OF NON-CASH INFORMATION
Construction expenditures in accounts payable	$240	$195	$284	$234
Software licenses acquired but unpaid as of end of period			$89	—

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)			June 30, 2018	December 31, 2017
ASSETS
CURRENT ASSETS
Cash and temporary cash investments	$17	$702	$829	$730
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 $59 and $58 in 2018 and 2017, respectively			994	1,009
Other receivables, less allowance for uncollectible accounts of $6 and $7 in 2018 and 2017, respectively			166	92
Taxes receivable			—	19
Accrued unbilled revenue	382	399	315	454
Accounts receivable from affiliated companies	97	109	213	64
Fuel oil, gas in storage, materials and supplies, at average cost	288	270	277	287
Prepayments	498	100	125	108
Regulatory assets	100	90	85	62
Restricted cash	—	2
Other current assets	62	95	85	84
TOTAL CURRENT ASSETS	2,550	2,880	3,089	2,909
INVESTMENTS	370	315	406	383
UTILITY PLANT, AT ORIGINAL COST
Electric	26,930	26,122	27,960	27,299
Gas	7,229	6,814	7,909	7,499
Steam	2,458	2,421	2,496	2,473
General	2,640	2,490	2,896	2,753
TOTAL	39,257	37,847	41,261	40,024
Less: Accumulated depreciation	8,170	7,836	8,622	8,321
Net	31,087	30,011	32,639	31,703
Construction work in progress	1,327	1,104	1,622	1,502
NET UTILITY PLANT	32,414	31,115	34,261	33,205
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 2018 and 2017			4	4
NET PLANT	32,418	31,119	34,265	33,209
OTHER NONCURRENT ASSETS
Regulatory assets	6,248	6,473	3,694	3,863
Other deferred charges and noncurrent assets	61	69	71	87
TOTAL OTHER NONCURRENT ASSETS	6,309	6,542	3,765	3,950
TOTAL ASSETS	$41,647	$40,856	$41,525	$40,451

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)				June 30, 2018	December 31, 2017
LIABILITIES AND SHAREHOLDER’S EQUITY
CURRENT LIABILITIES
Long-term debt due within one year	$600		$—	$1,711	$1,200
Notes payable	147	600		550	150
Accounts payable	802	876		922	1,057
Accounts payable to affiliated companies	11	10		19	10
Customer deposits	332	336		337	334
Accrued taxes	32	50		36	102
Accrued taxes to affiliated companies	—	119		—	72
Accrued interest	172	111		112	113
Accrued wages	95	91		97	95
Fair value of derivative liabilities	59	66		28	12
Regulatory liabilities	38	90		40	65
System benefit charge	573	398		569	483
Other current liabilities	207	242		215	245
TOTAL CURRENT LIABILITIES	3,068	2,989		4,636	3,938
NONCURRENT LIABILITIES
Provision for injuries and damages	158	154		153	147
Pensions and retiree benefits	1,150	1,544		665	1,140
Superfund and other environmental costs	648	655		631	637
Asset retirement obligations	234	227		293	287
Fair value of derivative liabilities	73	33		23	31
Deferred income taxes and unamortized investment tax credits	10,060	9,450		5,513	5,306
Regulatory liabilities	1,673	1,712		4,179	4,219
Other deferred credits and noncurrent liabilities	217	190		225	242
TOTAL NONCURRENT LIABILITIES	14,213	13,965		11,682	12,009
LONG-TERM DEBT	11,971	12,073		12,582	12,065
SHAREHOLDER’S EQUITY (See Statement of Shareholder’s Equity)	12,395	11,829		12,625	12,439
TOTAL LIABILITIES AND SHAREHOLDER’S EQUITY	$41,647	$40,856		$41,525	$40,451

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							Shares	Amount
BALANCE AS OF DECEMBER 31, 2015	235	$589	$4,247	$7,611	$(962)	$(61)	$(9)	$11,415
BALANCE AS OF DECEMBER 31, 2017									235	$589	$4,649	$8,231	$(962)	$(62)	$(6)	$12,439
Net income				310				310				538				538
Common stock dividend to parent				(186)				(186)				(423)				(423)
Capital contribution by parent			23					23			70					70
Other comprehensive income							—	—							1
BALANCE AS OF MARCH 31, 2016	235	$589	$4,270	$7,735	$(962)	$(61)	$(9)	$11,562
Net income				161				161
Common stock dividend to parent				(186)				(186)
Capital contribution by parent			28					28
Other comprehensive income							1
BALANCE AS OF JUNE 30, 2016	235	$589	$4,298	$7,710	$(962)	$(61)	$(8)	$11,566
Net income				388				388
Common stock dividend to parent				(186)				(186)
Capital contribution by parent			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
Net income				339				339
Common stock dividend to parent				(199)				(199)
Capital contribution by parent			22					22
Other comprehensive income							—	—
BALANCE AS OF MARCH 31, 2017	235	$589	$4,369	$8,063	$(962)	$(61)	$(7)	$11,991
Net income				143				143
Common stock dividend to parent				(199)				(199)
Capital contribution by parent			23					23
Other comprehensive income							—	—
BALANCE AS OF JUNE 30, 2017	235	$589	$4,392	$8,007	$(962)	$(61)	$(7)	$11,958
Net income				401				401
Common stock dividend to parent				(199)				(199)
Capital contribution by parent			235			(1)		234
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, 2018									235	$589	$4,719	$8,346	$(962)	$(62)	$(5)	$12,625

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

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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 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~~2017 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~~period ended March 31, ~~2017 and June 30, 2017.~~2018. Certain prior period amounts have been reclassified to conform to the current period presentation.

Con Edison has two 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 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

Revenues

Adoption of New Standard

On January 1, 2018, the Companies adopted Accounting Standards Codification (ASC) Topic 606, “Revenue from Contracts with Customers,” using the modified retrospective method applied to those contracts that were not completed. No charge to retained earnings for cumulative impact was required as a result of the Companies’ adoption of Topic 606.

Revenue Recognition

The following table presents, for the three and six months ended June 30, 2018, revenue from contracts with customers as defined in Topic 606, 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 June 30, 2018				For the Six Months Ended June 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	$1,771		$36	$1,807	$3,474		$62	$3,536
Gas	428		7	435	1,252		24	1,276
Steam	93		3	96	404		6	410
Total CECONY	$2,292		$46	$2,338	$5,130		$92	$5,222
O&R
Electric	146		(2)	144	293		—	293
Gas	47		7	54	148		4	152
Total O&R	$193		$5	$198	$441		$4	$445
Clean Energy Businesses
Renewables	73	(b)	—	73	205	(b)	—	205
Energy services	23		—	23	41		—	41
Other	—		62	62	—		145	145
Total Clean Energy Businesses	$96		$62	$158	$246		$145	$391
Con Edison Transmission	1		—	1	2		—	2
Other (c)	—		1	1	—		—	—
Total Con Edison	$2,582		$114	$2,696	$5,819		$241	$6,060

(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 total for Renewables revenue at the Clean Energy Businesses is $9 million and $97 million for the three and six months ended June 30, 2018, respectively, of revenue related to engineering, procurement and construction services.


(c)	Parent company and consolidation adjustments.

The Utilities recognize revenues for tariff-based sales as they deliver electricity, gas and steam energy to their customers. The amount of revenues recognized reflects the consideration the Utilities expect to receive in exchange for delivering the energy. The transaction price for full-service customers includes the Utilities’ energy cost and for all customers includes delivery charges determined based on customer class and in accordance with established tariffs and guidelines of the New York State Public Service Commission (NYSPSC) or the New Jersey Board of Public Utilities (NJBPU), as applicable. Accordingly, there is no unsatisfied performance obligation associated with these customers. The transaction price is allocated to the Utilities’ revenue generating activities through the customer billing process. Because energy is delivered over time, the Utilities use output methods that recognize revenue based on direct measurement of the value transferred, such as units delivered, which provides an accurate measure of value for the energy delivered. The Utilities accrue revenues at the end of each month for estimated energy delivered but not yet billed to customers. The Utilities defer over a 12-month period net interruptible gas revenues, other than those authorized by the NYSPSC to be retained by the Utilities, for refund to firm gas sales and transportation customers.

Con Edison Development recognizes revenue for the sale of energy from renewable electric production projects as energy is generated and billed to counterparties. Con Edison Development accrues revenues at the end of each month for energy generated but not yet billed to counterparties. Con Edison Energy recognizes revenue as energy is delivered and services are provided for managing energy supply assets leased from others and managing the dispatch, fuel requirements and risk management activities for generating plants and merchant transmission in the northeastern United States. Con Edison Solutions recognizes revenue for providing energy-efficiency services to government and commercial customers, and Con Edison Development recognizes revenue for engineering, procurement and construction services, under the percentage-of-completion method of revenue recognition.

Sales and profits on each percentage-of-completion contract are recorded each month based on the ratio of actual cumulative costs incurred to the total estimated costs at completion of the contract, multiplied by the total estimated contract revenue, less cumulative revenues recognized in prior periods (the ‘‘cost-to-cost’’ method). The impact of revisions of contract estimates, which may result from contract modifications, performance or other reasons, are recognized on a cumulative catch-up basis in the period in which the revisions are made.

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(Millions of Dollars)	Unbilled contract revenue (a)	Unearned revenue (b)
Beginning balance as of January 1, 2018	$58	$87
Additions (c)	73	31
Subtractions (c)	88	105	(d)
Ending balance as of June 30, 2018	$43	$13

(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 $105 million in subtractions from unearned revenue, $50 million was included in the balance as of December 31, 2017.

As of June 30, 2018, the aggregate amount of the remaining fixed performance obligations is $109 million, of which $72 million will be recognized within the next two years, and the remaining $37 million will be recognized pursuant to long-term service and maintenance agreements.

Revenues are recorded as energy is delivered, generated or services are provided and billed to customers. Amounts billed are recorded in accounts receivable - customers, with payment generally due the following month. Con Edison’s and the Utilities’ accounts receivable - customers balance also reflects the Utilities’ purchase of receivables from energy service companies to support retail choice programs. Accrued revenues not yet billed to customers are recorded as accrued unbilled revenues.

Utility Plant

At June 30, 2018, utility plant of Con Edison and CECONY included $94 million and $89 million, respectively, related to a May 2018 acquisition of software licenses. The software licenses asset is being amortized over a period of 15 years, and the estimated aggregate annual amortization expense for Con Edison and CECONY is $6 million. At June 30, 2018, the accumulated amortization was immaterial.

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” 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.

~~Table of Contents~~

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


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		For the Three Months Ended June 30,		For the Six Months Ended June 30,
(Millions of Dollars, except per share amounts/Shares in Millions)	2017	2016	2017	2016	2018	2017	2018	2017
Net income	$457	$497	$1,020	$1,039	$188	$175	$616	$563
Weighted average common shares outstanding – basic	307.8	304.5	306.2	299.1	310.8	305.4	310.6	305.3
Add: Incremental shares attributable to effect of potentially dilutive securities	1.5	1.4	1.5	1.4	1.1	1.4	1.1	1.4
Adjusted weighted average common shares outstanding – diluted	309.3	305.9	307.7	300.5	311.9	306.8	311.7	306.7
Net Income per common share – basic	$1.48	$1.63	$3.33	$3.47	$0.60	$0.57	$1.98	$1.84
Net Income per common share – diluted	$1.48	$1.62	$3.31	$3.46	$0.60	$0.57	$1.98	$1.84

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The computation of diluted EPS for the three and six months ended June 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~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016,~~2017, changes to accumulated other comprehensive income/(loss) (OCI) for Con Edison and CECONY are as follows:


	For the Three Months Ended September 30,				For the Three Months Ended June 30,
	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Beginning balance, accumulated OCI, net of taxes (a)	$(27)	$(33)	$(7)	$(8)	$(22)	$(28)	$(6)	$(7)
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	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) for Con Edison in 2018 and 2017 (a)(b)					2	1	1	—
Current period OCI, net of taxes	1	1	1	—	2	1	1	—
Ending balance, accumulated OCI, net of taxes	$(26)	$(32)	$(6)	$(8)	$(20)	$(27)	$(5)	$(7)


	For the Nine Months Ended September 30,				For the Six Months Ended June 30,
	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Beginning balance, accumulated OCI, net of taxes (a)	$(27)	$(34)	$(7)	$(9)	$(26)	$(27)	$(6)	$(7)
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) and $1 for Con Edison in 2018 and 2017, respectively					3	(2)	—	—
Amounts reclassified from accumulated OCI related to pension plan liabilities, net of tax of $(1) and $(2) for Con Edison in 2018 and 2017, respectively (a)(b)					3	2	1	—
Current period OCI, net of taxes	1	2	1	1	6	—	1	—
Ending balance, accumulated OCI, net of taxes	$(26)	$(32)	$(6)	$(8)	$(20)	$(27)	$(5)	$(7)


(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

On January 1, 2018, the Companies adopted Accounting Standard Update (ASU) 2016-18, "Statement of Cash Flows (Topic 230): Restricted Cash," which they applied retrospectively for each prior period presented. Pursuant to ASU 2016-18, cash, temporary cash investments and restricted cash are presented on a combined basis in the Companies’ consolidated statements of cash flows. At June 30, 2018 and 2017, cash, temporary cash investments and restricted cash for Con Edison and CECONY are as follows:



	At June 30,
	Con Edison		CECONY
(Millions of Dollars)	2018	2017	2018	2017
Cash and temporary cash investments	$866	$816	$829	$767
Restricted cash (a)	55	26	—	2
Total cash, temporary cash investments and restricted cash	$921	$842	$829	$769

(a)

Restricted cash is comprised of funding reserved for CECONY construction expenditures ($2 million at June 30, 2017), RECO transition bond charge collections, net of principal, interest, trustee and service fees ($1 million and $2 million at June 30, 2018 and 2017, respectively) that are restricted until the bond matures in 2019, and the CEBs' cash collateral held for project finance agreements ($54 million and $22 million at June 30, 2018 and 2017, respectively) that are restricted until varying maturity dates. For these projects, such funds are restricted to being used for normal operating expenses and capital expenditures, debt service, and required reserves.

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Note B —– Regulatory Matters

Rate Plans

~~Rockland~~O&R New York – Electric ~~Company (RECO)~~

In ~~February 2017, the New Jersey Board of Public Utilities (NJBPU) approved a stipulation of settlement for a RECO~~May 2018, in O&R's electric rate ~~plan commencing March 2017. The following table contains~~proceeding, the NYSPSC staff recommended a ~~summary of the~~$10.6 million increase in O&R's electric ~~rate plan.~~



~~RECO~~
~~Effective period~~		~~March 2017 (a)~~
~~Base rate changes~~		~~Yr. 1 - $1.7 million~~
~~Amortization to income of net regulatory (assets) and liabilities~~		~~$0.2 million over three years and continuation of $(25.6) million of deferred storm costs over four years expiring July 31, 2018 (b)~~
~~Recoverable energy costs~~		~~Current rate recovery of purchased power costs.~~
~~Cost reconciliations~~		~~None~~
~~Average rate base~~		~~Yr. 1 - $178.7 million~~
~~Weighted average cost of capital (after-tax)~~		~~7.47 percent~~
~~Authorized return on common equity~~		~~9.6 percent~~
~~Cost of long-term debt~~		~~5.37 percent~~
~~Common equity ratio~~		~~49.7 percent~~


~~(a)~~	~~Effective until a new rate plan approved by the NJBPU goes into effect.~~


~~(b)~~	In January 2016, the NJBPU approved RECO’s plan to spend $15.7 million in capital over three years to harden its electric system against storms, the costs of which RECO, beginning in 2017, is collecting through a customer surcharge.

In September 2017, RECO, the New Jersey Division of Rate Counsel and the New Jersey Board of Public Utilities entered into a settlement agreement, which is subject to FERC approval, that increases RECO's annual transmission revenue requirement from $11.8 million to $17.7 million, effective April 2017. The revenue requirement reflects arates (reflecting an authorized return on common equity of ~~10.0 percent.~~8.6 percent). In June 2018, O&R filed an update to its requested rate increase, changing its request to a $30.4 million increase (reflecting an authorized return on common equity of 9.75 percent).

O&R New York – Gas

In May 2018, in O&R's gas rate proceeding, the NYSPSC staff recommended a $6.7 million decrease in O&R's gas rates (reflecting an authorized return on common equity of 8.6 percent). In June 2018, O&R filed an update to its requested rate increase, changing its request to a $0.5 million decrease (reflecting an authorized return on common equity of 9.75 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 is 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. Through June 30, 2018, the company incurred costs related to this matter of $180 million. Included in this amount is $30 million in capital and operating and maintenance costs reflected in the company's electric rate plan and $150 million deferred as a regulatory asset pursuant to the rate plan. The company, which plans to complete the required actions in 2018, expects to incur costs related to this matter during the remainder of 2018 of $84 million. Included in this amount is $2 million in expected capital and operating and maintenance costs reflected in the rate plan and $82 million expected to be deferred as a regulatory asset pursuant to the rate plan.

In ~~July~~December 2017, the ~~Chairman~~NYSPSC issued an order initiating a proceeding to study the potential effects of the ~~NYSPSC notified the company that the April 21,~~federal Tax Cuts and Jobs Act of 2017 ~~subway power outage incident will likely result in a prudence review~~(TCJA) on income tax expense and liabilities of ~~the reasonableness of CECONY's actions and conduct. The order did not commence a prudence review or address cost recovery. Under the~~ New York State ~~Administrative Procedure Act,~~utilities and the regulatory treatment to preserve the resulting benefits for customers. Upon enactment of the TCJA in December 2017, CECONY and O&R re-measured their deferred tax assets and liabilities and accrued net regulatory liabilities for future income taxes of $3,513 million and $161 million, respectively. Under the rate normalization requirements continued by the TCJA, the portion of their net regulatory liabilities related to certain accelerated tax depreciation benefits ($2,542 million and $126 million, respectively) is to be amortized over the remaining lives of the related assets. The remainder, or "unprotected portion," ($971 million and $35 million, respectively) will be amortized as determined by the NYSPSC.

In March 2018, the NYSPSC staff recommended that the NYSPSC require most New York State utilities to begin on October 1, 2018 to credit their customers’ bills with the net benefits of the TCJA as measured based on amounts reflected in their rate plans prior to the enactment of the TCJA. 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 the utilities collected from their customers that will not need to be paid to the Internal Revenue Service under the TCJA.

In June 2018, CECONY, O&R and other New York State utilities filed comments on the March 2018 NYSPSC staff recommendation. CECONY proposed to defer providing its electric customers with the net benefits of the TCJA allocable to them until its next electric rate proceeding, unless the NYSPSC determines that CECONY's electric customers should be credited sooner with a portion of the net benefits (for example, 20 percent). CECONY also proposed to begin on October 1, 2018 to credit its gas and steam customers’ bills with the net benefits allocable to them. CECONY’s proposals reflect deferral and amortization over a five-year period of the revenue requirement impact of the company’s net reduction in federal income tax expense in 2018 and 2019 due to the TCJA (except that for steam customers the impact after September 30, 2018 would be credited on a current monthly basis) and amortization over the remaining lives of the related assets of CECONY’s net regulatory liability for future income taxes (except that, for electric customers, the unprotected portion of the net regulatory liability would be amortized

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over a five-year period). In its ongoing rate proceedings (see “Rate Plans,” above), O&R has proposed and the NYSPSC staff has recommended that the company amortize over a five-year period the impact of its net reduction in federal income tax expense in 2018 due to the TCJA and amortize its net regulatory liability for future income taxes over the remaining lives of the related assets.

For the six months ended June 30, 2018, the Utilities deferred as regulatory liabilities estimated net benefits of the TCJA of $217 million, which represented approximately half of their estimated annual net benefits.

In January 2018, the NYSPSC issued an order ~~could not remain~~initiating a focused operations audit of the income tax accounting of certain utilities, including CECONY and O&R.

In January 2018, the NJBPU issued an order initiating a proceeding to consider the TCJA. In June 2018, the NJBPU made permanent its previously approved $2.9 million interim decrease in ~~effect~~Rockland Electric Company's (RECO) electric base rates, effective April 1, 2018, and ordered RECO to pay to its customers in July 2018 its approximately $1 million of net benefits of the TCJA for ~~more than 90 days without further action~~the three-month period ended March 31, 2018 and to begin in July 2018 to refund to its customers the unprotected portion of its net regulatory liability for future income taxes over a three-year period. Also in March 2018, the Federal Energy Regulatory Commission (FERC) issued an order directing RECO to propose revisions to its transmission revenue requirement to reflect the TCJA. RECO’s net regulatory liability for future income taxes resulting from its re-measurement of its deferred tax asset and liabilities is $28 million (including $16 million subject to the normalization requirements continued by the TCJA).

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. Through June 30, 2018, CECONY's costs related to March 2018 storms, including Riley and Quinn, amounted to $126 million, including operation and maintenance expenses reflected in its electric rate plan ($17 million), operation and maintenance expenses charged against a storm reserve pursuant to its electric rate plan ($75 million), capital expenditures ($28 million) and removal costs ($6 million). O&R and RECO had storm-related costs of $48 million and $18 million, respectively, most of which were deferred as regulatory assets pursuant to their electric rate plans. Recovery of CECONY and O&R storm-related costs is subject to review by the NYSPSC, ~~because it was adopted on an emergency basis. At its October 19, 2017 meeting,~~and recovery of RECO storm-related costs is subject to review by the ~~NYSPSC approved another order in this proceeding.~~NJBPU. The NYSPSC ~~has not yet issued this~~is investigating the preparation and response to the storms by CECONY, O&R, and other ~~order.~~New York electric utilities, including all aspects of their emergency response plans, and may penalize them. In July 2018, the NJBPU adopted NJBPU staff's recommendations to increase requirements for New Jersey utilities, including RECO, relating to pre-storm preparations, restoration of service and communications and outreach. The ~~company is~~Companies are unable to estimate the amount or range of their possible loss in connection with the storms.

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 ~~possible costs related~~option to ~~this matter.~~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 CECONY’s electric rate plan, unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service.

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

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Regulatory Assets and Liabilities

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


	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Regulatory assets
Unrecognized pension and other postretirement costs	$2,626	$2,874	$2,476	$2,730	$2,167	$2,526	$2,039	$2,376
Future income tax	2,419	2,439	2,308	2,325
Environmental remediation costs	803	823	690	711	772	793	662	677
Revenue taxes	341	295	325	280	276	260	264	248
MTA power reliability deferral					150	50	150	50
Pension and other postretirement benefits deferrals					74	79	57	58
Property tax reconciliation					77	51	57	25
Municipal infrastructure support costs					72	56	72	56
Recoverable energy costs					66	60	59	52
Deferred storm costs					82	38	—	—
Deferred derivative losses	88	48	78	42	36	44	30	37
Pension and other postretirement benefits deferrals	70	38	45	7
Municipal infrastructure support costs	57	44	57	44
Deferred storm costs	43	56	—	3
Unamortized loss on reacquired debt	39	43	37	41	34	37	32	35
Indian Point Energy Center program costs	32	50	32	50
O&R property tax reconciliation	29	37	—	—
Meadowlands heater odorization project					33	18	33	18
Brooklyn Queens demand management program	28	29	28	29	30	37	30	37
Preferred stock redemption	24	25	24	25	24	24	24
Surcharge for New York State assessment	18	28	16	26
Indian Point Energy Center program costs					20	29	20	29
Recoverable REV demonstration project expenses					18	19	16	17
Gate station upgrade project					14	13	14	13
Net electric deferrals	13	24	13	24	8	9	8	9
Workers’ compensation	12	13	12	13	6	10	6	10
O&R transition bond charges	10	15	—	—	5	9	—	—
Recoverable energy costs	4	42	4	38
Other	113	101	103	85	133	104	121	92
Regulatory assets – noncurrent	6,769	7,024	6,248	6,473	4,097	4,266	3,694	3,863
Deferred derivative losses	81	91	75	86	44	40	39	37
Recoverable energy costs	28	9	25	4	46	27	46	25
Regulatory assets – current	109	100	100	90	90	67	85	62
Total Regulatory Assets	$6,878	$7,124	$6,348	$6,563	$4,187	$4,333	$3,779	$3,925
Regulatory liabilities
Future income tax					$2,512	$2,545	$2,359	$2,390
Allowance for cost of removal less salvage	$798	$755	$671	$641	872	846	741	719
TCJA net benefits*					217	—	202	—
Pension and other postretirement benefit deferrals	202	193	174	162	145	207	122	181
Energy efficiency portfolio standard unencumbered funds					125	127	119	122
Net unbilled revenue deferrals	166	145	166	145	96	183	96	183
Unrecognized other postretirement costs					78	92	78	92
Property tax reconciliation	140	178	140	178	76	107	76	107
Unrecognized other postretirement costs	84	60	84	60
Settlement of prudence proceeding	73	95	73	95	51	66	51	66
Property tax refunds					45	44	45	44
Carrying charges on repair allowance and bonus depreciation	49	68	48	67	29	43	29	42
Earnings sharing - electric, gas and steam					28	29	18	19
New York State income tax rate change	48	61	48	60	26	36	26	35
Settlement of gas proceedings					24	27	24	27
Variable-rate tax-exempt debt – cost rate reconciliation	36	55	32	48	16	30	14	26
Property tax refunds	28	1	28	1
Settlement of gas proceedings	27		27
Base rate change deferrals	26	40	26	40	15	21	15	21
Earnings sharing - electric, gas and steam	24	39	15	28
Net utility plant reconciliations	11	16	8	15	9	12	5	8
Other	161	172	133	145	187	162	159	137
Regulatory liabilities – noncurrent	1,873	1,905	1,673	1,712	4,551	4,577	4,179	4,219
Refundable energy costs	29		9	5	34	41	16
Deferred derivative gains					14	31	12	28
Revenue decoupling mechanism	27	71	27	61	12	29	12	21
Deferred derivative gains	2	28	2	24
Regulatory liabilities – current	58	128	38	90	60	101	40	65
Total Regulatory Liabilities	$1,931	$2,033	$1,711	$1,802	$4,611	$4,678	$4,219	$4,284

* See "Other Regulatory Matters," above.

~~Note C — Capitalization~~

In March 2017, Con Edison issued $400 million aggregate principal amount of 2.00 percent debentures, due 2020, and prepaid the $400 million variable rate term loan that was to mature in 2018. Also, in March 2017, a Con Edison

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~~Development subsidiary~~Note C – Capitalization

In April 2018, CECONY redeemed at maturity $600 million of 5.85 percent 10-year debentures. In May 2018, CECONY issued ~~$97~~$300 million ~~aggregate principal amount~~ of ~~4.45~~3.80 percent ~~senior notes, due 2042, secured by the company’s Upton County Solar project.~~10-year debentures and $700 million of 4.50 percent 40-year debentures. In June ~~2017,~~2018, the $636 million of CECONY's tax-exempt debt for which the interest rates were to be determined pursuant to periodic auctions was called for redemption on various dates in July and August 2018, and CECONY issued ~~$500~~$640 million ~~aggregate principal amount~~ of 3.875 percent debentures, due 2047. In August 2017, Con Edison issued 4.1 million common shares resulting in net proceeds of $343 million, after issuance expenses, that were invested by Con Edison in its subsidiaries, principally CECONY and the Clean Energy Businesses, for funding of their construction expenditures and for other general corporate purposes.floating rate debentures.

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


(Millions of Dollars)	2017		2016		2018		2017
Long-Term Debt (including current portion) (a)	Carrying Amount	Fair Value	Carrying Amount	Fair Value	Carrying Amount	Fair Value	Carrying Amount	Fair Value
Con Edison	$15,338	$17,195	$14,774	$16,093	$17,040	$17,944	$16,029	$18,147
CECONY	$12,571	$14,213	$12,073	$13,268	$14,293	$15,108	$13,265	$15,163


(a)	Amounts shown are net of unamortized debt expense and unamortized debt discount of ~~$137~~$152 million and ~~$115~~$133 million for Con Edison and CECONY, respectively, as of ~~September~~June 30, ~~2017~~2018 and ~~$134~~$142 million and ~~$113~~$121 million for Con Edison and CECONY, respectively, as of December 31, ~~2016.~~2017.

Fair values of long-term debt have been estimated primarily using available market information. For Con Edison, ~~$16,559~~$636 million and ~~$636~~$17,308 million of the fair value of long-term debt at ~~September~~June 30, ~~2017~~2018 are classified as Level 21 and Level 3,2, respectively. For CECONY, ~~$13,577~~$636 million and ~~$636~~$14,472 million of the fair value of long-term debt at ~~September~~June 30, ~~2017~~2018 are classified as Level 21 and Level 3,2, respectively (see Note L). ~~The $636 million of long-term debt classified as Level 3 is CECONY’s tax-exempt, auction-rate securities for which the market is highly illiquid and there is a lack of observable inputs.~~

Note D —– Short-Term Borrowing

At ~~September~~June 30, ~~2017,~~2018, Con Edison had ~~$356~~$869 million of commercial paper outstanding of which ~~$147~~$550 million was outstanding under CECONY’s program. The weighted average interest rate at ~~September~~June 30, ~~2017~~2018 was ~~1.3~~2.2 percent for both Con Edison and CECONY. At December 31, ~~2016,~~2017, Con Edison had ~~$1,054~~$577 million of commercial paper outstanding of which ~~$600~~$150 million was outstanding under CECONY’s program. The weighted average interest rate at December 31, ~~2016~~2017 was ~~1.0~~1.8 percent for both Con Edison and CECONY.

At ~~September~~June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, no loans were outstanding under the 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~~June 30, ~~2017~~2018 and December 31, ~~2016, respectively.~~2017.

Note E —– Pension Benefits

Total Periodic Benefit Cost

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


	For the Three Months Ended September 30,				For the Three Months Ended June 30,
	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Service cost – including administrative expenses	$66	$69	$61	$65	$72	$66	$68	$61
Interest cost on projected benefit obligation	148	149	139	140	140	148	131	139
Expected return on plan assets	(243)	(237)	(229)	(225)	(258)	(243)	(245)	(229)
Recognition of net actuarial loss	149	149	141	141	172	149	163	141
Recognition of prior service costs	(4)	1	(5)	—
Recognition of prior service cost/(credit)					(4)	(4)	(5)	(5)
TOTAL PERIODIC BENEFIT COST	$116	$131	$107	$121	$122	$116	$112	$107
Cost capitalized	(40)	(51)	(37)	(49)	(31)	(51)	(29)	(48)
Reconciliation to rate level	(14)	10	(16)	13	(23)	(3)	(25)	(5)
Cost charged to operating expenses	$62	$90	$54	$85
Total expense recognized					$68	$62	$58	$54

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	For the Nine Months Ended September 30,				For the Six Months Ended June 30,
	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Service cost – including administrative expenses	$197	$207	$184	$194	$145	$132	$136	$123
Interest cost on projected benefit obligation	444	447	416	419	280	296	263	277
Expected return on plan assets	(726)	(711)	(689)	(674)	(516)	(484)	(490)	(459)
Recognition of net actuarial loss	446	447	423	424	344	297	326	282
Recognition of prior service costs	(13)	3	(14)	1
Recognition of prior service cost/(credit)					(9)	(9)	(10)
TOTAL PERIODIC BENEFIT COST	$348	$393	$320	$364	$244	$232	$225	$213
Cost capitalized	(134)	(157)	(125)	(148)	(62)	(94)	(59)	(88)
Reconciliation to rate level	(28)	35	(32)	39	(46)	(14)	(50)	(16)
Cost charged to operating expenses	$186	$271	$163	$255
Total expense recognized					$136	$124	$116	$109

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 Companies adopted ASU 2017-07 beginning on January 1, 2018. The guidance requires that components of net periodic benefit cost other than service cost be presented outside of operating income on consolidated income statements, and that only the service cost component is eligible for capitalization. Accordingly, the service cost components are 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. As permitted by a practical expedient under ASU 2017-07, the Companies applied the presentation requirements retrospectively for both pension and other postretirement benefit costs using amounts disclosed in prior-period financial statements as appropriate estimates.

Expected Contributions

Based on estimates as of ~~September~~June 30, ~~2017,~~2018, the Companies expect to make contributions to the pension plans during ~~2017~~2018 of ~~$450~~$472 million (of which ~~$412~~$433 million is to be contributed 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~~six months of ~~2017,~~2018, the Companies contributed ~~$446~~$368 million to the pension plans, ~~(of~~nearly all of which ~~$409 million~~ was contributed by ~~CECONY).~~CECONY. CECONY also contributed ~~$14~~$17 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 for the three and ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 were as follows:

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,				For the Three Months Ended June 30,
	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Service cost	$15	$13	$10		$5	$5	$3
Interest cost on accumulated other postretirement benefit obligation	34	36	28	30	11	11	9	10
Expected return on plan assets	(52)	(58)	(45)	(50)	(18)	(17)	(16)	(15)
Recognition of net actuarial loss/(gain)	2	4	(2)	2	2	1	1	(1)
Recognition of prior service cost	(13)	(15)	(9)	(11)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST	$(14)	$(20)	$(18)	$(19)
Recognition of prior service cost/(credit)					(2)	(4)	(1)	(3)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT)					$(2)	$(4)	$(4)	$(6)
Cost capitalized	6	5	7	5	(2)	2	(1)	3
Reconciliation to rate level	(3)	20	(1)	19	2	(1)	2	(1)
Cost charged to operating expenses	$(11)	$5	$(12)	$5
Total expense/(credit) recognized					$(2)	$(3)	$(3)	$(4)

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	For the Six Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2018	2017	2018	2017
Service cost	$10	$10	$7	$7
Interest cost on accumulated other postretirement benefit obligation	21	23	17	19
Expected return on plan assets	(37)	(35)	(31)	(30)
Recognition of net actuarial loss/(gain)	4	1	1	(2)
Recognition of prior service cost/(credit)	(3)	(8)	(1)	(6)
TOTAL PERIODIC OTHER POSTRETIREMENT BENEFIT COST/(CREDIT)	$(5)	$(9)	$(7)	$(12)
Cost capitalized	(4)	4	(3)	5
Reconciliation to rate level	5	(2)	5	(1)
Total expense/(credit) recognized	$(4)	$(7)	$(5)	$(8)

For information about the adoption of ASU 2017-07, “Compensation-Retirement Benefits (Topic 715): Improving the Presentation of Net Periodic Pension Cost and Net Periodic Postretirement Benefit Cost,” see Note E.

Contributions

~~During the first nine months~~Based on estimates as of ~~2017,~~June 30, 2018, Con Edison ~~contributed $16~~and CECONY expect to make a contribution of $6 million (substantially all of which ~~$8 million was~~is to be contributed by ~~CECONY,~~CECONY) to the other postretirement benefit ~~plans.~~plans in 2018. 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~~June 30, ~~2017~~2018 and December 31, ~~2016~~2017 were as follows:


	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Accrued Liabilities:
Manufactured gas plant sites	$659	$664	$563	$567	$645	$651	$548	$551
Other Superfund Sites	86	89	85	88	83	86	83	86
Total	$745	$753	$648	$655	$728	$737	$631	$637
Regulatory assets	$803	$823	$690	$711	$772	$793	$662	$677

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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 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~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 were as follows:

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

~~Table of Contents~~



	For the Three Months Ended June 30,
	Con Edison		CECONY
(Millions of Dollars)	2018	2017	2018	2017
Remediation costs incurred	$6	$7	$5	$4


	For the Nine Months Ended September 30,				For the Six Months Ended June 30,
	Con Edison		CECONY		Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
Remediation costs incurred	$18	$20	$13	$10	$9	$14	$8	$11

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

In ~~2016,~~2017, 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~~$2.7 billion and ~~$2.6~~$2.5 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~~June 30, ~~2017,~~2018, 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~~June 30, ~~2017~~2018 and December 31, ~~2016~~2017 were as follows:

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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	Con Edison		CECONY
(Millions of Dollars)	2018	2017	2018	2017
Accrued liability – asbestos suits	$8	$8	$7	$7
Regulatory assets – asbestos suits	$8	$8	$7	$7
Accrued liability – workers’ compensation	$81	$84	$77	$80
Regulatory assets – workers’ compensation	$6	$10	$6	$10

Note H —– Other Material Contingencies

Manhattan Explosion and Fire

On March 12, 2014, two 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 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 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~~June 30, ~~2017,~~2018, 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. 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 June 30, 2018, the company had not accrued a liability related to the incident.

Other Contingencies

See "Other Regulatory Matters" in Note B and “Uncertain Tax Positions” in Note I.

Guarantees

Con Edison and its subsidiaries enter into various agreements providing financial or performance assurance primarily to third parties on behalf of their subsidiaries. Maximum amounts guaranteed by Con Edison totaled ~~$2,162~~$2,012 million and ~~$2,370~~$2,073 million at ~~September~~June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, respectively.

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A summary, by type and term, of Con Edison’s total guarantees at ~~September~~June 30, ~~2017~~2018 is as follows:


Guarantee Type	0 – 3 years	4 – 10 years	> 10 years		Total	0 – 3 years	4 – 10 years	> 10 years		Total
	(Millions of Dollars)					(Millions of Dollars)
Con Edison Transmission	$643	$404		$—	$1,047	$744	$404		$—	$1,148
Energy transactions	459	30	211		700	426	31	204		661
Renewable electric production projects	268	—	19		287	109	—	24		133
Other	128	—	—		128	70	—	—		70
Total	$1,498	$434	$230		$2,162	$1,349	$435	$228		$2,012

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 a 45.7 percent interest in NY Transco when it was formed in 2014. 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 the New York Independent System Operator's competitive bidding process. These other projects are subject to certain authorizations from the NYSPSC, the FERC and, as applicable, other federal, state and local agencies. Guarantee amount shown is for the maximum possible required amount of CET Electric’s contributions for these other projects as calculated based on the assumptions that the projects are completed at 175 percent of their 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. Also included within the table above ~~is a guarantee~~are guarantees for ~~$25~~$125 million from Con Edison on behalf of CET Gas in relation to a proposed gas transmission project in West Virginia and Virginia.

~~Table of Contents~~

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 —– Income Tax

Con Edison’s income tax expense decreased to ~~$270~~$38 million for the three months ended ~~September~~June 30, ~~2017~~2018 from ~~$314~~$102 million for the three months ended ~~September~~June 30, 2016. Con Edison's effective tax rate for the three months ended September 30, 2017 and 2016 was 37 percent and 39 percent, respectively. The decrease in Con Edison's effective tax rate is primarily due to lower state income taxes, offset in part by a decrease in tax benefits for plant-related flow through items.

2017. CECONY’s income tax expense ~~increased~~decreased to ~~$242~~$31 million for the three months ended ~~September~~June 30, ~~2017~~2018 from ~~$226~~$91 million for the three months ended ~~September~~June 30, ~~2016. CECONY's effective~~2017. The decrease in income tax expense for both Companies is due primarily to lower income before income tax expense and the lower corporate federal income tax rate of 21 percent in 2018 resulting from the enactment of the TCJA.

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~~June 30 ~~2017 and 2016 was 38 percent and 37 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 credits, offset in part by lower state income taxes.~~as follows:

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	Con Edison				CECONY
(% of Pre-tax income)	2018		2017		2018		2017
STATUTORY TAX RATE
Federal	21	%	35	%	21	%	35	%
Changes in computed taxes resulting from:
State income tax	5		3		4		3
Cost of removal	2		3		2		3
Other plant-related items	(1	)	(2	)	(1	)	(2	)
Renewable energy credits	(3	)	(2	)	—		—
Amortization of excess deferred federal income taxes	(7	)	—		(8	)	—
Other	—		—		(1	)	—
Effective tax rate	17	%	37	%	17	%	39	%

Con Edison’s income tax expense decreased to ~~$599~~$156 million for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 from ~~$602~~$330 million for the ~~nine~~six months ended ~~September~~June 30, 2016. Con Edison's effective tax rate for the nine months ended September 30, 2017 and 2016 was 37 percent. The effective tax rate remained unchanged as lower state income taxes were offset by a decrease in tax benefits for plant-related flow through items.

2017. CECONY’s income tax expense ~~increased~~decreased to ~~$551~~$150 million for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 from ~~$491~~$309 million for the ~~nine~~six months ended ~~September~~June 30, ~~2016. CECONY's effective~~2017. The decrease in income tax expense for both Companies is due primarily to lower income before income tax expense and the lower corporate federal income tax rate ~~for~~of 21 percent in 2018 resulting from 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.enactment of the TCJA.

~~Con Edison anticipates~~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 six months ended June 30 is as follows:



	Con Edison				CECONY
(% of Pre-tax income)	2018		2017		2018		2017
STATUTORY TAX RATE
Federal	21	%	35	%	21	%	35	%
Changes in computed taxes resulting from:
State income tax	5		4		5		4
Cost of removal	1		2		1		2
Other plant-related items	(1	)	(1	)	(1	)	(1	)
Change in deferred taxes	—		(1	)	—		—
Renewable energy credits	(2	)	(1	)	—		—
Amortization of excess deferred federal income taxes	(4	)	—		(4	)	—
Other	—		(1	)	—		(1	)
Effective tax rate	20	%	37	%	22	%	39	%

CECONY and O&R deferred as regulatory liabilities their estimated net benefits under the TCJA for the six months ended June 30, 2018. RECO deferred as a regulatory liability its estimated net benefits under the TCJA for the three months ended March 31, 2018. The net benefits include the revenue requirement impact of the reduction in the corporate federal ~~consolidated net operating loss~~income tax rate to 21 percent, the elimination for utilities of bonus depreciation and the amortization of excess deferred federal income taxes 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 Note B.

At December 31, 2017, ~~primarily due~~the Companies recorded provisional income tax amounts in its accounting for certain effects of the provisions of the TCJA as allowed under SEC Staff Accounting Bulletin 118 (SAB 118). SAB 118 allowed for a measurement period for companies to ~~bonus depreciation. Con Edison expects~~finalize the provisional amounts recorded as of December 31, 2017, not to ~~carryback a portion~~exceed one year. As of ~~its 2017 net operating loss~~June 30, 2018, the Companies have not yet finalized their assessment of the provisional amounts, and there were no adjustments recorded in the second quarter of 2018. The Companies expect to ~~recover $19 million~~complete their assessment and record any final adjustments to the provisional amounts by the fourth quarter 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.2018.

Uncertain Tax Positions

In March 2018, Con Edison received approval of its tax refunds by the Joint Committee on Taxation for tax years 2012 through 2015. The approval effectively settled approximately $3 million in uncertain federal tax positions. Federal tax returns for 2016 remain under examination.

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At ~~September~~June 30, ~~2017,~~2018, the estimated liability for uncertain tax positions for Con Edison was ~~$41~~$10 million ($214 million for CECONY). Con Edison reasonably expects to resolve within the next twelve months approximately ~~$35~~$5 million ($244 million, net of federal taxes) of ~~its uncertain~~various federal and state uncertainties due to the expected completion of ongoing tax ~~positions within~~examinations and expiration of statute of limitations, of which the ~~next twelve months, including $21 million ($15 million, net of federal taxes), which,~~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~~$2 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~~$10 million ($189 million, net of federal taxes).

~~Table of Contents~~

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~~six months ended ~~September~~June 30, ~~2017,~~2018, the Companies recognized an immaterial amount of interest expense and no penalties for uncertain tax positions in their consolidated income statements. At ~~September~~June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, the Companies recognized an immaterial amount of accrued interest on their consolidated balance sheets.

Note J —– 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~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 were as follows:


	For the Three Months Ended September 30,										For the Three Months Ended June 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	2018	2017	2018		2017		2018	2017	2018	2017
CECONY
Electric	$2,469	$2,557	$4		$5		$232	$217	$855	$841	$1,807	$1,817	$4				$243	$229	$318	$358
Gas	268	208	2		1		47	41	(12)	(28)	435	388	2				51	45	82	89
Steam	62	63	19		22		21	20	(43)	(47)	96	88	18				22		(18)	(24)
Consolidation adjustments	—	—	(25)		(28)		—	—	—	—	—	—	(24)				—	—	—	—
Total CECONY	$2,799	$2,828		$—		$—	$300	$278	$800	$766	$2,338	$2,293		$—		$—	$316	$296	$382	$423
O&R
Electric	$206	$213		$—		$—	$13	$12	$56	$55	$144	$148		$—		$—	$14	$13	$18
Gas	28	27	—		—		5		(11)	(7)	54	47	—		—		5	4	5	6
Total O&R	$234	$240		$—		$—	$18	$17	$45	$48	$198	$195		$—		$—	$19	$17	$23	$24
Clean Energy Businesses	$177	$350		$—	$(2)		$19	$11	$29	$125	$158	$146		$—		$—	$19	$18	$24	$18
Con Edison Transmission	1	—	—		—		—	—	(2)	(1)	1	—	—		—		—	—	(1)	(2)
Other (a)	—	(1)	—		2		—	(1)	1	2	1	(1)	—		—		—	1	(2)	1
Total Con Edison	$3,211	$3,417		$—		$—	$337	$305	$873	$940	$2,696	$2,633		$—		$—	$354	$332	$426	$464

Table of Contents


	For the Nine Months Ended September 30,										For the Six Months Ended June 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	2018	2017	2018		2017		2018	2017	2018	2017
CECONY
Electric	$6,079	$6,222	$12		$13		$690	$645	$1,477	$1,487	$3,536	$3,610	$8				$483	$458	$571	$678
Gas	1,421	1,113	5		4		137	118	362	273	1,276	1,153	4		3		100	90	404	385
Steam	448	406	55		65		64	62	52	39	410	386	37				43		112	100
Consolidation adjustments	—	—	(72)		(82)		—	—	—	—	—	—	(49)		(48)		—	—	—	—
Total CECONY	$7,948	$7,741		$—		$—	$891	$825	$1,891	$1,799	$5,222	$5,149		$—		$—	$626	$591	$1,087	$1,163
O&R
Electric	$495	$497		$—		$—	$38	$37	$83	$86	$293	$289		$—		$—	$28	$25	$26	$35
Gas	172	133	—		—		15	13	33	28	152	144	—		—		10		42	46
Total O&R	$667	$630		$—		$—	$53	$50	$116	$114	$445	$433		$—		$—	$38	$35	$68	$81
Clean Energy Businesses	$460	$998		$—	$7		$54	$30	$63	$184	391	283	—		—		38	36	33	34
Con Edison Transmission	1	—	—		—		—	—	(6)	(1)	2	—	—		—		—	—	(3)	(5)
Other (a)	(4)	(1)	—		(7)		—	—	2	1	—	(4)	—		—		—	—	(5)	2
Total Con Edison	$9,072	$9,368		$—		$—	$998	$905	$2,066	$2,097	$6,060	$5,861		$—		$—	$702	$662	$1,180	$1,275

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

~~Table of Contents~~

Note K —– Derivative Instruments and Hedging Activities

Con Edison’s subsidiaries 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. Derivatives are recognized on the consolidated balance sheet at fair value (see Note L), 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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The fair values of the Companies’ commodity derivatives including the offsetting of assets and liabilities on the consolidated balance sheet at ~~September~~June 30, ~~2017~~2018 and December 31, ~~2016~~2017 were:


(Millions of Dollars)	2017				2016				2018					2017
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)	$48	$(31)		$17	(b)	$83	$(51)		$32	(b)
Noncurrent	64	(61)	3		49	(43)	6		26	(18)		8		10	(4)		6
Total fair value of derivative assets	$141	$(128)	$13		$130	$(107)	$23		$74	$(49)		$25		$93	$(55)		$38
Fair value of derivative liabilities
Current	$(141)	$71	$(70)		$(138)	$61	$(77)		$(69)	$29		$(40)		$(67)	$50		$(17)
Noncurrent	(143)	60	(83)		(91)	52	(39)	(c)	(46)	18		(28)		(43)	5		(38)
Total fair value of derivative liabilities	$(284)	$131	$(153)		$(229)	$113	$(116)		$(115)	$47		$(68)		$(110)	$55		$(55)
Net fair value derivative assets/(liabilities)	$(143)	$3	$(140)	(b)	$(99)	$6	$(93)	(b) (c)	$(41)	$(2)		$(43)	(b)	$(17)		$—	$(17)	(b)
CECONY
Fair value of derivative assets
Current	$55	$(53)	$2	(b)	$52	$(45)	$7	(b)	$26	$(16)		$10	(b)	$39	$(15)		$24	(b)
Noncurrent	57	(55)	2		41	(35)	6		20	(15)		5		9	(4)		5
Total fair value of derivative assets	$112	$(108)	$4		$93	$(80)	$13		$46	$(31)		$15		$48	$(19)		$29
Fair value of derivative liabilities
Current	$(116)	$57	$(59)		$(111)	$45	$(66)		$(44)	$16		$(28)		$(26)	$14		$(12)
Noncurrent	(127)	54	(73)		(77)	44	(33)		(38)	15		(23)		(36)	4		(32)
Total fair value of derivative liabilities	$(243)	$111	$(132)		$(188)	$89	$(99)		$(82)	$31		$(51)		$(62)	$18		$(44)
Net fair value derivative assets/(liabilities)	$(131)	$3	$(128)	(b)	$(95)	$9	$(86)	(b)	$(36)		$—	$(36)	(b)	$(14)	$(1)		$(15)	(b)

(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~~June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, margin deposits for Con Edison ($56 million and $7$12 million, respectively) and CECONY ($56 million and $7$11 million, respectively) 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 for interest rate swap.~~

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. 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. Management believes that these derivative instruments represent economic hedges that mitigate exposure to fluctuations in commodity prices.

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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~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016:~~2017:


		For the Three Months Ended September 30,										For the Three Months Ended June 30,
		Con Edison					CECONY					Con Edison							CECONY
(Millions of Dollars)	Balance Sheet Location	2017			2016		2017		2016		Balance Sheet Location	2018			2017				2018		2017
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	$5				($21	)		$6		$(17)
Noncurrent	Deferred derivative gains	1			(2)		1		—		Deferred derivative gains	7			—				3		—
Total deferred gains/(losses)		$(3)			$(3)		$(2)		$(3)			$12			$(21)				$9		$(17)
Current	Deferred derivative losses	$(11)			$(19)		$(9)		$(18)		Deferred derivative losses	$44				$22			$42		$20
Current	Recoverable energy costs	(40)			(39)		(38)		(35)		Recoverable energy costs	(34)			(40)				(34)		(39)
Noncurrent	Deferred derivative losses	(12)			(17)		(8)		(14)		Deferred derivative losses	59			(9)				56		(8)
Total deferred gains/(losses)		$(63)			$(75)		$(55)		$(67)			$69			$(27)				$64		$(27)
Net deferred gains/(losses)		$(66)			$(78)		$(57)		$(70)			$81			$(48)				$73		$(44)
	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)		$—		$—	Purchased power expense		$—			$—				$—		$—
	Gas purchased for resale	(47)			(38)		—		—		Gas purchased for resale	(1)			(51)				—		—
	Non-utility revenue	5		(a)	(2)	(b)	—		—		Non-utility revenue	(3)		(a)	(8)			(b)	—		—
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	$(4)			$(59)					$—		$—


(a)	For the three months ended ~~September~~June 30, ~~2017,~~2018, Con Edison recorded an unrealized pre-tax ~~gain~~losses in non-utility operating revenue ($63 million).


(b)	For the three months ended ~~September~~June 30, ~~2016,~~2017, Con Edison recorded unrealized pre-tax losses in non-utility operating revenue ($~~2 million) and purchased power expense ($23~~7 million).


		For the Nine Months Ended September 30,										For the Six Months Ended June 30,
		Con Edison					CECONY					Con Edison							CECONY
(Millions of Dollars)	Balance Sheet Location	2017			2016		2017		2016		Balance Sheet Location	2018			2017				2018		2017
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	$(26)			$6		$(22)		$2		Deferred derivative gains	$(17)				($22	)		$(16)		$(19)
Noncurrent	Deferred derivative gains	(2)			(1)		(2)		(1)		Deferred derivative gains	5			(3)				3		(3)
Total deferred gains/(losses)		$(28)			$5		$(24)		$1			$(12)			$(25)				$(13)		$(22)
Current	Deferred derivative losses	$10			$19		$11		$16		Deferred derivative losses	$(4)				$20			$(2)		$21
Current	Recoverable energy costs	(125)			(163)		(116)		(148)		Recoverable energy costs	(9)			(85)				(8)		(78)
Noncurrent	Deferred derivative losses	(40)			(5)		(36)		(3)		Deferred derivative losses	8			(29)				7		(28)
Total deferred gains/(losses)		$(155)			$(149)		$(141)		$(135)			$(5)			$(94)				$(3)		$(85)
Net deferred gains/(losses)		$(183)			$(144)		$(165)		$(134)			$(17)			$(119)				$(16)		$(107)
	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		$—		$(106)	(b)		$—		$—	Purchased power expense		$—			$—				$—		$—
	Gas purchased for resale	(161)			(72)		—		—		Gas purchased for resale	(1)			(114)				—		—
	Non-utility revenue	11		(a)	15	(b)	—		—		Non-utility revenue	—		(a)	6			(b)	—		—
Total pre-tax gains/(losses) recognized in income	Total pre-tax gains/(losses) recognized in income	$(150)			$(163)			$—		$—	Total pre-tax gains/(losses) recognized in income	$(1)			$(108)					$—		$—


(a)	For the ~~nine~~six months ended ~~September~~June 30, ~~2017,~~2018, Con Edison recorded an unrealized pre-tax ~~gain~~losses in non-utility operating revenue ($23 million).


(b)	For the ~~nine~~six months ended ~~September~~June 30, ~~2016,~~2017, Con Edison recorded unrealized pre-tax ~~gains and~~ losses in non-utility operating revenue ($~~3 million loss) and purchased power expense ($11 million gain)~~4 million).

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The following table presents the hedged volume of Con Edison’s and CECONY’s derivative transactions at ~~September~~June 30, ~~2017:~~2018:


	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	35,139,532	8,356	184,203,665	1,680,000
CECONY	30,492,575	3,000	158,500,000	672,000	32,200,400	3,450	177,250,000	1,680,000


(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~~June 30, ~~2017,~~2018, Con Edison and CECONY had ~~$80~~$102 million and $8$14 million of credit exposure in connection with energy supply and hedging activities, net of collateral, respectively. Con Edison’s net credit exposure consisted of ~~$23~~$40 million with independent system operators, $26 million with investment-grade counterparties, ~~$23~~$22 million with non-investment grade/non-rated counterparties ~~$19 million with independent system operators~~ and ~~$15~~$14 million with commodity exchange brokers. CECONY’s net credit exposure consisted of $7 million with commodity exchange brokers and $1$7 million 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~~June 30, ~~2017:~~2018:


(Millions of Dollars)	Con Edison (a)		CECONY (a)		Con Edison (a)		CECONY (a)
Aggregate fair value – net liabilities	$148		$131		$60		$47
Collateral posted	61		56		68		67
Additional collateral (b) (downgrade one level from current ratings)	23		22		2		—
Additional collateral (b) (downgrade to below investment grade from current ratings)	101	(c)	88	(c)	29	(c)	15	(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 additional collateral of ~~$11~~$1 million at ~~September~~June 30, ~~2017.~~2018. 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~~June 30, ~~2017,~~2018, 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 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~~an asset of $1 million as of June 30, 2018 and an immaterial amount as of December 31, ~~2016~~2017 on Con Edison’s consolidated balance sheet.

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Note L —– 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 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.

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


	2017					2016						2018					2017
(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	$41	$12	$(26)	$31	$5	$77	$7		$(39)	$50
Interest rate swap (a)(b)(c)												—	1	—	—	1	—	—	—		—	—
Other (a)(b)(d)	271	118	—	—	389	222	111	—		—	333	308	116	—	—	424	283	120	—		—	403
Total assets	$277	$146	$2	$(18)	$407	$236	$144	$7		$(24)	$363	$312	$158	$12	$(26)	$456	$288	$197	$7		$(39)	$453
Derivative liabilities:
Commodity (a)(b)(c)	$2	$155	$22	$(26)	$153	$4	$144	$6		$(38)	$116	$5	$78	$16	$(31)	$68	$8	$93	$6		$(52)	$55
Interest Rate Swap (a)(b)(c)	—	—	—	—	—	—	1	—		—	1
Total liabilities	$2	$155	$22	$(26)	$153	$4	$145	$6		$(38)	$117
CECONY
Derivative assets:
Commodity (a)(b)(c)	$5	$12	$1	$(9)	$9	$10	$19	$1		$(10)	$20	$3	$28	$1	$(11)	$21	$3	$40	$4		$(7)	$40
Other (a)(b)(d)	248	113	—	—	361	200	106	—		—	306	286	110	—	—	396	260	114	—		—	374
Total assets	$253	$125	$1	$(9)	$370	$210	$125	$1		$(10)	$326	$289	$138	$1	$(11)	$417	$263	$154	$4		$(7)	$414
Derivative liabilities:
Commodity (a)(b)(c)	$1	$133	$15	$(17)	$132	$1	$124		$—	$(26)	$99	$4	$63	$1	$(17)	$51	$5	$57		$—	$(18)	$44

(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 no transfers between levels 1,~~Con Edison and CECONY had $1 million of net commodity derivative liabilities transferred from level 3 to level 2 ~~and 3 for~~during the ~~nine~~six months ended ~~September~~June 30, 2018 because of availability of observable market data due to the decrease in the terms of certain contracts from beyond three years as of December 31, 2017 to less than three years as of June 30, 2018. Con Edison and ~~for~~CECONY had $11 million and $10 million, respectively, of commodity derivative liabilities transferred from level 3 to level 2 during the year ended December 31, ~~2016.~~2017 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, 2017 to less than three years as of December 31, 2017.

(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~~June 30, ~~2017~~2018 and December 31, ~~2016,~~2017, 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. Under the Companies’ policies and procedures, multiple independent sources of information are obtained for forward price curves used to value commodity derivatives. Fair value and changes in fair value of commodity derivatives 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.

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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 June 30, 2018		Valuation Techniques	Unobservable Inputs	Range
	(Millions of Dollars)		Valuation Techniques	Unobservable Inputs	Range
Con Edison – Commodity
Electricity	$4		Discounted Cash Flow	Forward energy prices (a)	$17.38-$75.75 per MWh
	(5)		Discounted Cash Flow	Forward capacity prices (a)	$2.05-$10.16 per kW-month
Natural Gas	(4)		Discounted Cash Flow	Forward natural gas prices (a)	$0.33-$9.24 per Dt
Transmission Congestion Contracts/Financial Transmission Rights	1		Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$(3.00)-$4.80 per MWh
Total Con Edison—Commodity	$(4)
CECONY – Commodity
Electricity	$(1)		Discounted Cash Flow	Forward capacity prices (a)	$2.05-$9.26 per kW-month
Transmission Congestion Contracts	1		Discounted Cash Flow	Inter-zonal forward price curves adjusted for historical zonal losses (b)	$0.51-$3.63 per MWh
Total CECONY—Commodity		$—


(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~~June 30, ~~2017~~2018 and ~~2016~~2017 and classified as Level 3 in the fair value hierarchy:


	For the Three Months Ended September 30,					For the Three Months Ended June 30,
	�� Con Edison		CECONY			Con Edison		CECONY
(Millions of Dollars)	2017	2016	2017	2016		2018	2017	2018		2017
Beginning balance as of July 1,	$(10)	$5	$(6)	$2
Beginning balance as of April 1,						$3	$3	$2		$1
Included in earnings	7	(4)	1	—		(3)	2	1		1
Included in regulatory assets and liabilities	(13)	(5)	(8)	(3)		(1)	(11)	(2)		(7)
Sales	—	4	—	—
Settlements	(4)	1	(1)	1		(3)	(4)	(1)		(1)
Ending balance as of September 30,	$(20)	$1	$(14)		$—
Transfer out of level 3						—	—	—		—
Ending balance as of June 30,						$(4)	$(10)		$—	$(6)


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

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

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~~September 30, 2017 and 2016, respectively. For the nine months ended September 30, 2017 and 2016, the change in fair value relating to Level~~ 3 commodity derivative assets and liabilities is included in non-utility revenues ~~(immaterial for both periods)~~($4 million loss and immaterial) and purchased power costs ~~($2 million gain~~(immaterial and $2 million loss), respectively, on the consolidated income ~~statement, respectively.~~

statement.

Note M —– Variable Interest Entities

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

CECONY has an ongoing long-term electricity purchase agreement with Brooklyn Navy Yard Cogeneration Partners, LP, a potential variable interest entity (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~~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 the VIEs in which Con Edison Development has entered into as of ~~September~~June 30, ~~2017:~~2018:


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)	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	128	20	2014	Nevada	$174
Mesquite Solar 1	83	20	2013	Arizona	102	83	20	2013	Arizona	101
Copper Mountain Solar 2	75	25	2013	Nevada	83	75	25	2013	Nevada	80
California Solar	55	25	2012	California	64	55	25	2012	California	57
Broken Bow II	38	25	2014	Nebraska	44	38	25	2014	Nebraska	43
Texas Solar 4	32	25	2014	Texas	47	32	25	2014	Texas	19

(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 not the primary beneficiary since the power to direct the activities that most significantly impact the economics of the entities are shared equally between Con Edison Development and third parties. Con Edison’s ownership interest in Texas Solar 4 is 80 percent and is consolidated in the financial statements. Con Edison is the primary beneficiary since the power to direct the activities that most significantly impact the economics of Texas Solar 4 is held by Con Edison Development.

(b) Represents Con Edison Development’s ownership interest in the project.

(c) 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 and ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 that was not previously contractually required.

Note N —– 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, 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~~Accounting Standards Update (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.~~“Revenue from Contracts with Customers (Topic 606)." For income statement purposes, the pattern of expense recognition will ~~be dependent~~depend on whether transactions are designated as operating leases or finance leases. The amendments are effective, and the Companies plan to adopt the amendments, 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~~

Upon adoption of the amendments, the Companies expect to elect the following practical expedients: (1) for leases commenced prior to adoption date, the following three transition expedients that will allow the Companies to not reassess: (a) whether expired contracts contain leases; (b) the lease classification for expired leases and (c) the initial direct costs for existing ~~portfolio~~leases; (2) if elected for an underlying asset class, an expedient that will allow the Companies to not apply the recognition requirements to short-term leases and an expedient that will allow 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 will allow 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 ~~at implementation, for~~under the current lease standard. For leases currently classified as operating leases, upon adoption of the amendments, 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 through ASU 2017-01, “Business Combinations (Topic 805): Clarifying the Definition of a Business.” The amendments in this update clarify the definition of a business and provide guidance on evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. 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 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.~~their balance sheets right-of-use assets and lease liabilities. The ~~Company is in the process of evaluating~~Companies are continuing to evaluate the potential impact of the ~~new guidance~~amendments 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, and the Companies plan to adopt the amendments, for reporting periods beginning after December 15, 2018. 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 February 2018, the FASB issued amendments to the guidance for reporting comprehensive income through ASU 2018-02, “Income Statement-Reporting Comprehensive Income (Topic 220): Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income.” The amendments allow a reclassification from accumulated other comprehensive income to retained earnings for stranded tax effects resulting from the TCJA. For public entities, the amendments are effective, and ~~interim~~the Companies plan to adopt the amendments, for reporting periods ~~within those fiscal years. Early adoption is permitted.~~beginning after December 15, 2018. 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~~Second 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~~Second 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~~2017 (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~~period ended March 31, ~~2017 and June 30, 2017~~2018 (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.

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

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, the company decreased its five-year forecast of average annual growth of the peak gas demand in its service area at design conditions from approximately 2.3 percent (for 2017 to 2021) to 1.6 percent (for 2018 to 2022). The decrease reflects, among other things, that in rolling the forecast forward a year, another year of oil-to-gas conversions has been completed and fewer opportunities to convert remain.

Steam

CECONY operates the largest steam distribution system in the United States by producing and delivering approximately ~~19,500~~20,840 MMlb of steam annually to approximately ~~1,640~~1,600 customers in parts of Manhattan.

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, electric peak demand in O&R's service area was 1,410 MW (which occurred on June 13, 2017). At design conditions, electric peak demand in the company's service area would have been approximately 1,615 MW in 2017 compared to the company's forecast of 1,625 MW. The company’s five-year forecast of average annual growth of the electric peak demand in its service area at design conditions is flat for 2018 to 2022 (as compared to approximately (0.1) percent for 2017 to 2021).

Gas

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

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. In addition, Con Edison received $23 million in cash as a working capital adjustment in February 2017.~~

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

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retail customers.

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, 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 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~~that operates a gas storage ~~business~~facility in upstate New York. In addition, CET Gas owns ~~a 12.5 percent interest~~interests in two Mountain Valley Pipeline LLC a joint venture ~~developing~~projects: a ~~proposed 300 mile~~12.5 interest in a 300-mile gas transmission project being constructed in West Virginia and

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Virginia (Mountain Valley Pipeline) and a 6.375 percent interest in a proposed 70-mile gas pipeline system in Virginia and North Carolina (MVP Southgate). 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 June 30, 2018						For the Six Months Ended June 30, 2018						At June 30, 2018
(Millions of Dollars, except percentages)	Operating Revenues			Net Income			Operating Revenues			Net Income			Assets			Operating Revenues			Net Income			Operating Revenues			Net Income			Assets
CECONY	$2,799	87	%	$401	88	%	$7,948	88	%	$883	87	%	$41,647	85	%	$2,338	87	%	$149	79	%	$5,222	86	%	$538	87	%	$41,525	84	%
O&R	234	7		22	5		667	7		53	5		2,832	6		198	7		8	5		445	7		31	5		2,799	6
Total Utilities	3,033	94		423	93		8,615	95		936	92		44,479	91		2,536	94		157	84		5,667	93		569	92		44,324	90
Clean Energy Businesses ~~(a)~~	177	6		26	5		460	5		54	5		2,811	6		158	6		25	13		391	7		31	5		2,816	6
Con Edison Transmission	1	—		9	2		1	—		25	2		1,210	2		1	—		12	6		2	—		23	4		1,247	3
Other ~~(b)~~(a)	—	—		(1)	—		(4)	—		5	1		746	1		1	—		(6)	(3	)	—	—		(7)	(1	)	677	1
Total Con Edison	$3,211	100	%	$457	100	%	$9,072	100	%	$1,020	100	%	$49,246	100	%	$2,696	100	%	$188	100	%	$6,060	100	%	$616	100	%	$49,064	100	%

(a)

Net income 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 million and $1 million of net after-tax mark-to-market gains, respectively.


~~(b)~~	Other includes parent company and consolidation adjustments.

Results of Operations

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


	For the Three Months Ended September 30,							For the Nine Months Ended September 30,							For the Three Months Ended June 30,				For the Six Months Ended June 30,
	2017	2016	2017		2016			2017	2016	2017		2016			2018	2017	2018	2017	2018	2017	2018			2017
(Millions of Dollars, except per share amounts)	Net Income		Earnings per Share					Net Income		Earnings per Share					Net Income		Earnings per Share		Net Income		Earnings per Share
CECONY	$401	$388		$1.30		$1.27		$883	$859		$2.88		$2.87		$149	$143	$0.48	$0.47	$538	$482		$1.73			$1.58
O&R	22	27	0.07		0.09			53	55	0.18		0.18			8	5	0.02	0.01	31		0.10			0.10
Clean Energy Businesses (a)	26	78	0.08		0.26			54	120	0.18		0.40			25	21	0.08	0.07	31	28	0.10			0.09
Con Edison Transmission	9	10	0.03		0.03			25	11	0.08		0.04			12	9	0.04	0.03	23	16	0.07			0.05
Other (b)	(1)	(6)	—		(0.02		)	5	(6)	0.01		(0.02		)	(6)	(3)	(0.02)	(0.01)	(7)	6	(0.02		)	0.02
Con Edison (c)	$457	$497		$1.48		$1.63		$1,020	$1,039		$3.33		$3.47		$188	$175	$0.60	$0.57	$616	$563		$1.98			$1.84

(a)

Includes $4$(1) million or ~~$0.01~~$(0.01) a share and ~~$(15)~~$(4) million or ~~$(0.05)~~$(0.01) a share of net after-tax mark-to-market gains/(losses) for the three months ended ~~September~~June 30, ~~2017~~2018 and ~~2016,~~2017, respectively, and $1$(1) million or ~~$0.01~~$(0.01) a share and $5$(3) million or ~~$0.02~~$(0.01) a share of net after-tax mark-to-market gains/(losses) for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016,~~2017, 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~~three and six months ended ~~September~~June 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 investment for the three and nine months ended September 30, 2016 and a $5 million or $0.02 a share of net loss related to the impairment of a solar electric production investment for the nine months ended September 30, 2016.2017.

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(b)	Other includes parent company and consolidation adjustments.


(c)	Earnings per share on a diluted basis were ~~$1.48~~$0.60 a share and ~~$1.62~~$0.57 a share for the three months ended ~~September~~June 30, ~~2017~~2018 and ~~2016,~~2017, respectively, and ~~$3.31~~$1.98 a share and ~~$3.46~~$1.84 a share for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016,~~2017, respectively.

The Companies’ results of operations for the three and ~~nine~~six months ended ~~September~~June 30, ~~2017,~~2018, as compared with the ~~2016~~2017 periods, reflect changes in the Utilities' rate plans ~~and regulatory charges~~ and the impact of weather on steam revenues. ~~The new electric rate plan~~Con Edison's results of ~~CECONY includes changes~~operations also reflect lower income tax expense in the ~~timing~~2018 periods for the Clean Energy Businesses and Con Edison Transmission. The lower income tax expense for the Utilities in the 2018 periods was offset by the reduction in revenues resulting from the deferral for customers of ~~recognition~~estimated net benefits for the periods of ~~annual revenues between quarters.~~the federal Tax Cuts and Jobs Act of 2017 (TCJA). Operations and maintenance expenses for ~~CECONY~~the Utilities for the three and ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 primarily reflect ~~lower~~higher consultant costs ~~for pensions~~ and ~~other postretirement benefits.~~storm-related costs. 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.

The following ~~table presents~~tables present the estimated effect on earnings per share and net income for the three and ~~nine~~six months ended ~~September~~June 30, ~~2017 period~~2018 periods as compared with ~~2016 period,~~the 2017 periods, 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 June 30, 2018 vs. 2017
	Earnings per Share	Net Income (Millions of Dollars)
CECONY (a)
Changes in rate plans	$0.26	$79	Reflects primarily higher electric and gas net base revenues of $0.17 a share and $0.03 a share, respectively, and growth in the number of gas customers of $0.02 a share. Electric and gas base rates increased in January 2018 in accordance with the company's rate plans.
Weather impact on steam revenues	0.03	8	Steam revenues were $0.03 a share higher in the 2018 period due to the estimated impact of colder than normal April weather. Weather had an immaterial impact on steam revenues in the 2017 period.
Operations and maintenance expenses	(0.07)	(20)	Reflects higher consultant costs of $(0.02) a share, storm-related costs of $(0.01) a share, a higher reserve for uncollectibles of $(0.01) a share, healthcare costs of $(0.01) a share, and higher substation maintenance costs of $(0.01) a share.
Depreciation, property taxes and other tax matters	(0.10)	(29)	Reflects higher net property taxes of $(0.07) a share and depreciation and amortization expense of $(0.05) a share, offset in part by a New York State sales and use tax refund of $0.02 a share.
Other	(0.11)	(32)	Reflects primarily timing of the deferral for customers of estimated net benefits of the TCJA of $(0.09) a share, higher interest expense on long-term debt of $(0.03) a share, and the dilutive effect of Con Edison's stock issuances of $(0.01) a share.
Total CECONY	0.01	6
O&R (a)
Changes in rate plans	0.01	3	Reflects primarily higher gas net base revenues. Gas base rates increased in November 2017 in accordance with the company's gas rate plan.
Depreciation, property taxes and other tax matters	—	(1)
Other	0.00	1
Total O&R	0.01	3
Clean Energy Businesses
Operating revenues less energy costs	0.01	4	Reflects primarily higher renewable revenues, including engineering, procurement and construction services and an increase in renewable electric production projects in operation.
Operations and maintenance expenses	0.01	2	Reflects primarily a decrease of energy services costs.
Net interest expense	(0.01)	(3)
Other	—	1
Total Clean Energy Businesses	0.01	4
Con Edison Transmission	0.01	3	Reflects income from equity investments.
Other, including parent company expenses	(0.01)	(3)	Reflects lower state income tax benefits.
Total Reported (GAAP basis)	$0.03	$13

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 Six Months Ended June 30, 2018 vs. 2017
	Earnings per Share	Net Income (Millions of Dollars)
CECONY (a)
Changes in rate plans	$0.48	$149	Reflects primarily higher electric and gas net base revenues of $0.29 a share and $0.11 a share, respectively, and growth in the number of gas customers of $0.04 a share. Electric and gas base rates increased in January 2018 in accordance with the company's rate plans.
Weather impact on steam revenues	0.07	22	Steam revenues were $0.02 a share higher in the 2018 period due to the estimated impact of colder than normal April weather. Steam revenues were $(0.05) a share lower in the 2017 period due to the estimated impact of warmer than normal winter weather.
Operations and maintenance expenses	(0.07)	(23)	Reflects primarily higher consultant costs of $(0.03) a share and storm-related costs of $(0.03) a share.
Depreciation, property taxes and other tax matters	(0.19)	(58)	Reflects higher net property taxes of $(0.14) a share and depreciation and amortization expense of $(0.09) a share, offset in part by two New York State sales and use tax refunds of $0.04 a share.
Other	(0.14)	(34)	Reflects primarily timing of the deferral for customers of estimated net benefits of the TCJA of $(0.03) a share, higher interest expense on long-term debt of $(0.07) a share, and the dilutive effect of Con Edison's stock issuances of $(0.04) a share.
Total CECONY	0.15	56
O&R (a)
Changes in rate plans	0.03	10	Reflects primarily higher gas net base revenues. Gas base rates increased in November 2017 in accordance with the company's gas rate plan.
Operations and maintenance expenses	(0.02)	(7)	Reflects storm-related costs.
Depreciation, property taxes and other tax matters	(0.02)	(6)
Other	0.01	3
Total O&R	—	—
Clean Energy Businesses
Operating revenues less energy costs	0.21	63	Reflects primarily higher renewable revenues, including engineering, procurement and construction services and an increase in renewable electric production projects in operation.
Operations and maintenance expenses	(0.20)	(60)	Reflects primarily higher engineering, procurement and construction costs and energy services costs.
Depreciation	(0.01)	(2)
Net interest expense	(0.01)	(3)
Other	0.02	5
Total Clean Energy Businesses	0.01	3
Con Edison Transmission	0.02	7	Reflects income from equity investments.
Other, including parent company expenses	(0.04)	(13)	Reflects lower state income tax benefits.
Total Reported (GAAP basis)	$0.14	$53

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~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 were as follows:


	For the Three Months Ended September 30,		For the Nine Months Ended September 30,		For the Three Months Ended June 30,		For the Six Months Ended June 30,
(Millions of Dollars)	2017	2016	2017	2016	2018	2017	2018	2017
CECONY
Operations	$386	$381	$1,147	$1,109	$401	$377	$794	$761
Pensions and other postretirement benefits	51	87	152	261	18	15	35	29
Health care and other benefits	45	47	127	124	47	42	86	82
Regulatory fees and assessments (a)	142	135	355	361	94	102	203	213
Other	67	74	211	250	69	66	142	144
Total CECONY	691	724	1,992	2,105	629	602	1,260	1,229
O&R	80	77	236	220	74		154	145
Clean Energy Businesses(b)	79	40	174	124	52	56	176	94
Con Edison Transmission	3	1	7	1	2		5
Other ~~(b)~~(c)	(1)	(2)	(3)		(1)	(2)	(3)	(2)
Total other operations and maintenance expenses	$852	$840	$2,406	$2,447	$756	$732	$1,592	$1,471


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


(b)	The increase in operations and maintenance for the six months ended June 30, 2018 compared with the 2017 period is due primarily to higher 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~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 follows. For additional business segment financial information, see Note J to the ~~Third~~Second Quarter Financial Statements.

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Three Months Ended ~~September~~June 30, ~~2017~~2018 Compared with Three Months Ended ~~September~~June 30, ~~2016~~2017

The Companies’ results of operations in ~~2017~~2018 compared with ~~2016~~2017 were:


	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		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
Operating revenues	$(29)	(1.0	)%	$(6)	(2.5	)%	$(173)	(49.4	)%	$1	—	%	$1	Large		$(206)	(6.0	)%	$45	2.0	%	$3	1.5	%	$12	8.2	%	$1	—	%	$2	Large		$63	2.4	%
Purchased power	(95)	(19.2	)	(9)	(13.0	)	(234)	Large		—	—		—	—		(338)	(42.4	)	(20)	(5.5	)	(3)	(6.5	)	2	—		—	—		1	Large		(20)	(4.9	)
Fuel	1	3.4		—	—		—	—		—	—		—	—		1	3.4		—	—		—	—		—	—		—	—		—	—		—	—
Gas purchased for resale	24	70.6		2	25.0		8	20.5		—	—		—	—		34	42.0		34	40.5		5	35.7		6	11.8		—	—		—	—		45	30.2
Other operations and maintenance	(33)	(4.6	)	3	3.9		39	97.5		2	Large		1	(50.0	)	12	1.4		27	4.5		—	—		(4)	(7.1	)	—	—		1	50.0	%	24	3.3
Depreciation and amortization	22	7.9		1	5.9		8	72.7		—	—		1	Large		32	10.5		20	6.8		2	11.8		1	5.6		—	—		(1)	Large		22	6.6
Taxes, other than income taxes	18	3.6		—	—		(2)	(40.0	)	—	—		—	—		16	3.0		25	5.1		—	—		—	—		—	—		4	—		29	5.7
Gain on sale of retail electric supply business (2016)	—	—		—	—		(104)	Large		—	—		—	—		(104)	Large
Gain on sale of solar electric production project (2017)																			—	—		—	—		(1)	Large		—	—		—	—		(1)	Large
Operating income	34	4.4		(3)	(6.3	)	(96)	(76.8	)	(1)	Large		(1)	(50.0	)	(67)	(7.1	)	(41)	(9.7	)	(1)	(4.2	)	6	33.3		1	50.0		(3)	Large		(38)	(8.2	)
Other income less deductions	(2)	Large		(1)	Large		(9)	(33.3	)	1	5.0		1	Large		(10)	(20.4	)	—	—		—	—		2	14.3		2	10.0		—	—		4	57.1
Net interest expense	3	1.9		—	—		5	71.4		1	33.3		(2)	(40.0	)	7	3.9		13	8.4		—	—		4	40.0		—	—		—	—		17	9.4
Income before income tax expense	29	4.7		(4)	(10.0	)	(110)	(75.9	)	(1)	(6.3	)	2	50.0		(84)	(10.4	)	(54)	(23.1	)	(1)	(10.0	)	4	18.2		3	21.4		(3)	Large		(51)	(18.4	)
Income tax expense	16	7.1		1	7.7		(58)	(86.6	)	—	—		(3)	Large		(44)	(14.0	)	(60)	(65.9	)	(4)	(80.0	)	—	—		—	—		—	—		(64)	(62.7	)
Net income	$13	3.4	%	$(5)	(18.5	)%	$(52)	(66.7	)%	$(1)	(10.0	)%	$5	83.3	%	$(40)	(8.0	)%	$6	4.2	%	$3	60.0	%	$4	19.0	%	$3	33.3	%	$(3)	Large		$13	7.4	%


(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 June 30, 2018				For the Three Months Ended June 30, 2017
(Millions of Dollars)	Electric	Gas	Steam	2017 Total	Electric	Gas	Steam	2016 Total	2017-2016 Variation	Electric	Gas	Steam	2018 Total	Electric	Gas	Steam	2017 Total	2018-2017 Variation
Operating revenues	$2,469	$268	$62	$2,799	$2,557	$208	$63	$2,828	$(29)	$1,807	$435	$96	$2,338	$1,817	$388	$88	$2,293	$45
Purchased power	393	—	7	400	486	—	9	495	(95)	337	—	6	343	358	—	5	363	(20)
Fuel	24	—	6	30	21	—	8	29	1	26	—	12	38	27	—	11	38	—
Gas purchased for resale	—	58	—	58	—	34	—	34	24	—	118	—	118	—	84	—	84	34
Other operations and maintenance	547	104	40	691	578	102	44	724	(33)	483	106	40	629	457	101	44	602	27
Depreciation and amortization	232	47	21	300	217	41	20	278	22	243	51	22	316	229	45	22	296	20
Taxes, other than income taxes	418	71	31	520	414	59	29	502	18	400	78	34	512	388	69	30	487	25
Operating income	$855	$(12)	$(43)	$800	$841	$(28)	$(47)	$766	$34	$318	$82	$(18)	$382	$358	$89	$(24)	$423	$(41)

Electric

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


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	June 30, 2018	June 30, 2017	Variation
Operating revenues	$2,469	$2,557	$(88)	$1,807	$1,817	$(10)
Purchased power	393	486	(93)	337	358	(21)
Fuel	24	21	3	26	27	(1)
Other operations and maintenance	547	578	(31)	483	457	26
Depreciation and amortization	232	217	15	243	229	14
Taxes, other than income taxes	418	414	4	400	388	12
Electric operating income	$855	$841	$14	$318	$358	$(40)

CECONY’s electric sales and deliveries for the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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		June 30, 2018	June 30, 2017	Variation	Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential/Religious (b)	3,237	3,653	(416	)	(11.4	)%		$805	$883	$(78)	(8.8	)%	2,187	2,062	125	6.1	%		$601	$546	$55	10.1	%
Commercial/Industrial	2,570	2,749	(179	)	(6.5	)		534	551	(17)	(3.1	)	2,222	2,090	132	6.3			438	429	9	2.1
Retail choice customers	7,510	8,136	(626	)	(7.7	)		867	918	(51)	(5.6	)	5,966	5,934	32	0.5			563	593	(30)	(5.1	)
NYPA, Municipal Agency and other sales	2,705	2,764	(59	)	(2.1	)		207	204	3	1.5		2,403	2,330	73	3.1			152	146	6	4.1
Other operating revenues (c)	—	—	—		—			56	1	55	Large		—	—	—	—			53	103	(50)	(48.5	)
Total	16,022	17,302	(1,280	)	(7.4	)%	(d)	$2,469	$2,557	$(88)	(3.4	)%	12,778	12,416	362	2.9	%	(d)	$1,807	$1,817	$(10)	(0.6	)%


(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 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 0.3 percent in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

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Operating revenues decreased ~~$88~~$10 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($76 million) and lower purchased power expenses ($9321 million), offset in part by higher revenues from the electric rate plan ($2781 million).

Purchased power expenses decreased ~~$93~~$21 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to lower ~~purchased volumes ($66 million) and~~ unit ~~costs ($27 million).~~costs.

Fuel expenses ~~increased $3~~decreased $1 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to ~~higher unit costs ($6 million), offset by~~ lower purchased volumes from the company's electric generating ~~facilities ($3 million).~~facilities.

Other operations and maintenance expenses ~~decreased $31~~increased $26 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower pension and other postretirement benefits~~higher municipal infrastructure support costs ($389 million), consultant costs ($5 million), a higher reserve for uncollectibles ($4 million), healthcare costs ($3 million) and ~~environmental~~storm-related costs ($~~6 million), offset by higher surcharges for assessments and fees that are collected in revenues from customers ($6 million) and uncollectible expense ($5~~2 million).

Depreciation and amortization increased ~~$15~~$14 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased $4$12 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher property taxes ($1132 million), ~~offset by lower~~payroll taxes ($1 million) and state and local taxes ($51 million), offset in part by deferral of under-collected property taxes due to new property tax rates for fiscal year 2017-2018 ($14 million) and a sales and use tax refund ($8 million).

Gas

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


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	June 30, 2018	June 30, 2017	Variation
Operating revenues	$268	$208	$60	$435	$388	$47
Gas purchased for resale	58	34	24	118	84	34
Other operations and maintenance	104	102	2	106	101	5
Depreciation and amortization	47	41	6	51	45	6
Taxes, other than income taxes	71	59	12	78	69	9
Gas operating income	$(12)	$(28)	$16	$82	$89	$(7)

CECONY’s gas sales and deliveries, excluding off-system sales, for the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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		June 30, 2018	June 30, 2017	Variation		Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential	4,731	4,335	396		9.1	%		$104	$88	$16	18.2	%	11,973	10,303	1,670		16.2	%		$217	$171	$46	26.9	%
General	4,292	3,963	329		8.3			49	41	8	19.5		7,252	6,503	749		11.5			90	74	16	21.6
Firm transportation	8,766	8,305	461		5.6			67	53	14	26.4		17,627	14,771	2,856		19.3			118	102	16	15.7
Total firm sales and transportation	17,789	16,603	1,186		7.1		(b)	220	182	38	20.9		36,852	31,577	5,275		16.7		(b)	425	347	78	22.5
Interruptible sales (c)	2,108	1,664	444		26.7			8	4	4	Large		1,983	2,109	(126	)	(6.0	)		13	9	4	44.4
NYPA	10,148	12,800	(2,652	)	(20.7	)		1		—	—		9,900	10,493	(593	)	(5.7	)		1		—	—
Generation plants	24,068	35,745	(11,677	)	(32.7	)		7		—	—		14,418	14,476	(58	)	(0.4	)		6		—	—
Other	4,487	4,975	(488	)	(9.8	)		6		—	—		5,430	4,073	1,357		33.3			10	7	3	42.9
Other operating revenues (d)	—	—	—		—			26	8	18	Large		—	—	—		—			(20)	18	(38)	Large
Total	58,600	71,787	(13,187	)	(18.4	)%		$268	$208	$60	28.8	%	68,583	62,728	5,855		9.3	%		$435	$388	$47	12.1	%


(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~~9.9 percent in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period, reflecting primarily increased volumes attributable to the growth in the number of gas customers.


(c)	Includes ~~1,535~~849 thousands and ~~915~~1,217 thousands of Dt for the ~~2017~~2018 and ~~2016~~2017 periods, respectively, which are also reflected in firm transportation and other.


(d)	Other gas operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plans.

Operating revenues increased ~~$60~~$47 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher revenues from the gas rate plan and growth in the number of customers ($2928 million) and higher gas purchased for resale expense ($2434 million), offset in part by the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($21 million).

Gas purchased for resale increased ~~$24~~$34 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher unit costs ($2018 million) and purchased volumes ($416 million).

Other operations and maintenance expenses increased $2$5 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher ~~surcharges~~consultant costs ($1 million), municipal infrastructure support costs ($1 million) and a higher reserve for ~~assessments and fees that were collected in revenues from customers.~~uncollectibles ($1 million).

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

Taxes, other than income taxes increased ~~$12~~$9 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher property taxes ($610 million), and state and local taxes ($42 million), offset in part by deferral of under-collected property taxes due to new property tax rates for fiscal year 2017-2018 ($2 million) and ~~payroll taxes~~a sales and use tax refund ($12 million).

Steam

CECONY’s results of steam operations for the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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	June 30, 2018	June 30, 2017	Variation
Operating revenues	$62	$63	$(1)	$96	$88	$8
Purchased power	7	9	(2)	6	5	1
Fuel	6	8	(2)	12	11	1
Other operations and maintenance	40	44	(4)	40	44	(4)
Depreciation and amortization	21	20	1	22		—
Taxes, other than income taxes	31	29	2	34	30	4
Steam operating income	$(43)	$(47)	$4	$(18)	$(24)	$6

CECONY’s steam sales and deliveries for the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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		June 30, 2018	June 30, 2017	Variation	Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
General	13	10	3		30.0	%		$2			$—	—	%	92	58	34	58.6	%		$5	$4	$1	25.0	%
Apartment house	748	776	(28	)	(3.6	)		15		—		—		1,177	1,032	145	14.1			29	26	3	11.5
Annual power	2,439	2,950	(511	)	(17.3	)		42	49	(7)		(14.3	)	2,655	2,335	320	13.7			72	61	11	18.0
Other operating revenues (a)	—	—	—		—			3	(3)	6		Large		—	—	—	—			(10)	(3)	(7)	Large
Total	3,200	3,736	(536	)	(14.3	)%	(b)	$62	$63	$(1)		(1.6	)%	3,924	3,425	499	14.6	%	(b)	$96	$88	$8	9.1	%


(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 ~~8.6~~0.3 percent in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

~~Table of Contents~~

Operating revenues ~~decreased $1~~increased $8 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower~~the weather impact on revenues ($10 million), higher purchased power expenses ($21 million) and ~~lower~~ fuel expenses ($21 million), offset in part by the reduction in other operating revenues resulting from the deferral as a ~~property tax refund incentive~~regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($35 million).

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

Fuel expenses ~~decreased $2~~increased $1 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to ~~lower unit costs ($1 million) and~~higher purchased volumes from the company's steam generating ~~facilities ($1 million).~~facilities.

Other operations and maintenance expenses decreased $4 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to lower equipment maintenance expenses ($2 million) and municipal infrastructure support ~~costs.~~

~~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.~~costs ($2 million).

Taxes, other than income taxes increased $2$4 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher property ~~taxes.~~

~~Other Income (Deductions)~~

~~Other income (deductions) decreased $2 million~~taxes ($4 million), offset in ~~the three months ended September 30, 2017 compared with the 2016 period due primarily to~~part by a ~~decrease in investment~~sales and ~~other income.~~use tax refund ($1 million).

Net Interest Expense

Net interest expense increased $3$13 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher long-term debt balances in the ~~2017~~2018 period.

Table of Contents

Income Tax Expense

Income taxes ~~increased $16~~decreased $60 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~higher~~lower income before income tax expense ($11 million), a decrease in the corporate federal income tax ~~benefits for plant-related flow through items~~rate due to the TCJA ($733 million), ~~offset in part by~~ higher research and development tax credits ($21 million) and an increase in the amortization of excess deferred federal income taxes due to the TCJA ($15 million). CECONY 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 Second 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 June 30, 2018			For the Three Months Ended June 30, 2017
(Millions of Dollars)	Electric	Gas	2017 Total	Electric	Gas	2016 Total	2017-2016 Variation	Electric	Gas	2018 Total	Electric	Gas	2017 Total	2018-2017 Variation
Operating revenues	$206	$28	$234	$213	$27	$240	$(6)	$144	$54	$198	$148	$47	$195	$3
Purchased power	60	—	60	69	—	69	(9)	43	—	43	46	—	46	(3)
Gas purchased for resale	—	10	10	—	8	8	2	—	19	19	—	14	14	5
Other operations and maintenance	63	17	80	63	14	77	3	56	18	74	58	16	74	—
Depreciation and amortization	13	5	18	12	5	17	1	14	5	19	13	4	17	2
Taxes, other than income taxes	14	7	21	14	7	21	—	13	7	20	13	7	20	—
Operating income	$56	$(11)	$45	$55	$(7)	$48	$(3)	$18	$5	$23	$18	$6	$24	$(1)

Electric

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



	For the Three Months Ended
(Millions of Dollars)	June 30, 2018	June 30, 2017	Variation
Operating revenues	$144	$148	$(4)
Purchased power	43	46	(3)
Other operations and maintenance	56	58	(2)
Depreciation and amortization	14	13	1
Taxes, other than income taxes	13	13	—
Electric operating income	$18	$18		$—

4853

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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~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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		June 30, 2018	June 30, 2017	Variation		Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential/Religious (b)	500	585	(85	)	(14.5	)%		$105	$109	$(4)	(3.7	)%	376	359	17		4.7	%		$71	$69	$2	2.9	%
Commercial/Industrial	206	216	(10	)	(4.6	)		34	35	(1)	(2.9	)	192	177	15		8.5			27		—	—
Retail choice customers	818	925	(107	)	(11.6	)		64	70	(6)	(8.6	)	713	730	(17	)	(2.3	)		47	48	(1)	(2.1	)
Public authorities	31	31	—		—			3	2	1	50.0		43	24	19		79.2			3	2	1	50.0
Other operating revenues (c)	—	—	—		—			—	(3)	3	Large		—	—	—		—			(4)	2	(6)	Large
Total	1,555	1,757	(202	)	(11.5	)%	(d)	$206	$213	$(7)	(3.3	)%	1,324	1,290	34		2.6	%	(d)	$144	$148	$(4)	(2.7	)%


(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~~increased 3.2 percent in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

Operating revenues decreased $7$4 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to lower purchased power expenses ($93 million) and the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($2 million), offset in part by higher revenues from the New York electric rate plan ($31 million).

Purchased power expenses decreased $9$3 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to lower ~~purchased volumes ($10 million), offset by higher~~ unit costs.

Other operations and maintenance expenses decreased $2 million in the three months ended June 30, 2018 compared with the 2017 period due primarily to lower healthcare costs ($1 million) and lower surcharges for assessments and fees that are collected in revenues from customers ($1 million).

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

Gas

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


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	June 30, 2018	June 30, 2017	Variation
Operating revenues	$28	$27	$1	$54	$47	$7
Gas purchased for resale	10	8	2	19	14	5
Other operations and maintenance	17	14	3	18	16	2
Depreciation and amortization	5		—	5	4	1
Taxes, other than income taxes	7		—	7		—
Gas operating income	$(11)	$(7)	$(4)	$5	$6	$(1)

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O&R’s gas sales and deliveries, excluding off-system sales, for the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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		June 30, 2018	June 30, 2017	Variation		Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential	579	550	29		5.3	%		$11	$9	$2	22.2	%	1,435	1,092	343		31.4	%		$25	$19	$6	31.6	%
General	198	177	21		11.9			2		—	—		338	292	46		15.8			4		—	—
Firm transportation	898	884	14		1.6			8		—	—		1,623	1,457	166		11.4			14	13	1	7.7
Total firm sales and transportation	1,675	1,611	64		4.0		(b)	21	19	2	10.5		3,396	2,841	555		19.5		(b)	43	36	7	19.4
Interruptible sales	819	893	(74	)	(8.3	)		1	—	1	—		928	959	(31	)	(3.2	)		2	1		Large
Generation plants	5	3	2		66.7			—	—	—	—		—	1	(1	)	Large			—	—	—	—
Other	74	70	4		5.7			—	—	—	—		147	118	29		24.6			—	1	(1)	Large
Other gas revenues	—	—	—		—			6	8	(2)	(25.0	)	—	—	—		—			9		—	—
Total	2,573	2,577	(4	)	(0.2	)%		$28	$27	$1	3.7	%	4,471	3,919	552		14.1	%		$54	$47	$7	14.9	%


(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~~4.1 percent in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

Operating revenues increased $1$7 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher gas purchased for resale ($25 million)~~, offset by lower~~ and higher revenues from the New York gas rate plan ($3 million), offset in part by the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($1 million).

Gas purchased for resale increased $2$5 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher ~~purchased volumes ($3 million), offset by lower~~ unit ~~costs ($1 million).~~costs.

Other operations and maintenance expenses increased $3$2 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher pension costs.

~~Income Tax Expense~~

~~Income taxes~~Depreciation and amortization expenses increased $1 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher gas utility plant balances.

Income Tax Expense

Income taxes decreased $4 million in the ~~absence~~three months ended June 30, 2018 compared with the 2017 period due primarily to a decrease in ~~2017 of a~~the corporate federal income tax ~~benefit from a corporate-owned life insurance policy in 2016~~rate due to the TCJA ($21 million), ~~offset~~a decrease in ~~part by lower~~tax benefits for plant-related flow through items ($1 million) and an increase in the amortization of excess deferred federal income ~~before income tax expense~~taxes due to the TCJA ($1 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 Second Quarter Financial Statements.

Table of Contents

Clean Energy Businesses

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


	For the Three Months Ended			For the Three Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	June 30, 2018	June 30, 2017	Variation
Operating revenues	$177	$350	$(173)	$158	$146	$12
Purchased power	—	234	(234)	2	—	2
Gas purchased for resale	47	39	8	57	51	6
Other operations and maintenance	79	40	39	52	56	(4)
Depreciation and amortization	19	11	8	19	18	1
Taxes, other than income taxes	3	5	(2)	4		—
Gain on sale of retail electric supply business (2016)	—	(104)	104
Gain on sale of solar electric production project (2017)				—	1	(1)
Operating income	$29	$125	$(96)	$24	$18	$6

Operating revenues ~~decreased $173~~increased $12 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower electric retail~~higher renewable revenues ~~of $256 million~~($10 million), including revenues from ~~the sale of the retail electric supply business in September 2016. Renewable revenues increased $56 million due primarily to~~engineering, procurement and construction services and an increase in renewable electric production projects in ~~operation and revenues from the engineering, procurement and construction of Upton~~

~~Table of Contents~~

~~2 (see Note O to the Third Quarter Financial Statements). Energy services revenues increased $9 million.~~operation. Wholesale revenues increased ~~$10~~$6 million due to higher sales volumes. Energy services revenues decreased $8 million. Net mark-to-market values increased ~~$32~~$4 million.

Purchased power expenses increased $2 million in the three months ended June 30, 2018 compared with the 2017 period due primarily to costs relating 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).business.

Gas purchased for resale increased $8$6 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher purchased volumes.

Other operations and maintenance expenses ~~increased $39~~decreased $4 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~Upton 2 engineering, procurement and construction costs (see Note O to the Third Quarter Financial Statements) and an increase in~~a decrease of energy services costs.

Depreciation and amortization increased $8$1 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to an increase in solar electric production projects in operation during ~~2017.~~

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

G~~ain on sale of retail electric supply business was $104 million in the three months ended September 30, 2016 reflecting the sale of the Clean Energy Businesses' retail electric supply business.~~2018.

Other Income (Deductions)

Other income (deductions) ~~decreased $9~~increased $2 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~the gain related to the acquisition of a solar~~higher income from renewable electric production ~~investment in 2016.~~investments.

Net Interest Expense

Net interest expense increased $5$4 million in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to the reversal of interest on uncertain tax positions in the 2017 period and increased debt on ~~solar~~renewable electric production ~~projects.~~projects in the 2018 period.

Income Tax Expense

Income taxes ~~decreased $58 million~~remained flat in the three months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower~~a decrease in the corporate federal income tax rate due to the TCJA ($3 million), offset in part by higher income before income tax expense ($441 million) and higher state income taxes ($2 million).

Con Edison Transmission

Income Tax Expense

Income taxes remained flat in the three months ended June 30, 2018 compared with the 2017 period due primarily to the decrease in the corporate federal income tax rate due to the TCJA ($2 million), partially offset by higher ~~renewable energy~~income before income tax ~~credits~~expense ($1 million) and ~~the increase to deferred~~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~~Six Months Ended ~~September~~June 30, ~~2017~~2018 Compared with ~~Nine~~Six Months Ended ~~September~~June 30, ~~2016~~2017

The Companies’ results of operations in ~~2017~~2018 compared with ~~2016~~2017 were:


	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		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
Operating revenues	$207	2.7	%	$37	5.9	%	$(538)	(53.9	)%	$1	—	%	$(3)	Large		$(296)	(3.2	)%	$73	1.4	%	$12		2.8	%	$108	38.2	%	$2	—	%	$4		Large		$199	3.4	%
Purchased power	(106)	(8.7	)	(6)	(3.9	)	(679)	Large		—	—		(3)	Large		(794)	(38.8	)	(65)	(9.2	)	6		6.8		4	Large		—	—		4		Large		(51)	(6.4	)
Fuel	36	27.1		—	—		—	—		—	—		—	—		36	27.1		23	16.5		—		—		—	—		—	—		—		—		23	16.5
Gas purchased for resale	155	71.4		20	62.5		89	Large		—	—		—	—		264	82.5		77	24.5		6		14.3		19	16.7		—	—		—		—		102	21.7
Other operations and maintenance	(113)	(5.4	)	16	7.3		50	40.3		6	Large		—	—		(41)	(1.7	)	31	2.5		9		6.2		82	87.2		0	—		(1)		50.0		121	8.2
Depreciation and amortization	66	8.0		3	6.0		24	80.0		—	—		—	—		93	10.3		35	5.9		3		8.6		2	5.6		—	—		—		—		40	6.0
Taxes, other than income taxes	77	5.3		2	3.3		(4)	(25.0	)	—	—		(1)	Large		74	4.9		48	4.8		1		2.4		1	12.5		—	—		8		Large		58	5.5
Gain on sale of retail electric supply business (2016) and solar electric production project (2017)	—	—		—	—		(103)	Large		—	—		—	—		(103)	Large
Gain on sale of solar electric production project (2017)																			—	—		—		—		(1)	Large		—	—		—		—		(1)	Large
Operating income	92	5.1		2	1.8		(121)	(65.8	)	(5)	Large		1	Large		(31)	(1.5	)	(76)	(6.5	)	(13)		(16.0	)	(1)	(2.9	)	2	40.0		(7)		Large		(95)	(7.5	)
Other income less deductions	4	Large		(1)	Large		(2)	(5.7	)	37	Large		(1)	—		37	60.7		(1)	(1.5	)	—		—		3	20.0		5	12.8		(2)		—		5	22.7
Net interest expense	12	2.7		(1)	(3.6	)	11	47.8		8	Large		(2)	(18.2	)	28	5.4		26	8.5		1		5.6		4	18.2		2	28.6		(2	)	(28.6	)	31	8.6
Income before income tax expense	84	6.2		2	2.3		(134)	(68.4	)	24	Large		2	(20.0	)	(22)	(1.3	)	(103)	(13.0	)	(14)		(26.4	)	(2)	(7.4	)	5	18.5		(7)		Large		(121)	(13.5	)
Income tax expense	60	12.2		4	12.5		(68)	(89.5	)	10	Large		(9)	Large		(3)	(0.5	)	(159)	(51.5	)	(14)		(63.6	)	(5)	Large		(2)	(18.2	)	6		54.5	%	(174)	(52.7	)
Net income	$24	2.8	%	$(2)	(3.6	)%	$(66)	(55.0	)%	$14	Large		$11	Large		$(19)	(1.8	)%	$56	11.6	%		$—	—	%	$3	10.7	%	$7	43.8	%	$(13)		Large		$53	9.4	%


(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 Six Months Ended June 30, 2018				For the Six Months Ended June 30, 2017
(Millions of Dollars)	Electric	Gas	Steam	2017 Total	Electric	Gas	Steam	2016 Total	2017-2016 Variation	Electric	Gas	Steam	2018 Total	Electric	Gas	Steam	2017 Total	2018-2017 Variation
Operating revenues	$6,079	$1,421	$448	$7,948	$6,222	$1,113	$406	$7,741	$207	$3,536	$1,276	$410	$5,222	$3,610	$1,153	$386	$5,149	$73
Purchased power	1,084	—	26	1,110	1,191	—	25	1,216	(106)	626	—	19	645	691	—	19	710	(65)
Fuel	95	—	74	169	81	—	52	133	36	84	—	78	162	70	—	69	139	23
Gas purchased for resale	—	372	—	372	—	217	—	217	155	—	391	—	391	—	314	—	314	77
Other operations and maintenance	1,528	330	134	1,992	1,659	307	139	2,105	(113)	962	214	84	1,260	926	214	89	1,229	31
Depreciation and amortization	690	137	64	891	645	118	62	825	66	483	100	43	626	458	90	43	591	35
Taxes, other than income taxes	1,205	220	98	1,523	1,159	198	89	1,446	77	810	167	74	1,051	787	150	66	1,003	48
Operating income	$1,477	$362	$52	$1,891	$1,487	$273	$39	$1,799	$92	$571	$404	$112	$1,087	$678	$385	$100	$1,163	$(76)

Electric

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


	For the Nine Months Ended			For the Six Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	June 30, 2018	June 30, 2017	Variation
Operating revenues	$6,079	$6,222	$(143)	$3,536	$3,610	$(74)
Purchased power	1,084	1,191	(107)	626	691	(65)
Fuel	95	81	14	84	70	14
Other operations and maintenance	1,528	1,659	(131)	962	926	36
Depreciation and amortization	690	645	45	483	458	25
Taxes, other than income taxes	1,205	1,159	46	810	787	23
Electric operating income	$1,477	$1,487	$(10)	$571	$678	$(107)

CECONY’s electric sales and deliveries for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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 Six Months Ended						For the Six Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		June 30, 2018	June 30, 2017	Variation	Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential/Religious (b)	7,576	8,130	(554	)	(6.8	)%		$1,925	$2,017	$(92)	(4.6	)%	4,597	4,339	258	5.9	%		$1,225	$1,120	$105	9.4	%
Commercial/Industrial	6,965	7,220	(255	)	(3.5	)		1,393	1,381	12	0.9		4,637	4,395	242	5.5			890	859	31	3.6
Retail choice customers	19,748	20,404	(656	)	(3.2	)		2,092	2,114	(22)	(1.0	)	12,241	12,238	3	—			1,121	1,225	(104)	(8.5	)
NYPA, Municipal Agency and other sales	7,548	7,641	(93	)	(1.2	)		483	474	9	1.9		4,989	4,843	146	3.0			282	275	7	2.5
Other operating revenues (c)	—	—	—		—			186	236	(50)	(21.2	)	—	—	—	—			18	131	(113)	(86.3	)
Total	41,837	43,395	(1,558	)	(3.6	)%	(d)	$6,079	$6,222	$(143)	(2.3	)%	26,464	25,815	649	2.5	%	(d)	$3,536	$3,610	$(74)	(2.0	)%


(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 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~~increased 0.5 percent in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

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Operating revenues decreased ~~$143~~$74 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($151 million) and lower purchased power ~~costs~~expenses ($~~107~~65 million)~~. The lower revenues reflected the decline~~, offset in ~~surcharges for assessments and fees that were collected in~~part by higher revenues from ~~customers~~the electric rate plan ($13128 million).

Purchased power expenses decreased ~~$107~~$65 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to lower unit costs ($79 million), offset by higher purchased volumes ($~~95 million) and unit costs ($12~~14 million).

Fuel expenses increased $14 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher unit costs ($1218 million) ~~and~~, offset in part by lower purchased volumes from the company’s electric generating facilities ($24 million).

Other operations and maintenance expenses ~~decreased $131~~increased $36 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower~~higher storm-related costs ~~for pension and other postretirement benefits~~ ($~~114~~14 million), ~~surcharges for assessments and fees that are collected in revenues from customers~~consultant costs ($1312 million), ~~environmental~~municipal infrastructure costs ($178 million) and ~~stock based compensation~~a higher reserve for uncollectibles ($68 million), offset in part by ~~higher costs for municipal infrastructure support~~lower stock-based compensation ($2017 million).

Depreciation and amortization increased ~~$45~~$25 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher electric utility plant balances.

Taxes, other than income taxes increased ~~$46~~$23 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher property taxes ($4364 million), offset in part by deferral of under-collected property taxes due to new property tax rates for fiscal year 2017-2018 ($28 million) and ~~the absence in 2017 of~~ a ~~favorable state audit settlement in 2016~~sales and use tax refund ($~~5 million), offset by lower state and local taxes ($4~~14 million).

Gas

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


	For the Nine Months Ended			For the Six Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	June 30, 2018	June 30, 2017	Variation
Operating revenues	$1,421	$1,113	$308	$1,276	$1,153	$123
Gas purchased for resale	372	217	155	391	314	77
Other operations and maintenance	330	307	23	214		—
Depreciation and amortization	137	118	19	100	90	10
Taxes, other than income taxes	220	198	22	167	150	17
Gas operating income	$362	$273	$89	$404	$385	$19

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CECONY’s gas sales and deliveries, excluding off-system sales, for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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 Six Months Ended							For the Six Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		June 30, 2018	June 30, 2017	Variation		Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential	39,814	35,565	4,249		11.9	%		$613	$506	$107	21.1	%	39,272	34,910	4,362		12.5	%		$610	$509	$101	19.8	%
General	23,427	20,962	2,465		11.8			255	200	55	27.5		21,693	19,306	2,387		12.4			244	206	38	18.4
Firm transportation	53,952	51,333	2,619		5.1			390	332	58	17.5		52,417	45,186	7,231		16.0			378	325	53	16.3
Total firm sales and transportation	117,193	107,860	9,333		8.7		(b)	1,258	1,038	220	21.2		113,382	99,402	13,980		14.1		(b)	1,232	1,040	192	18.5
Interruptible sales (c)	6,526	7,587	(1,061	)	(14.0	)		30	29	1	3.4		3,474	4,417	(943	)	(21.3	)		24	22	2	9.1
NYPA	30,233	31,970	(1,737	)	(5.4	)		2	2	—	—		14,713	20,085	(5,372	)	(26.7	)		1	1	—	—
Generation plants	48,989	70,895	(21,906	)	(30.9	)		19	19	—	—		26,821	24,921	1,900		7.6			12	11	1	9.1
Other	16,756	16,442	314		1.9			24	25	(1)	(4.0	)	11,446	12,269	(823	)	(6.7	)		18	18	—	—
Other operating revenues (d)	—	—	—		—			88	—	88	—		—	—	—		—			(11)	61	(72)	Large
Total	219,697	234,754	(15,057	)	(6.4	)%		$1,421	$1,113	$308	27.7	%	169,836	161,094	8,742		5.4	%		$1,276	$1,153	$123	10.7	%


(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~~6.2 percent in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period, reflecting primarily increased volumes attributable to the growth in the number of gas customers.


(c)	Includes ~~3,563~~1,117 thousands and ~~3,940~~2,027 thousands of Dt for the ~~2017~~2018 and ~~2016~~2017 periods, respectively, which are also reflected in firm transportation and other.


(d)	Other gas operating revenues generally reflect changes in regulatory assets and liabilities in accordance with the company’s rate plans.

Operating revenues increased ~~$308~~$123 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher revenues from the gas rate plan and growth in the number of customers ($~~133~~74 million) and ~~increased~~higher gas purchased for resale expense ($~~155~~77 million), offset in part by the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($41 million).

Gas purchased for resale increased ~~$155~~$77 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher purchased volumes ($39 million) and unit costs ($~~151 million) and purchased volumes ($4 million).~~

~~Other operations and maintenance~~ expenses increased $23 million in the nine months ended September 30, 2017 compared with the 2016 period due primarily to higher pension and other postretirement benefits costs ($7 million), health and life expenses ($5 million), surcharges for assessments and fees that are collected in revenues from customers ($3 million) and costs for maintenance of gas mains ($238 million).

Depreciation and amortization increased ~~$19~~$10 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher gas utility plant balances.

Taxes, other than income taxes increased ~~$22~~$17 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher property taxes ($1220 million), and state and local taxes ($64 million), offset in part by deferral of under-collected property taxes due to new property tax rates for fiscal year 2017-2018 ($4 million) and ~~payroll taxes~~a sales and use tax refund ($3 million).

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Steam

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


	For the Nine Months Ended			For the Six Months Ended
(Millions of Dollars)	September 30, 2017	September 30, 2016	Variation	June 30, 2018	June 30, 2017	Variation
Operating revenues	$448	$406	$42	$410	$386	$24
Purchased power	26	25	1	19		—
Fuel	74	52	22	78	69	9
Other operations and maintenance	134	139	(5)	84	89	(5)
Depreciation and amortization	64	62	2	43		—
Taxes, other than income taxes	98	89	9	74	66	8
Steam operating income	$52	$39	$13	$112	$100	$12

CECONY’s steam sales and deliveries for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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 Six Months Ended						For the Six Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		June 30, 2018	June 30, 2017	Variation	Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
General	364	345	19		5.5	%		$20	$18	$2	11.1	%	430	351	79	22.5	%		$21	$18	$3	16.7	%
Apartment house	4,248	4,251	(3	)	(0.1	)		119	107	12	11.2		3,889	3,500	389	11.1			113	103	10	9.7
Annual power	10,074	10,640	(566	)	(5.3	)		300	284	16	5.6		8,602	7,634	968	12.7			288	258	30	11.6
Other operating revenues (a)	—	—	—		—			9	(3)	12	Large		—	—	—	—			(12)	7	(19)	Large
Total	14,686	15,236	(550	)	(3.6	)%	(b)	$448	$406	$42	10.3	%	12,921	11,485	1,436	12.5	%	(b)	$410	$386	$24	6.2	%


(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~~0.1 percent in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

Operating revenues increased ~~$42~~$24 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~higher fuel expenses ($22 million),~~ the weather impact on revenues ($630 million) and fuel expenses ($9 million), ~~lower~~offset in part by the reduction in other operating revenues resulting from the deferral as a regulatory ~~reserve related~~liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to ~~steam earnings sharing~~the Second Quarter Financial Statements) ($~~7 million), a property tax refund incentive ($3 million), and higher purchased power costs ($1~~10 million).

~~Purchased power~~Fuel expenses increased $1$9 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher unit costs ($5 million)~~, offset by lower purchased volumes ($4 million).~~

~~Fuel~~ ~~expenses increased $22 million in the nine months ended September 30, 2017 compared with the 2016 period due to higher unit costs ($23 million), offset by lower~~ and purchased volumes from the company’s steam generating facilities ($14 million).

Other operations and maintenance expenses decreased $5 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to lower ~~equipment maintenance expenses.~~

~~Depreciation~~municipal infrastructure support costs ($2 million), surcharges for assessments and ~~amortization~~ ~~increased $2 million~~fees that are collected in ~~the nine months ended September 30, 2017 compared with the 2016 period due primarily to higher steam utility plant balances.~~revenues from customers ($2 million) and stock-based compensation ($1 million).

Taxes, other than income taxes increased $9$8 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher property taxes ($78 million), offset in part by a sales and ~~state and local taxes~~use tax refund ($1 million).

Net Interest Expense

Net interest expense increased ~~$12~~$26 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher long-term debt balances in the ~~2017~~2018 period.

Income Tax Expense

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Income ~~Tax Expense~~

~~Income~~ taxes ~~increased $60~~decreased $159 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~higher~~lower income before income tax expense ($3321 million), a decrease in the corporate federal income tax ~~benefits for plant-related flow through items~~rate due to the TCJA ($~~27 million), lower research and development tax credits ($10 million) and a higher reserve for injuries and damages ($9 million), offset in part by lower state income taxes ($7~~111 million), higher research and development tax credits ~~included in Con Edison's filing of its 2016 consolidated federal tax return in September 2017 ($5 million), a decrease in bad debt expense~~ ($2 million) and an increase in the amortization of excess deferred federal income taxes due to the TCJA ($29 million). CECONY deferred as a ~~decrease~~regulatory liability its estimated net benefits for the 2018 period under the TCJA. See “Other Regulatory Matters” in ~~uncertain tax positions ($1 million).~~Note B to the Second Quarter Financial Statements.

O&R


	For the Nine Months Ended September 30, 2017			For the Nine Months Ended September 30, 2016				For the Six Months Ended June 30, 2018			For the Six Months Ended June 30, 2017
(Millions of Dollars)	Electric	Gas	2017 Total	Electric	Gas	2016 Total	2017-2016 Variation	Electric	Gas	2018 Total	Electric	Gas	2017 Total	2018-2017 Variation
Operating revenues	$495	$172	$667	$497	$133	$630	$37	$293	$152	$445	$289	$144	$433	$12
Purchased power	148	—	148	154	—	154	(6)	94	—	94	88	—	88	6
Gas purchased for resale	—	52	52	—	32	32	20	—	48	48	—	42	42	6
Other operations and maintenance	185	51	236	180	40	220	16	118	36	154	114	31	145	9
Depreciation and amortization	38	15	53	37	13	50	3	28	10	38	25	10	35	3
Taxes, other than income taxes	41	21	62	40	20	60	2	27	16	43	27	15	42	1
Operating income	$83	$33	$116	$86	$28	$114	$2	$26	$42	$68	$35	$46	$81	$(13)

Electric

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

For the Nine Months Ended

(Millions of Dollars) September 30, 2017 September 30, 2016 Variation
Operating revenues $495 $497 $(2)
Purchased power 148 154 (6)
Other operations and maintenance 185 180 5
Depreciation and amortization 38 37 1
Taxes, other than income taxes 41 40 1
Electric operating income $83 $86 $(3)

~~Table of Contents~~



	For the Six Months Ended
(Millions of Dollars)	June 30, 2018	June 30, 2017	Variation
Operating revenues	$293	$289	$4
Purchased power	94	88	6
Other operations and maintenance	118	114	4
Depreciation and amortization	28	25	3
Taxes, other than income taxes	27	27	—
Electric operating income	$26	$35	$(9)

O&R’s electric sales and deliveries for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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 Six Months Ended							For the Six Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		June 30, 2018	June 30, 2017	Variation		Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential/Religious (b)	1,208	1,307	(99	)	(7.6	)%		$242	$240	$2	0.8	%	753	708	45		6.4	%		$145	$137	$8	5.8	%
Commercial/Industrial	574	607	(33	)	(5.4	)		88	89	(1)	(1.1	)	390	368	22		6.0			57	54	3	5.6
Retail choice customers	2,255	2,434	(179	)	(7.4	)		155	166	(11)	(6.6	)	1,410	1,437	(27	)	(1.9	)		91		—	—
Public authorities	79	76	3		3.9			7	6	1	16.7		72	48	24		50.0			6	4	2	50.0
Other operating revenues (c)	—	—	—		—			3	(4)	7	Large		—	—	—		—			(6)	3	(9)	Large
Total	4,116	4,424	(308	)	(7.0	)%	(d)	$495	$497	$(2)	(0.4	)%	2,625	2,561	64		2.5	%	(d)	$293	$289	$4	1.4	%


(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~~increased 0.4 percent in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

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Operating revenues ~~decreased $2~~increased $4 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower~~higher purchased power ~~expense~~expenses ($6 million) and ~~lower revenues from rental property ($1 million), offset by~~ higher revenues from the New York electric rate plan ($62 million), offset in part by the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($5 million).

Purchased power expenses ~~decreased~~increased $6 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher unit costs ($7 million), offset by lower purchased volumes ~~($5 million) and unit costs~~ ($1 million).

Other operations and maintenance expenses increased $5$4 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~operating~~higher storm-related 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).~~2018.

Depreciation and amortization increased $1$3 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period iswere as follows:

For the Nine Months Ended

(Millions of Dollars) September 30, 2017 September 30, 2016 Variation
Operating revenues $172 $133 $39
Gas purchased for resale 52 32 20
Other operations and maintenance 51 40 11
Depreciation and amortization 15 13 2
Taxes, other than income taxes 21 20 1
Gas operating income $33 $28 $5

~~Table of Contents~~



	For the Six Months Ended
(Millions of Dollars)	June 30, 2018	June 30, 2017	Variation
Operating revenues	$152	$144	$8
Gas purchased for resale	48	42	6
Other operations and maintenance	36	31	5
Depreciation and amortization	10	10	—
Taxes, other than income taxes	16	15	1
Gas operating income	$42	$46	$(4)

O&R’s gas sales and deliveries, excluding off-system sales, for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 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 Six Months Ended							For the Six Months Ended
Description	September 30, 2017	September 30, 2016	Variation		Percent Variation			September 30, 2017	September 30, 2016	Variation	Percent Variation		June 30, 2018	June 30, 2017	Variation		Percent Variation			June 30, 2018	June 30, 2017	Variation	Percent Variation
Residential	5,556	5,266	290		5.5	%		$79	$55	$24	43.6	%	5,898	4,977	921		18.5	%		$83	$68	$15	22.1	%
General	1,447	1,224	223		18.2			16	10	6	60.0		1,300	1,250	50		4.0			15	14	1	7.1
Firm transportation	6,543	7,188	(645	)	(9.0	)		50	49	1	2.0		6,072	5,645	427		7.6			49	42	7	16.7
Total firm sales and transportation	13,546	13,678	(132	)	(1.0	)	(b)	145	114	31	27.2		13,270	11,872	1,398		11.8		(b)	147	124	23	18.5
Interruptible sales	2,966	3,020	(54	)	(1.8	)		5	2	3	Large		2,071	2,147	(76	)	(3.5	)		4		—	—
Generation plants	6	15	(9	)	(60.0	)		—	—	—	—		—	2	(2	)	Large			—	—	—	—
Other	589	583	6		1.0			1	—	1	—		573	515	58		11.3			1		—	—
Other gas revenues	—	—	—		—			21	17	4	23.5	%	—	—	—		—			—	15	(15)	Large
Total	17,107	17,296	(189	)	(1.1	)%		$172	$133	$39	29.3	%	15,914	14,536	1,378		9.5	%		$152	$144	$8	5.6	%


(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~~2.1 percent in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with ~~2016~~2017 period.

Operating revenues increased ~~$39~~$8 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to an increase in gas purchased for resale ($206 million) and higher revenues from the New York gas rate plan ($1412 million), offset in part by the reduction in other operating revenues resulting from the deferral as a regulatory liability of estimated net benefits for the 2018 period under the TCJA (see “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements) ($9 million).

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Gas purchased for resale increased ~~$20~~$6 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher purchased ~~volumes ($12 million) and unit costs ($8 million).~~volumes.

Other operations and maintenance expenses increased ~~$11~~$5 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher pension costs.

~~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~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to higher property taxes.

Income Tax Expense

Income taxes ~~increased $4~~decreased $14 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~higher~~lower income before income tax expense ($13 million), a decrease in the corporate federal income tax rate due to the TCJA ($7 million), a decrease in tax benefits for plant-related flow through items ($1 million) and an increase in the ~~absence in 2017~~amortization of ~~a tax benefit from a corporate-owned life insurance policy in 2016~~excess deferred federal income taxes due to the TCJA ($2 million).

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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 Second Quarter Financial Statements.

Clean Energy Businesses

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

For the Nine Months Ended

(Millions of Dollars) September 30, 2017 September 30, 2016 Variation
Operating revenues $460 $998 $(538)
Purchased power (3) 676 (679)
Gas purchased for resale 161 72 89
Other operations and maintenance 174 124 50
Depreciation and amortization 54 30 24
Taxes, other than income taxes 12 16 (4)
Gain on sale of retail electric supply business (2016) and solar electric production project (2017) (a) (1) (104) 103
Operating income $63 $184 $(121)

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



	For the Six Months Ended
(Millions of Dollars)	June 30, 2018	June 30, 2017	Variation
Operating revenues	$391	$283	$108
Purchased power	2	(2)	4
Gas purchased for resale	133	114	19
Other operations and maintenance	176	94	82
Depreciation and amortization	38	36	2
Taxes, other than income taxes	9	8	1
Gain on sale of solar electric production project (2017)	—	1	(1)
Operating income	$33	$34	$(1)

Operating revenues ~~decreased $538~~increased $108 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower electric retail~~higher renewable revenues ~~of $781 million~~($102 million), including revenues from ~~the sale of the retail electric supply business in September 2016. Renewable revenues increased $112 million due primarily to~~engineering, procurement and construction services and an increase in renewable electric production projects in ~~operation and revenues from the engineering, procurement and construction of Upton 2 (see Note O to the Third Quarter Financial Statements).~~operation. Energy services revenues ~~increased $21~~decreased $11 million. Wholesale revenues increased ~~$105~~$15 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.~~increased $2 million.

Purchased power expenses ~~decreased $679~~increased $4 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~lower electric~~ costs ~~due~~relating to the sale of the retail electric supply ~~business in September 2016 ($689 million) offset by changes in mark-to-market values ($11 million).~~business.

Gas purchased for resale increased ~~$89~~$19 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to higher purchased volumes.

Other operations and maintenance expenses increased ~~$50~~$82 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to ~~Upton 2~~increased 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 ~~$24~~$2 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to an increase in solar electric production projects in operation during ~~2017.~~2018.

Taxes, other than income taxes ~~decreased $4~~increased $1 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due to ~~lower~~ gross receipts tax true-ups in the 2017 period 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~~increased $3 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~earnings~~higher income 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~~renewable electric production ~~projects.~~

investments.

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~~Income Tax Expense~~

Income taxes decreased $68 million in the nine months ended September 30, 2017 compared with the 2016 period due primarily to lower income before income tax expense ($54 million), higher renewable energy tax credits ($1 million) and the increase to deferred 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 ($13 million).

~~Con Edison Transmission~~

~~Other operations and maintenance~~ ~~increased $6 million in the nine months ended September 30, 2017 compared with the 2016 period due primarily to CET having no employees or other direct costs until January 1, 2017.~~

Net Interest Expense

Net interest expense increased $8$4 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to ~~a new debt issuance in 2016.~~

~~Other Income (Deductions)~~

~~Other income (deductions) increased $37 million~~the reversal of interest on uncertain tax positions in the ~~nine months ended September 30,~~ 2017 ~~compared with~~period and increased debt on solar electric production projects in the ~~2016 period due primarily to earnings from equity investments in Stagecoach Gas Services, LLC, substantially all of which were made in June 2016.~~2018 period.

Income Tax Expense

Income taxes ~~increased $10~~decreased $5 million in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period due primarily to a decrease in the corporate federal income tax rate due to the TCJA ($4 million) and a $2 million income tax benefit in 2018 related to the extension of energy efficiency programs, offset in part by the absence of the reversal of uncertain tax positions in 2017 ($1 million).

Con Edison Transmission

Income Tax Expense

Income taxes decreased $2 million in the six months ended June 30, 2018 compared with the 2017 period due primarily to the decrease in the corporate federal income tax rate due to the TCJA ($4 million), offset in part by higher income before income tax ~~expense.~~expense ($1 million) and higher state income taxes ($1 million).

Other

For Con Edison, “Other” includes ~~parent company and consolidation adjustments.~~the increase in income tax expense resulting from the absence of a deferred state income tax adjustment recorded in 2017 ($7 million), offset in part by lower income before income tax expense ($1 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 Companies’ cash and temporary cash investments resulting from operating, investing and financing activities for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 are summarized as follows:


	For the Nine Months Ended September 30,						For the Six Months Ended June 30,
	Con Edison			CECONY			Con Edison			CECONY
(Millions of Dollars)	2017	2016	Variation	2017	2016	Variation	2018	2017	Variation	2018	2017	Variation
Operating activities	$2,227	$2,336	$(109)	$1,790	$2,017	$(227)	$1,040	$1,574	$(534)	$655	$1,234	$(579)
Investing activities	(2,572)	(3,717)	1,145	(2,197)	(1,943)	(254)	(1,866)	(1,731)	(135)	(1,627)	(1,460)	(167)
Financing activities	(362)	583	(945)	(278)	(891)	613	903	169	734	1,071	291	780
Net change for the period	(707)	(798)	91	(685)	(817)	132	77	12	65	99	65	34
Balance at beginning of period	776	944	(168)	702	843	(141)	844	830	14	730	704	26
Balance at end of period	$69	$146	$(77)	$17	$26	$(9)	$921	$842	$79	$829	$769	$60
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)

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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, the reduction of the corporate tax rate to 21 percent under the TCJA is expected to result in decreased cash flows from operating activities as and when the rates the Utilities charge their customers are adjusted to reflect the reduction. See “Other Regulatory Matters” in Note B to the Second 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~~six months ended ~~September~~June 30, ~~2017~~2018 for Con Edison and CECONY were ~~$109~~$534 million and ~~$227~~$579 million lower, respectively, than in the ~~2016~~2017 period. The change in net cash flows for Con Edison and CECONY reflects primarily cash payments of MTA power reliability costs ($100 million and $100 million, respectively) and Puerto Rico related restoration costs ($97 million and $92 million, respectively), storm restoration costs ($192 million and $126 million, respectively), higher ~~cash paid for~~pension and retiree benefit contributions ($85 million and $86 million, respectively) and lower income tax refunds received, net of income taxes paid ($33 million and $141 million, respectively), offset in part by the cash impact of the Utilities’ estimated net benefits in the ~~2017~~2018 period ~~as compared with~~under the ~~2016 period of $110~~TCJA ($217 million and ~~$226~~$202 million, ~~respectively, net of refunds received. The income tax refund received~~respectively). See “Other Changes in ~~2016 reflected the extension of bonus depreciation in late 2015, resulting in a refund of the 2015 estimated federal tax payments.~~Assets and Liabilities,” below.

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, 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~~$135 million ~~lower~~ and ~~$254~~$167 million higher, respectively, for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period. The change for Con Edison reflects primarily ~~lower~~higher utility construction expenditures ($177 million), new investments in electric and gas transmission projects ($~~1,011~~35 million) and ~~renewable electric production projects~~proceeds from the sale of assets in 2017 ($~~240~~34 million), ~~and~~offset in part by a decrease in non-utility construction expenditures ($~~148 million), offset in part by lower proceeds from sale of assets ($216~~116 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 ($88 million).~~expenditures.

Cash Flows from Financing Activities

Net cash flows from financing activities for Con Edison and CECONY were ~~$945~~$734 million ~~lower~~ and ~~$613~~$780 million higher, respectively, in the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 compared with the ~~2016~~2017 period.

In June 2018, CECONY issued $640 million aggregate principal amount of debentures, due 2021, at a variable interest rate of 0.40 percent above three-month LIBOR and called for redemption on various dates in July and August ~~2017, Con Edison~~2018 the $636 million of CECONY’s tax-exempt debt for which the interest rates were to be determined pursuant to periodic auctions.

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In May 2018, CECONY issued ~~4.1~~$700 million ~~common shares resulting in~~aggregate principal amount of 4.50 percent debentures, due 2058, and $300 million aggregate principal amount of 3.80 percent debentures, due 2028, the net proceeds from the sale of ~~$343 million, after issuance expenses, that~~which were ~~invested by Con Edison in its subsidiaries, principally CECONY and the Clean Energy Businesses, for funding of their construction expenditures~~used to repay short-term borrowings and for other general corporate purposes.

In April 2018, CECONY redeemed at maturity $600 million of 5.85 percent 10-year debentures.

In June 2017, CECONY issued $500 million aggregate principal amount of 3.875 percent debentures, due 2047, 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 issued $400 million aggregate principal amount of 2.00 percent debentures, due 2020, and prepaid the June 2016 $400 million variable rate term loan that was to mature in 2018.

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

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In June 2016, CECONY issued $550 million aggregate principal amount of 3.85 percent debentures, due 2046, the net proceeds from the sale of which were used to repay short-term borrowings and for other general corporate purposes. In September 2016, CECONY redeemed at maturity $400 million of 5.50 percent 10-year debentures.

In June 2016, a Con Edison Solutions subsidiary borrowed $2 million pursuant to a loan agreement with a New Jersey utility. The borrowing matures 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 million aggregate principal amount of 2.00 percent debentures, due 2021, the net proceeds from the sale of which were used in connection with 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.

~~In May 2016, a Con Edison Development subsidiary issued $95 million aggregate principal amount of 4.07 percent senior notes, due 2036, secured by the company's California Holdings 3 solar project.~~

~~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~~renewable electric production project.

Con Edison’s cash flows from financing for ~~nine~~the six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 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 million and $77 million, respectively.~~$50 million.

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


	2017		2016		2018		2017
(Millions of Dollars, except Weighted Average Yield)	Outstanding at September 30,	Daily average	Outstanding at September 30,	Daily average	Outstanding at June 30,	Daily average	Outstanding at June 30,	Daily average
Con Edison	$356	$645	$601	$813	$869	$722	$1,036	$699
CECONY	$147	$323	$480	$385	$550	$354	$750	$330
Weighted average yield	1.3	1.1	0.7	0.6	2.2	2.1	1.3	1.0

Capital Requirements and Resources

Contractual Obligations

Con ~~Edison has decreased its estimates for capital requirements for the retirement of~~Edison’s material obligations to make payments pursuant to contracts totaled $47,113 million and $43,822 million at June 30, 2018 and December 31, 2017, respectively. The increase at June 30, 2018 is due primarily to an increase in long-term ~~securities for 2018~~debt, including interest ($2,351 million). See ”Cash Flows from ~~$1,688 million to $1,288 million. The decrease reflects the $400 million prepayment of a variable rate term loan that was to mature in 2018. See Note C to the Third Quarter Financial Statements.~~Financing Activities,” above.

Capital Resources

For each of the Companies, the ratio of earnings to fixed charges (Securities and Exchange Commission (SEC) basis) for the ~~nine~~six months ended ~~September~~June 30, ~~2017~~2018 and ~~2016~~2017 and the twelve months ended December 31, ~~2016~~2017 was:


	Ratio of Earnings to Fixed Charges			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	Six Months Ended June 30, 2018^(a)	For the Six Months Ended June 30, 2017	For the Twelve Months Ended December 31, 2017
Con Edison	3.8	4.0	3.6	2.7	3.3	3.6
CECONY	3.9	3.8	3.6	3.0	3.4	3.7

(a) The ratios are calculated on a pre-tax basis, and as a result the ratios shown for the six months ended June 30, 2018 do not reflect the reduction in income tax expense under the TCJA but do reflect the reduction in other operating revenues for Con Edison and CECONY of $217 million and $202 million, respectively, resulting from the deferral as a regulatory liability of the estimated net benefits under the TCJA. See “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements.

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


	Common Equity Ratio (Percent of total capitalization)		Common Equity Ratio (Percent of total capitalization)
	September 30, 2017	December 31, 2016	June 30, 2018	December 31, 2017
Con Edison	50.8	49.3	50.7	51.1
CECONY	50.9	49.5	50.1	50.8

Other Changes in Assets and Liabilities

The following table shows changes in certain assets and liabilities at ~~September~~June 30, ~~2017,~~2018, compared with December 31, ~~2016.~~2017.


	Con Edison	CECONY	Con Edison	CECONY
(Millions of Dollars)	2017 vs. 2016 Variation	2017 vs. 2016 Variation	2018 vs. 2017 Variation	2018 vs. 2017 Variation
Assets
Prepayments	$433	$398
Non-utility property, less accumulated depreciation	204	—
Other receivables, less allowance for uncollectible accounts			$104	$74
Regulatory asset - Unrecognized pension and other postretirement costs	(248)	(254)	(359)	(337)
Regulatory asset - MTA Power Reliability costs			100	100
Regulatory asset - Deferred storm costs			44	—
Other deferred charges and noncurrent assets			4	(16)
Liabilities
System benefit charge			$94	$86
Pension and retiree benefits	$(404)	$(394)	(484)	(475)
Deferred income taxes and unamortized investment tax credits	539	610	215	207
System benefit charge	194	175
Regulatory liability - TCJA net benefits			217	202
Other deferred credits and noncurrent liabilities			(23)	(17)

~~Prepayments~~

~~The increase in prepayments for Con Edison and CECONY reflects primarily the portion allocable to the 2017 fourth quarter of CECONY's July 2017 payment of its New York City semi-annual property taxes.~~

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

The increase in non-utility property, less 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).

Regulatory Asset for Unrecognized Pension and Other Postretirement Costs and Liability for Pension and Retiree Benefits

The decrease in the regulatory asset for unrecognized pension and other postretirement costs and the liability for pension and retiree benefits reflects the final actuarial valuation, as measured at December 31, 2017, of the pension and other retiree benefit plans ~~as measured at December 31, 2016,~~ in accordance with the accounting rules for retirement benefits. The change in the regulatory asset also reflects the ~~year’s~~year's amortization of accounting costs. The change in the liability for pension and retiree benefits reflects in part contributions to the plans made by the Utilities in ~~2017.~~2018. See Notes E and F to the ~~Third~~Second Quarter Financial Statements.

~~Deferred Income Taxes and Unamortized Investment Tax Credits~~Regulatory Asset for MTA Power Reliability Costs

The increase in the ~~liability~~regulatory asset for MTA power reliability deferral reflects costs incurred and deferred ~~income taxes~~as a regulatory asset in the 2018 period. See “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements.

Other Receivables and ~~unamortized investment tax credits~~Other Deferred Charges and Noncurrent Assets

The increase in other receivables for Con Edison and CECONY reflects ~~primarily bonus depreciation in 2017, partially offset~~costs related to aid provided by the ~~increase~~Utilities in ~~deferred income tax assets associated with~~ the ~~federal tax attribute carryforwards~~restoration of power in Puerto Rico in the aftermath of September 2017 hurricanes that have been billed to the appropriate authorities. As of June 30, 2018, Con Edison and CECONY other receivables' balances related to such costs were $100 million and $94 million, respectively. The decrease in other deferred charges and noncurrent assets for Con Edison and CECONY reflects such costs that have already been billed.

Regulatory Liability for TCJA Net Benefits

The changes in the regulatory liability for TCJA net ~~operating loss and general business tax credits. See Note I~~benefits were due to the ~~Third~~Utilities’ deferral of estimated net benefits under the TCJA for the six months ended June 30, 2018. See “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements.

Regulatory Asset for Deferred Storm Costs and Other Deferred Credits and Noncurrent Liabilities

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The changes in the regulatory asset for deferred storm costs and other deferred credits and noncurrent liabilities were due primarily to storm-related costs that were deferred as a regulatory asset or charged against a storm reserve. See “Other Regulatory Matters” in Note B to the Second Quarter Financial Statements.

System Benefit Charge

The increase in the liability for the system benefit charge reflects amounts collected by the Utilities from their customers that will be required to be paid to NYSERDA.

Deferred Income Taxes and Unamortized Investment Tax Credits

The increase in deferred income taxes and unamortized investment tax credits reflects primarily accelerated tax depreciation and repair deductions.

Off-Balance Sheet Arrangements

None of the Companies’ 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,~~July 2018, the NYSPSC issued an order adopting an offshore wind renewable energy standard. NYSERDA is to conduct offshore wind project solicitations in 2018 and 2019 for 800 MW in total and purchase offshore wind renewable energy credits (ORECs) from developers under 20 to 25 year contracts. Load serving entities, such as CECONY and O&R, will be required to purchase ORECs from NYSERDA beginning in 2025 when projects are first expected to begin operation.

In July 2018, the NYSPSC issued an order that ~~changes the way distributed~~authorizes CECONY to expand its energy ~~resources are compensated and begins to phase out net energy metering. In New York, net energy metering compensates kilowatt-hours exported~~efficiency programs for gas customers. Other smart solutions proposed for natural gas customers, which CECONY addressed in its September 2017 petition to the ~~electric distribution system at~~NYSPSC, are expected to be further considered by 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.NYSPSC.

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

Environmental Matters

In May 2017, a transformer failure at a CECONY substation discharged thousands of gallons of transformer oil into the soil. Some of the transformer oil, which contained small amounts of polychlorinated biphenyls (PCBs), leaked into the East River. The company, the U.S. Coast Guard, the New York State Department of Environmental Conservation and other agencies responded to 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 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 protection of, the environment.

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~~In 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~~lines and repaired. Monitoring 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~~being conducted to evaluate whether any further action is necessary. In 2017, the other utility sued the marina owner, whose pier had collapsed on the transmission lines, seeking, among other things, recovery of its response and repair costs. In February 2018, the marina owner filed claims against both the other utility and CECONY seeking recovery of its alleged costs associated with this matter (including an interim demand for approximately $18.4 million). In April 2018, the other utility responded to the marina owner’s counterclaims and filed cross-claims against CECONY. In May 2018, the other utility also filed a complaint with FERC in which it requested that FERC order CECONY to cooperate with the other utility to remove all of the dielectric fluid from the transmission lines and remove the lines. In June 2018, CECONY responded in opposition to this FERC filing by the other utility and filed counter-claims against the other utility in the court action. CECONY expects that, consistent with the cost allocation provisions of ~~their~~its prior arrangements with the other utility for the transmission lines, the ~~costs to respond to the incident~~response and repair costs incurred by CECONY, the ~~line,~~other utility and the U.S. Coast Guard, 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~~that CECONY's share is not ~~expect that its ultimate share of the costs~~reasonably likely to ~~respond to the discharge and repair the transmission line will~~ have a material adverse effect on its financial ~~condition,~~position, results of ~~operation~~operations or liquidity.

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

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Con Edison Development

The following table provides information about the ~~renewable electric production~~ projects ~~Con Edison Development owned~~ the company has in operation and/or in construction

at ~~September~~June 30, ~~2017:~~2018:


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)	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	Solar	18	(d)	2011	New Jersey
Flemington Solar	Solar	8	(d)	2011	New Jersey	Solar	8	(d)	2011	New Jersey
Frenchtown I, II and III	Solar	14	(d)	2011-13	New Jersey	Solar	14	(d)	2011-13	New Jersey
PA Solar	Solar	10		2012	Pennsylvania	Solar	10	(d)	2012	Pennsylvania
California Solar 2 (e)	Solar	80	20	2014-16	California	Solar	80	20	2014-16	California
Oak Tree Wind	Wind	20		2014	South Dakota	Wind	20		2014	South Dakota
Texas Solar 3	Solar	6	25	2015	Texas	Solar	6	25	2015	Texas
Texas Solar 5 (e)	Solar	95	25	2015	Texas	Solar	95	25	2015	Texas
Campbell County Wind	Wind	95	30	2015	South Dakota	Wind	95	30	2015	South Dakota
Texas Solar 7 (e)	Solar	106	25	2016	Texas	Solar	106	25	2016	Texas
California Solar 3 (e)	Solar	110	20	2016	California	Solar	110	20	2016	California
Adams Wind (e)	Wind	23	7	2016	Minnesota	Wind	23	7	2016	Minnesota
Valley View (e)	Wind	10	14	2016	Minnesota	Wind	10	14	2016	Minnesota
Coram (e)	Wind	102	16	2016	California	Wind	102	16	2016	California
Upton County Solar (e)	Solar	158	25	2017	Texas	Solar	158	25	2017	Texas
Panoche Valley (partial)						Solar	62	20	2017	California
Big Timber						Wind	25	25	2018	Montana
Projects of less than 5 MW	Solar / Wind	25	Various	Various	Various	Solar / Wind	30	Various		Various
Jointly owned projects (e) (f)
California Solar	Solar	55	25	2012-13	California	Solar	55	25	2012-13	California
Mesquite Solar 1	Solar	83	20	2013	Arizona	Solar	83	20	2013	Arizona
Copper Mountain Solar 2	Solar	75	25	2013-15	Nevada	Solar	75	25	2013-15	Nevada
Copper Mountain Solar 3	Solar	128	20	2014-15	Nevada	Solar	128	20	2014-15	Nevada
Broken Bow II	Wind	38	25	2014	Nebraska	Wind	38	25	2014	Nebraska
Texas Solar 4	Solar	32	25	2014	Texas	Solar	32	25	2014	Texas
Total MW (AC) in Operation		1,291					1,383
Panoche Valley	Solar	240	20	2018	California
Panoche Valley (partial)						Solar	78	20	2018	California
Wistaria Solar						Solar	100	20	2018	California
Aurora County Wind						Wind	20		2018	South Dakota
Brule County Wind						Wind	20		2018	South Dakota
Total MW (AC) in Construction		240					218
Total MW (AC), All Projects		1,531					1,601

(a) Represents Con Edison Development’s ownership interest in the project.

(b) Represents PPA contractual term or remaining term from Con Edison Development’s date of acquisition.

(d) ~~Have~~ Solar Renewable Energy Credit hedges are in place, in lieu of PPAs, ~~out to 2020.~~through 2022.

(e) Project has been pledged ~~to secure financing~~as security for ~~the project.~~debt financing.

(f) All of the jointly-owned projects are 50 percent owned, except for Texas Solar 4 (which is 80 percent owned). See Note M to the ~~Third~~Second

Quarter Financial Statements.

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

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	Millions of kWh Generated										Millions of kWh Generated
	For the Three Months Ended					For the Nine Months Ended					For the Three Months Ended					For the Six Months Ended
Description	September 30, 2017	September 30, 2016	Variation	Percent Variation		September 30, 2017	September 30, 2016	Variation	Percent Variation		June 30, 2018	June 30, 2017	Variation	Percent Variation		June 30, 2018	June 30, 2017	Variation	Percent Variation
Renewable electric production projects
Solar	668	458	210	45.9	%	1,679	1,215	464	38.2	%	804	612	192	31.4	%	1,335	1,011	324	32.0	%
Wind	217	137	80	58.4	%	734	464	270	58.2	%	296	279	17	6.1	%	530	517	13	2.5	%
Total	885	595	290	48.7	%	2,413	1,679	734	43.7	%	1,100	891	209	23.5	%	1,865	1,528	337	22.1	%

Con Edison Transmission

CET Electric

In June 2018, the NYISO management committee supported the NYISO Staff recommendation to the NYISO Board of Directors to select two projects that were submitted under the NYISO’s FERC-approved public policy planning process by developers other than NY Transco. The NYISO Board is expected to make its final decision after engaging in additional review. CET Electric owns a 45.7 percent interest in NY Transco.

CET Gas

Certain federal and state regulatory approvals for the Mountain Valley Pipeline are being challenged and, as a result, construction has been delayed on portions of the project. In July 2018, Mountain Valley Pipeline LLC indicated that the project has an estimated total cost of $3,500 million to $3,700 million and is targeted to be fully in-service by the end of the first quarter of 2019. CET Gas owns a 12.5 percent interest in the Mountain Valley Pipeline.

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 manage interest rate risk through the issuance of mostly fixed-rate debt with varying maturities and through opportunistic refinancing of debt. Con Edison and CECONY estimate that at ~~September~~June 30, ~~2017,~~2018, a 10 percent increase in interest rates applicable to its variable rate debt would result in an increase in annual interest expense of $2$6 million. Under CECONY’s current electric, gas 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 K to the ~~Third~~Second Quarter Financial Statements.

Con Edison estimates that, as of ~~September~~June 30, ~~2017,~~2018, a 10 percent decline in market prices would result in a decline in fair value of ~~$66~~$79 million for the derivative instruments used by the Utilities to hedge purchases of electricity and gas, of which ~~$60~~$71 million is for CECONY and $6$8 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.

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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~~six months ended ~~September~~June 30, ~~2017~~2018 and the year ended December 31, ~~2016,~~2017, respectively, was as follows:

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

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

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 53 to 63 percent equities and 35 to 49 percent fixed income and other securities. At ~~September~~June 30, ~~2017,~~2018, the pension plan investments consisted of 58 percent equity and 42 percent fixed income and other securities.

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 concerning potential liabilities arising from the Companies’ material contingencies, see "Other Regulatory Matters" in Note B and Notes G and H to the ~~Third~~Second 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 "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 ~~10.1.1~~4.1	~~Amendment~~ First Supplemental Indenture, dated as of August 1, 2009, between Con Edison and The Bank of New York Mellon (formerly known as The Bank of New York (successor as trustee to ~~the Consolidated Edison Retirement Plan.~~
JPMorgan Chase Bank, N.A. (formerly known as JPMorgan Chase Bank))), as Trustee. (Incorporated by reference to Exhibit ~~10.1.2~~	~~Amendment~~4.2 to ~~the Consolidated Edison Retirement Plan.~~Con Edison’s Registration Statement No. 333-161018.)
Exhibit 12.1	Statement of computation of Con Edison’s ratio of earnings to fixed charges for the ~~nine-month~~six-month periods ended ~~September~~June 30, ~~2017~~2018 and ~~2016,~~2017, and the 12-month period ended December 31, ~~2016.~~2017.
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.
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~~4.2.1	~~CECONY Supplemental Medical Benefits.~~Form of CECONY’s 3.80% Debentures, Series 2018 A. (Incorporated by reference to Exhibit 4.1 to CECONY’s Current Report on Form 8-K, dated May 7, 2018 (File No. 1-1217).).
Exhibit 4.2.2	Form of CECONY’s 4.50% Debentures, Series 2018 B. (Incorporated by reference to Exhibit 4.2 to CECONY’s Current Report on Form 8-K, dated May 7, 2018 (File No. 1-1217).).
Exhibit 4.2.3	Form of CECONY’s Floating Rate Debentures, Series 2018 C. (Incorporated by reference to Exhibit 4 to CECONY’s Current Report on Form 8-K, dated June 21, 2018 (File No. 1-1217).).
Exhibit 12.2	Statement of computation of CECONY’s ratio of earnings to fixed charges for the ~~nine-month~~six-month periods ended ~~September~~June 30, ~~2017~~2018 and ~~2016,~~2017, and the 12-month period ended December 31, ~~2016.~~2017.
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.
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~~August 2, ~~2017~~2018	By	/s/ Robert Hoglund
		Robert Hoglund Senior Vice President, Chief Financial Officer and Duly Authorized Officer

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	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)