Regulatory Matters (Tables)

12 Months Ended

Dec. 31, 2017

Regulated Operations [Abstract]

Summary of Utilities Rate Plans

RECO
Effective period	August 2014 – February 2017	March 2017 (a)
Base rate changes	Yr. 1 – $13.0 million	Yr. 1 – $1.7 million
Amortization to income of net regulatory (assets) and liabilities	$0.4 million over three years and $(25.6) million of deferred storm costs over four years	$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.	Current rate recovery of purchased power costs.
Cost reconciliations	None	None
Average rate base	$172.2 million	Yr. 1 – $178.7 million
Weighted average cost of capital (after-tax)	7.83 percent	7.47 percent
Authorized return on common equity	9.75 percent	9.6 percent
Actual return on common equity	Yr. 1 – 9.2 percent Yr. 2 – 8.7 percent	(c)
Cost of long-term debt	5.89 percent	5.37 percent
Common equity ratio	50 percent	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.

The following tables contain a summary of the Utilities’ rate plans:

CECONY – Electric
Effective period	January 2014 – December 2016	January 2017 – December 2019 (b)
Base rate changes	Yr. 1 – $(76.2) million (a) Yr. 2 – $124.0 million (a) Yr. 3 – None	Yr. 1 – $195 million (c) Yr. 2 – $155 million (c) Yr. 3 – $155 million (c)
Amortizations to income of net regulatory (assets) and liabilities	Yr. 1 and 2 – $(37) million (d) Yr. 3 – $123 million (d)	Yr. 1 – $84 million Yr. 2 – $83 million Yr. 3 – $69 million
Other revenue sources	Retention of $90 million of annual transmission congestion revenues.	Retention of $75 million of annual transmission congestion revenues. Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $28 million Yr. 2 – $47 million Yr. 3 – $64 million In 2017, the company recorded $13 million of earnings adjustment mechanism incentives for energy efficiency. The company also achieved other incentives of $5 million that, pursuant to the rate plan, will be recorded ratably in earnings from 2018 to 2020.
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred for customer benefit $146 million, $98 million and $101 million of revenues, respectively.	Continuation of reconciliation of actual to authorized electric delivery revenues. In 2017, the company deferred $45 million for customer benefits.
Recoverable energy costs (e)	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties (up to $400 million annually) if certain performance targets are not met. In 2014, the company recorded a $5 million negative revenue adjustment. In 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $376 million Yr. 2 – $341 million Yr. 3 – $352 million In 2017, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $57 million, $26 million and $68 million of net regulatory liabilities, respectively (f).	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (f), municipal infrastructure support costs (g), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (h). In 2017, the company deferred $35 million of net regulatory assets.
Net utility plant reconciliations	Target levels reflected in rates were: Transmission and distribution: Yr. 1 – $16,869 million Yr. 2 – $17,401 million Yr. 3 – $17,929 million Storm hardening: Yr. 1 – $89 million; Yr. 2 – $177 million; Yr. 3 – $268 million Other: Yr. 1 – $2,034 million; Yr. 2 – $2,102 million; Yr. 3 – $2,069 million The company deferred $6 million and $17 million as a regulatory liability in 2014 and 2015, respectively. In 2016, $9 million was deferred as a regulatory asset.	Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 – $21,689 million Yr. 2 – $22,338 million Yr. 3 – $23,002 million AMI: Yr. 1 – $126 million Yr. 2 – $257 million Yr. 3 – $415 million The company deferred $0.4 million as a regulatory asset in 2017.
Average rate base	Yr. 1 – $17,323 million Yr. 2 – $18,113 million Yr. 3 – $18,282 million	Yr. 1 – $18,902 million Yr. 2 – $19,530 million Yr. 3 – $20,277 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.05 percent Yr. 2 – 7.08 percent Yr. 3 – 6.91 percent	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent
Authorized return on common equity	Yrs. 1 and 2 – 9.2 percent Yr. 3 – 9.0 percent	9.0 percent
Actual return on common equity	Yr. 1 – 9.04 percent Yr. 2 – 10.16 percent Yr. 3 – 9.66 percent	Yr. 1 – 9.3 percent

Earnings sharing	Most earnings above an annual earnings threshold of 9.8 percent for Yrs. 1 and 2 and 9.6 percent for Yr. 3 are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014 the company had no earnings above the threshold. Actual earnings were $44.4 million and $6.5 million above the threshold for 2015 and 2016, respectively.	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold but recorded a positive adjustment related to 2016 of $5.7 million in earnings.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.09 percent	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent
Common equity ratio	48 percent	48 percent

(a) The impact of these base rate changes was deferred which resulted in a $30 million regulatory liability at December 31, 2015; this amount has been amortized to $0 at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's electric rate plan for January 2017 through December 2019. If at the end of any year, Con Edison’s investments in its non-utility businesses exceed 15 percent of Con Edison’s total consolidated revenues, assets or cash flow, or if the ratio of holding company debt to total consolidated debt rises above 20 percent, CECONY is required to notify the NYSPSC and submit a ring-fencing plan or a demonstration why additional ring-fencing measures are not necessary.

(c) The electric base rate increases are in addition to a $48 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan. At the NYSPSC’s option, these increases are being implemented with increases of $199 million in each rate year. Base rates reflect recovery by the company of certain costs of its energy efficiency, system peak reduction and electric vehicle programs (Yr. 1 - $20.5 million; Yr. 2 - $49 million; and Yr. 3 - $107.5 million) over a ten-year period, including the overall pre-tax rate of return on such costs.

(d) Amounts reflect annual amortization of $107 million of the regulatory asset for deferred Superstorm Sandy and other major storm costs. The costs recoverable from customers were reduced by $4 million. The costs are no longer subject to NYSPSC staff review and the recovery of the costs is no longer subject to refund. In 2016, an additional $123 million of net regulatory liabilities were amortized to income.

(e) For transmission service provided pursuant to the open access transmission tariff of PJM Interconnection LLC (PJM), unless and until changed by the NYSPSC, the company will recover all charges incurred associated with the transmission service. Starting in January 2014, PJM submitted to the FERC a series of requests that substantially increase the charges for the transmission service. CECONY has challenged each of these requests. To date, FERC has 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 April 2017, the transmission service terminated because CECONY did not exercise its option to continue the service.

(f) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points (5.0, 7.5 or 10.0 basis points, depending on the year).

(g) In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral of 30 percent of the amount reflected in rates.

(h) In addition, amounts reflected in rates relating to the regulatory asset for future income tax and the excess deferred federal income tax liability are subject to reconciliation. The NYSPSC staff is to audit the regulatory asset and the tax liability. Differences resulting from the NYSPSC staff review will be deferred for NYSPSC determination of any amounts to be refunded or collected from customers. See "Other Regulatory Matters," below.

CECONY – Gas
Effective period	January 2014 – December 2016	January 2017 - December 2019 (b)
Base rate changes	Yr. 1 – $(54.6) million (a) Yr. 2 – $38.6 million (a) Yr. 3 – $56.8 million (a)	Yr. 1 – $(5) million (b) Yr. 2 – $92 million (b) Yr. 3 – $90 million (b)
Amortizations to income of net regulatory (assets) and liabilities	$4 million over three years	Yr. 1 – $39 million Yr. 2 – $37 million Yr. 3 – $36 million
Other revenue sources	Retention of revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. The company retained $70 million, $66 million and $65 million of such revenues in 2014, 2015 and 2016, respectively.	Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $7 million Yr. 2 – $8 million Yr. 3 – $8 million In 2017, the company achieved incentives of $7 million that, pursuant to the rate plan, will be recorded ratably in earnings from 2018 to 2020.
Revenue decoupling mechanisms	In 2014, 2015 and 2016, the company deferred $28 million, $54 million and $71 million of regulatory liabilities, respectively.	Continuation of reconciliation of actual to authorized gas delivery revenues. In 2017, the company deferred $3 million of regulatory liabilities.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $33 million in 2014, $44 million in 2015, and $56 million in 2016) if certain gas performance targets are not met. In 2014, 2015 and 2016, the company did not record any negative revenue adjustments.	Potential penalties if performance targets relating to service, safety and other matters are not met: Yr. 1 – $68 million Yr. 2 – $63 million Yr. 3 – $70 million In 2017, the company recorded a $5 million negative revenue adjustment.
Cost reconciliations	In 2014, 2015 and 2016, the company deferred $38 million, $11 million, and $32 million of net regulatory liabilities, respectively. (c)	Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes, municipal infrastructure support costs, the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (d) In 2017, the company deferred $2 million of net regulatory liabilities.
Net utility plant reconciliations	Target levels reflected in rates were: Gas delivery Yr. 1 – $3,899 million; Yr. 2 – $4,258 million; Yr. 3 – $4,698 million Storm hardening: Yr. 1 – $3 million; Yr. 2 – $8 million; Yr. 3 – $30 million In 2015 $1 million was deferred as a regulatory liability. In 2014 and 2016 the company deferred an immaterial amount.	Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $5,844 million Yr. 2 – $6,512 million Yr. 3 – $7,177 million AMI: Yr. 1 – $27 million Yr. 2 – $57 million Yr. 3 – $100 million In 2017 $2.2 million was deferred a regulatory liability.
Average rate base	Yr. 1 – $3,521 million Yr. 2 – $3,863 million Yr. 3 – $4,236 million	Yr. 1 – $4,841 million Yr. 2 – $5,395 million Yr. 3 – $6,005 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent	Yr. 1 – 6.82 percent Yr. 2 – 6.80 percent Yr. 3 – 6.73 percent
Authorized return on common equity	9.3 percent	9.0 percent
Actual return on common equity	Yr. 1 – 8.02 percent Yr. 2 – 8.13 percent Yr. 3 – 7.83 percent	Yr. 1 – 9.22 percent
Earnings sharing	Most earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, 2015 and 2016, the company had no earnings above the threshold.	Most earnings above an annual earnings threshold of 9.5 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2017, the company had no earnings above the threshold.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent	Yr. 1 – 4.93 percent Yr. 2 – 4.88 percent Yr. 3 – 4.74 percent

Common equity ratio 48 percent 48 percent

(a) The impact of these base rate changes was deferred which resulted in a $32 million regulatory liability at December 31, 2016.

(b) In January 2017, the NYSPSC approved the September 2016 Joint Proposal for CECONY's gas rate plan for January 2017 through December 2019. The gas base rate decrease is offset by a $41 million increase resulting from the December 2016 expiration of a temporary credit under the prior rate plan.

(c) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity

(d) See footnotes (e), (f), (g) and (h) to the table under "CECONY - Electric" above.

CECONY – Steam
Effective period	January 2014 – December 2016 (a)
Base rate changes	Yr. 1 – $(22.4) million (b) Yr. 2 – $19.8 million (b) Yr. 3 – $20.3 million (b) Yr. 4 – None
Amortizations to income of net regulatory (assets) and liabilities	$37 million over three years
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.
Negative revenue adjustments	Potential penalties (up to $1 million annually) if certain steam performance targets are not met. In 2014, 2015, 2016 and 2017, the company did not record any negative revenue adjustments.
Cost reconciliations (c)	In 2014, 2015, 2016 and 2017, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Production: Yr. 1 – $1,752 million; Yr. 2 – $1,732 million; Yr. 3 – $1,720 million Distribution: Yr. 1 – $6 million; Yr. 2 – $11 million; Yr. 3 – $25 million The company reduced its regulatory liability by $0.1 million in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017.
Average rate base	Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.10 percent Yr. 2 – 7.13 percent Yr. 3 – 7.21 percent
Authorized return on common equity	9.3 percent
Actual return on common equity	Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent
Earnings sharing	Weather normalized earnings above an annual earnings threshold of 9.9 percent are to be applied to reduce regulatory assets for environmental remediation and other costs. In 2014, the company had no earnings above the threshold. Actual earnings were $11.5 million and $7.8 million above the threshold in 2015 and 2016, respectively. In 2017, actual earnings were $8.5 million above the threshold, offset in part by a positive adjustment related to 2016 of $4 million.
Cost of long-term debt	Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent
Common equity ratio	48 percent

(a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC.

(b) The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016.

(c) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a 10 basis point impact on return on common equity.

O&R New York – Electric
Effective period	July 2012 – October 2015	November 2015 - October 2017 (a)
Base rate changes	Yr. 1 – $19.4 million Yr. 2 – $8.8 million Yr. 3 – $15.2 million	Yr. 1 – $9.3 million Yr. 2 – $8.8 million
Amortizations to income of net regulatory (assets) and liabilities	$(32.2) million over three years	Yr. 1 – $(8.5) million (b) Yr. 2 – $(9.4) million (b)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred for the customer’s benefit $2.6 million, $3.2 million and $(3.4) million, respectively.	In 2015, 2016 and 2017, the company deferred for the customer’s benefit an immaterial amount, $6.3 million as regulatory liabilities and $11.2 million as regulatory asset, respectively.
Recoverable energy costs	Current rate recovery of purchased power and fuel costs.	Continuation of current rate recovery of purchased power costs.
Negative revenue adjustments	Potential penalties (up to $3 million annually) if certain customer service and system reliability performance targets are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (up to $4 million annually) if certain performance targets are not met. In 2015 the company recorded $1.25 million in negative revenue adjustments. In 2016 and 2017, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $7.8 million, $4.1 million and $(0.2) million as a net increase/(decrease) to regulatory assets, respectively.	In 2015, 2016 and 2017, the company deferred $0.3 million, $7.4 million and $3.2 million as net decreases to regulatory assets, respectively.
Net utility plant reconciliations	Target levels reflected in rates were: Yr. 1 – $678 million; Yr. 2- $704 million; Yr. 3 – $753 million The company increased its regulatory liability by $4.2 million in 2012. The company reduced its regulatory liability by $1.1 million and $2.3 million in 2013 and 2014, respectively.	Target levels reflected in rates are: Yr. 1 – $928 million (c) Yr. 2 – $970 million (c) The company increased/(reduced) its regulatory asset by $2.2 million, $(1.9) million and $(1.9) million in 2015, 2016 and 2017, respectively.
Average rate base	Yr. 1 – $671 million Yr. 2 – $708 million Yr. 3 – $759 million	Yr. 1 – $763 million Yr. 2 – $805 million
Weighted average cost of capital (after-tax)	Yr. 1 – 7.61 percent Yr. 2 – 7.65 percent Yr. 3 – 7.48 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent
Authorized return on common equity	Yr. 1 – 9.4 percent Yr. 2 – 9.5 percent Yr. 3 – 9.6 percent	9.0 percent
Actual return on common equity	Yr. 1 – 12.9 percent Yr. 2 – 8.7 percent Yr. 3 – 9.4 percent	Yr. 1 – 10.8 percent Yr. 2 – 9.7 percent
Earnings sharing	The company recorded a regulatory liability of $1 million for earnings above the sharing threshold under the rate plan as of December 31, 2014.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $6.1 million and $0.3 million above the threshold for 2016 and 2017, respectively.
Cost of long-term debt	Yr. 1 – 6.07 percent Yr. 2 – 6.07 percent Yr. 3 – 5.64 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) Rates determined pursuant to this rate plan continue in effect until a new rate plan is approved by the NYSPSC.

(b) $59.3 million of the regulatory asset for deferred storm costs is to be recovered from customers over a five year period, including $11.85 million in each of years 1 and 2, $1 million of the regulatory asset for such costs will not be recovered from customers, and all outstanding issues related to Superstorm Sandy and other past major storms prior to November 2014 are resolved. Approximately $4 million of regulatory assets for property tax and interest rate reconciliations will not be recovered from customers. Amounts that will not be recovered from customers were charged-off in June 2015.

(c) Excludes electric AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $1 million in year 1 and $9 million in year 2.

O&R New York – Gas
Effective period	November 2009 – October 2015	November 2015 – October 2018
Base rate changes	Yr. 1 – $9 million Yr. 2 – $9 million Yr. 3 – $4.6 million Yr. 3 – $4.3 million collected through a surcharge Yr. 4 – None Yr. 5 – None	Yr. 1 – $16.4 million Yr. 2 – $16.4 million Yr. 3 – $5.8 million Yr. 3 – $10.6 million collected through a surcharge
Amortization to income of net regulatory (assets) and liabilities	$(2) million over three years	Yr. 1 – $(1.7) million (a) Yr. 2 – $(2.1) million (a) Yr. 3 – $(2.5) million (a)
Revenue decoupling mechanisms	In 2012, 2013 and 2014, the company deferred $4.7 million, $0.7 million and $(0.1) million of regulatory liabilities, respectively.	In 2015 and 2016, the company deferred $0.8 million regulatory assets and $6.2 million of regulatory liabilities, respectively. In 2017, the company deferred $1.7 million in regulatory liabilities.
Recoverable energy costs	Current rate recovery of purchased gas costs.	Current rate recovery of purchased gas costs.
Negative revenue adjustments	Potential penalties (up to $1.4 million annually) if certain operations and customer service requirements are not met. In 2012, 2013 and 2014, the company did not record any negative revenue adjustments.	Potential penalties (up to $3.7 million in Yr. 1, $4.7 million in Yr. 2 and $4.9 million in Yr. 3) if certain performance targets are not met. In 2015, 2016 and 2017, the company did not record any negative revenue adjustments.
Cost reconciliations	In 2012, 2013 and 2014, the company deferred $0.7 million, $8.3 million and $8.3 million as net regulatory assets, respectively.	In 2015 and 2016, the company deferred $4.5 million and $6.6 million as net regulatory liabilities and assets, respectively. In 2017, the company deferred $3.5 million as net regulatory liabilities.
Net utility plant reconciliations	The company deferred $0.7 million in 2012 as a regulatory asset and no deferrals were recorded for 2013 or 2014.	Target levels reflected in rates are: Yr. 1 – $492 million (b) Yr. 2 – $518 million (b) Yr. 3 – $546 million (b) No deferral was recorded for 2015 and immaterial amounts were recorded as regulatory liabilities in 2016 and 2017.
Average rate base	Yr. 1 – $280 million Yr. 2 – $296 million Yr. 3 – $309 million	Yr. 1 – $366 million Yr. 2 – $391 million Yr. 3 – $417 million
Weighted average cost of capital (after-tax)	8.49 percent	Yr. 1 – 7.10 percent Yr. 2 – 7.06 percent Yr. 3 – 7.06 percent
Authorized return on common equity	10.4 percent	9.0 percent
Actual return on common equity	Yr. 1 – 10.2 percent Yr. 2 – 9.6 percent Yr. 3 – 12.6 percent Yr. 4 – 10.2 percent Yr. 5 – 6.1 percent	Yr. 1 – 11.2 percent Yr. 2 – 9.7 percent
Earnings sharing	Earnings above an annual earnings threshold of 11.4 percent are to be applied to reduce regulatory assets. In 2012, 2013 and 2014, earnings did not exceed the earnings threshold.	Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets. In 2015, earnings did not exceed the earnings threshold. Actual earnings were $4 million and $0.2 million above the threshold for 2016 and 2017, respectively.
Cost of long-term debt	6.81 percent	Yr. 1 – 5.42 percent Yr. 2 – 5.35 percent Yr. 3 – 5.35 percent
Common equity ratio	48 percent	48 percent

(a) Reflects that the company will not recover from customers a total of approximately $14 million of regulatory assets for property tax and interest rate reconciliations. Amounts that will not be recovered from customers were charged-off in June 2015.

(b) Excludes gas AMI as to which the company will be required to defer as a regulatory liability the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates: $0.5 million in year 1, $4.2 million in year 2 and $7.2 million in year 3.

Schedule of Regulatory Assets

Regulatory assets and liabilities at December 31, 2017 and 2016 were comprised of the following items:

	Con Edison			CECONY
(Millions of Dollars)	2017	2016		2017	2016
Regulatory assets
Unrecognized pension and other postretirement costs	$2,526	$2,874		$2,376	$2,730
Future income tax*	—	2,439		—	2,325
Environmental remediation costs	793	823		677	711
Revenue taxes	260	295		248	280
Pension and other postretirement benefits deferrals	79	38		58	7
Recoverable energy costs	60	42		52	38
Municipal infrastructure support costs	56	44		56	44
Property tax reconciliation	51	37		25	—
MTA power reliability deferral	50	—		50	—
Deferred derivative losses	44	48		37	42
Deferred storm costs	38	56		—	3
Brooklyn Queens demand management program	37	29		37	29
Unamortized loss on reacquired debt	37	43		35	41
Indian Point Energy Center program costs	29	50		29	50
Preferred stock redemption	24	25		24	25
Workers’ compensation	10	13		10	13
Net electric deferrals	9	24		9	24
O&R transition bond charges	9	15		—	—
Surcharge for New York State assessment	2	28		2	26
Other	152	101		138	85
Regulatory assets – noncurrent	4,266	7,024		3,863	6,473
Deferred derivative losses	40	91		37	86
Recoverable energy costs	27	9		25	4
Regulatory assets – current	67	100		62	90
Total Regulatory Assets	$4,333	$7,124		$3,925	$6,563
Regulatory liabilities
Future income tax*	$2,545		$—	$2,390		$—
Allowance for cost of removal less salvage	846	755		719	641
Pension and other postretirement benefit deferrals	207	193		181	162
Net unbilled revenue deferrals	183	145		183	145
Energy efficiency portfolio standard unencumbered funds	127	—		122	—
Property tax reconciliation	107	178		107	178
Unrecognized other postretirement costs	92	60		92	60
Settlement of prudence proceeding	66	95		66	95
Property tax refunds	44	1		44	1
Carrying charges on repair allowance and bonus depreciation	43	68		42	67
New York State income tax rate change	36	61		35	60
Variable-rate tax-exempt debt - cost rate reconciliation	30	55		26	48
Earnings sharing - electric, gas and steam	29	39		19	28
Settlement of gas proceedings	27	27		27	27
Base rate change deferrals	21	40		21	40
Net utility plant reconciliations	12	16		8	15
Other	162	172		137	145
Regulatory liabilities – noncurrent	4,577	1,905		4,219	1,712
Refundable energy costs	41	29		16	5
Deferred derivative gains	31	28		28	24
Revenue decoupling mechanism	29	71		21	61
Regulatory liabilities—current	101	128		65	90
Total Regulatory Liabilities	$4,678	$2,033		$4,284	$1,802

` * See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L.

Schedule of Regulatory Liabilities

Regulatory assets and liabilities at December 31, 2017 and 2016 were comprised of the following items:

	Con Edison			CECONY
(Millions of Dollars)	2017	2016		2017	2016
Regulatory assets
Unrecognized pension and other postretirement costs	$2,526	$2,874		$2,376	$2,730
Future income tax*	—	2,439		—	2,325
Environmental remediation costs	793	823		677	711
Revenue taxes	260	295		248	280
Pension and other postretirement benefits deferrals	79	38		58	7
Recoverable energy costs	60	42		52	38
Municipal infrastructure support costs	56	44		56	44
Property tax reconciliation	51	37		25	—
MTA power reliability deferral	50	—		50	—
Deferred derivative losses	44	48		37	42
Deferred storm costs	38	56		—	3
Brooklyn Queens demand management program	37	29		37	29
Unamortized loss on reacquired debt	37	43		35	41
Indian Point Energy Center program costs	29	50		29	50
Preferred stock redemption	24	25		24	25
Workers’ compensation	10	13		10	13
Net electric deferrals	9	24		9	24
O&R transition bond charges	9	15		—	—
Surcharge for New York State assessment	2	28		2	26
Other	152	101		138	85
Regulatory assets – noncurrent	4,266	7,024		3,863	6,473
Deferred derivative losses	40	91		37	86
Recoverable energy costs	27	9		25	4
Regulatory assets – current	67	100		62	90
Total Regulatory Assets	$4,333	$7,124		$3,925	$6,563
Regulatory liabilities
Future income tax*	$2,545		$—	$2,390		$—
Allowance for cost of removal less salvage	846	755		719	641
Pension and other postretirement benefit deferrals	207	193		181	162
Net unbilled revenue deferrals	183	145		183	145
Energy efficiency portfolio standard unencumbered funds	127	—		122	—
Property tax reconciliation	107	178		107	178
Unrecognized other postretirement costs	92	60		92	60
Settlement of prudence proceeding	66	95		66	95
Property tax refunds	44	1		44	1
Carrying charges on repair allowance and bonus depreciation	43	68		42	67
New York State income tax rate change	36	61		35	60
Variable-rate tax-exempt debt - cost rate reconciliation	30	55		26	48
Earnings sharing - electric, gas and steam	29	39		19	28
Settlement of gas proceedings	27	27		27	27
Base rate change deferrals	21	40		21	40
Net utility plant reconciliations	12	16		8	15
Other	162	172		137	145
Regulatory liabilities – noncurrent	4,577	1,905		4,219	1,712
Refundable energy costs	41	29		16	5
Deferred derivative gains	31	28		28	24
Revenue decoupling mechanism	29	71		21	61
Regulatory liabilities—current	101	128		65	90
Total Regulatory Liabilities	$4,678	$2,033		$4,284	$1,802