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Electricity and Gas Purchase Agreements | 12 Months Ended
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Dec. 31, 2023
Regulated Operations [Abstract] |
Electricity and Gas Purchase Agreements | Regulatory Matters Rate Plans The Utilities provide service to New York customers according to the terms of tariffs approved by the NYSPSC. Tariffs for service to customers of Rockland Electric Company (RECO), O&R’s New Jersey regulated utility subsidiary, are approved by the New Jersey Board of Public Utilities (NJBPU). The tariffs include schedules of rates for service that limit the rates charged by the Utilities to amounts that the Utilities recover from their customers costs approved by the regulator, including capital costs, of providing service to customers as defined by the tariff. The tariffs implement rate plans adopted by state utility regulators in rate orders issued at the conclusion of rate proceedings. Pursuant to the Utilities’ rate plans, there generally can be no change to the charges to customers during the respective terms of the rate plans other than specified adjustments provided for in the rate plans. The Utilities’ rate plans each cover specified periods, but rates determined pursuant to a plan generally continue in effect until a new rate plan is approved by the state utility regulator. Common provisions of the Utilities’ New York rate plans include: Earnings sharing that require the Utilities to defer for customer benefit a portion of earnings over specified rates of return on common equity. There is no symmetric mechanism for earnings below specified rates of return on common equity. Negative revenue adjustments for failure to meet certain performance standards relating to service, reliability, safety and other matters Net utility plant reconciliations that require deferral as a regulatory liability of the revenue requirement impact of the amount, if any, by which actual average net utility plant balances are less than amounts reflected in rates. There is generally no symmetric mechanism if actual average net utility plant balances are more than amounts reflected in rates. Other revenue adjustments represent positive revenue adjustments, positive incentives, and earnings adjustments mechanisms for achievement of performance standards related to achievement of clean energy goals, safety and other matters. Rate base, as reflected in the rate plans, is, in general, the sum of the Utilities’ net plant, working capital and certain regulatory assets less deferred taxes and certain regulatory liabilities. For each rate plan, the NYSPSC uses a forecast of the average rate base for each year that new rates would be in effect (“rate year”). Recoverable energy costs that allow the Utilities to recover on a current basis the costs for the energy they supply with no mark-up to their full-service customers. Regulatory reconciliations that reconcile pension and other postretirement benefit costs, environmental remediation costs, property taxes, variable-rate tax-exempt debt and certain other costs to amounts reflected in delivery rates for such costs. In addition, changes in the Utilities' costs not reflected in rates, in excess of certain amounts, resulting from changes in tax or changes in legislation, regulation or related actions, are deferred as a regulatory asset or regulatory liability to be reflected in the Utilities' next rate plan or in a manner to be determined by the NYSPSC. Also, the Utilities generally retain the right to petition for recovery or accounting deferral of extraordinary and material cost increases and provision is sometimes made for the utility to retain a share of cost reductions, for example, property tax refunds. Revenue decoupling mechanisms that reconcile actual energy delivery revenues to the authorized delivery revenues approved by the NYSPSC. The difference is accrued with interest for refund to, or recovery from customers, as applicable. Weighted average cost of capital is determined based on the authorized common equity ratio, return on common equity, cost of long-term debt and cost of customer deposits reflected in each rate plan. For each rate plan, the revenues designed to provide the utility a return on invested capital for each rate year are determined by multiplying each utility rate base by its pre–tax weighted average cost of capital. The Utilities’ actual return on common equity will reflect their actual operations for each rate year, and may be more or less than the authorized return on equity reflected in their rate plans (and if more, may be subject to earnings sharing). The following tables contain a summary of the Utilities’ rate plans:
CECONY – Electric |  |  |  |  |  |
Effective period |  |  |  | January 2020 – December 2022 |  | January 2023 – December 2025
Base rate changes |  |  |  | Yr. 1 – $113 million (a) Yr. 2 – $370 million (a) Yr. 3 – $326 million (a) |  | Yr. 1 – $442 million (c) Yr. 2 – $518 million (c) Yr. 3 – $382 million (c)
Amortizations to income of net regulatory (assets) and liabilities |  |  |  | Yr. 1 – $267 million (b) Yr. 2 – $269 million (b) Yr. 3 – $272 million (b) |  | Yr. 1 – $104 million (j) Yr. 2 – $49 million (j) Yr. 3 – $(205) million (j)
Other revenue sources |  |  |  | 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 - $69 million Yr. 2 - $74 million Yr. 3 - $79 million In 2020, 2021 and 2022, the company recorded $34 million, $64 million and $33 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively. In 2022, the company recorded a positive incentive of $4 million. |  | 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 - $70 million Yr. 2 - $75 million Yr. 3 - $79 million In 2023, the company recorded $34.4 million primarily related to earnings adjustment mechanism incentives for energy efficiency.
Revenue decoupling mechanisms |  |  |  | Continuation of reconciliation of actual to authorized electric delivery revenues. In 2020, 2021 and 2022, the company deferred for recovery from customers $242 million, $226 million and $90 million of revenues, respectively. |  | Continuation of reconciliation of actual to authorized electric delivery revenues. In 2023, the company deferred for recovery from customers $162 million of revenues.
Recoverable energy costs |  |  |  | Continuation of current rate recovery of purchased power and fuel costs. |  | Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments |  |  |  | Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $450 million Yr. 2 - $461 million Yr. 3 - $476 million In 2020, the company recorded negative revenue adjustments of $5 million. In 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $3 million. |  | Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $516 million Yr. 2 - $557 million Yr. 3 - $597 million In 2023, the company did not record any negative revenue adjustments.
Regulatory reconciliations |  |  |  | Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $288 million and $191 million of net regulatory assets, respectively. In 2022, the company deferred $138 million of net regulatory liabilities. |  | Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023, the company deferred $140 million of net regulatory liabilities.
Net utility plant reconciliations |  |  |  | Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $24,491 million Yr. 2 - $25,092 million Yr. 3 - $25,708 million AMI (h): Yr. 1 - $572 million Yr. 2 - $740 million Yr. 3 - $806 million In 2020, the company deferred $4.1 million as a regulatory asset. In 2021 and 2022, the company deferred $3.2 million and $1.8 million, as a regulatory liability, respectively. |  | Target levels reflected in rates: Electric average net plant target excluding advanced metering infrastructure (AMI) and Customer Service System (CSS) for Yr. 1: Yr. 1 - $27,847 million Yr. 2 - $29,884 million Yr. 3 - $31,026 million AMI (h): Yr. 1 - $744 million CSS: Yr. 1 - $11 million In 2023, the company deferred $1.2 million as a regulatory asset.
Average rate base |  |  |  | Yr. 1 - $21,660 million Yr. 2 - $22,783 million Yr. 3 - $23,926 million |  | Yr. 1 - $26,095 million Yr. 2 - $27,925 million Yr. 3 - $29,362 million
Weighted average cost of capital (after-tax) |  |  |  | Yr. 1 to Yr. 3 – 6.61 percent |  | Yr. 1 - 6.75 percent Yr. 2 - 6.79 percent Yr. 3 - 6.85 percent
Authorized return on common equity |  |  |  | 8.8 percent |  | 9.25 percent
Actual return on common equity (h) (i) |  |  |  | Yr. 1 – 8.5 percent Yr. 2 – 8.03 percent Yr. 3 – 8.41 percent |  | Yr. 1 – 9.46 percent
Earnings sharing |  |  |  | Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings sharing above the threshold. A reserve of $4.3 million was recorded in 2021 related to a potential adjustment to the excess earnings sharing amount for 2016. |  | Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023, the company had no earnings sharing above the threshold.
Cost of long-term debt |  |  |  | Yr. 1 to Yr. 3 – 4.63 percent |  | Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent
Common equity ratio |  |  |  | 48 percent |  | 48 percent
(a)Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $206 million; Yr. 2 - $245 million; and Yr. 3 - $251 million) over a 10-year period, including the overall pre-tax rate of return on such costs. (b)Amounts reflect amortization of the 2018 tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) allocable to CECONY’s electric customers ($377 million) over a three-year period ($126 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,663 million) over the remaining lives of the related assets ($49 million in Yr. 1, $50 million in Yr. 2, and $53 million in Yr. 3) and the unprotected portion of the net regulatory liability ($784 million) over five years ($157 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($238 million) over a five-year period ($48 million annually). (c)The electric base rate increases shown above will be implemented with increases of $457 million in Yr. 1; $457 million in Yr. 2; and $457 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023 and CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($216 million) are being collected through a surcharge billed through 2024, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency, demonstration projects, non-wire alternative projects (including the Brooklyn Queens demand management program), and off-peak electric vehicle charging programs (Yr. 1 - $244 million; Yr. 2 - $237 million; and Yr. 3 - $281 million) over periods varying between seven and fifteen years, including the overall pre-tax rate of return on such costs. (d)Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity of 10.0 basis points, 7.5 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2020 – 2022 rate plan and 10.0 basis points, 5.0 basis points and 5.0 basis points for each of Yr. 1, Yr. 2 and Yr. 3, respectively, of the 2023 – 2025 rate plan. (e)In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates the company will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates the company will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 15 percent of the amount reflected in the rate plans. (f)In addition, the NYSPSC continues its focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (g)Reconciliation of net utility plant for AMI will be done on a combined basis for electric and gas. (h)Calculated in accordance with the earnings calculation method prescribed in the rate order. (i)In November 2021, the NYSPSC issued an order that allowed CECONY to recover $43 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.81 percent. (j)Amounts reflect amortization of the TCJA allocable to CECONY’s electric customers ($256 million) over a two-year period ($128 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s electric customers ($1,512 million) over the remaining lives of the related assets ($34 million in Yr. 1, $63 million in Yr. 2, and $34 million in Yr. 3) and the unprotected portion of the net regulatory liability ($306 million) over two years ($153 million annually). Amounts also reflect amortization of the regulatory asset for deferred MTA power reliability costs ($93 million) over a three-year period ($31 million annually). In April 2023, the NYSPSC approved CECONY’s December 2022 petition seeking cost recovery approval for a proposed clean energy hub in Brooklyn, New York (Brooklyn Clean Energy Hub) at an estimated cost of $810 million, and an estimated in-service date of December 2027, that is in addition to the capital expenditures approved in the CECONY 2023 - 2025 electric rate plan summarized above. The Brooklyn Clean Energy Hub primarily addresses an identified reliability need in 2028 due to a forecasted increase in electric demand. The Brooklyn Clean Energy Hub provides the flexibility for offshore wind resources to interconnect to it during construction and after it commences operation. Construction began in September 2023 and is expected to be completed by 2028. The carrying costs of the Brooklyn Clean Energy Hub will be recovered from customers via a surcharge mechanism after it is placed into service and until such costs are reflected in base rates. In January 2024, the NYSPSC approved CECONY's August 2023 petition requesting authorization and cost recovery to construct two new substations in Jamaica, Queens (the Reliable Clean City - Idlewild Project) that is in addition to the capital expenditures approved in CECONY's 2023 - 2025 electric rate plan summarized above. The project is expected to be completed by May 2028 to meet anticipated reliability needs and to support New York State’s Climate Leadership and Community Protection Act goals. CECONY estimates that construction will cost $1,200 million. The carrying costs of the Reliable Clean City – Idlewild Project will be recovered from customers via a surcharge mechanism after it is placed into service and until such costs are reflected in base rates.
CECONY – Gas |  |  |  |
Effective period |  | January 2020 – December 2022 |  | January 2023 – December 2025
Base rate changes |  | Yr. 1 – $84 million (a) Yr. 2 – $122 million (a) Yr. 3 – $167 million (a) |  | Yr. 1 – $217 million (c) Yr. 2 – $173 million (c) Yr. 3 – $122 million (c)
Amortizations to income of net regulatory (assets) and liabilities |  | Yr. 1 – $45 million (b) Yr. 2 – $43 million (b) Yr. 3 – $10 million (b) |  | Yr. 1 – $31 million (j) Yr. 2 – $24 million (j) Yr. 3 – $(11) million (j)
Other revenue sources |  | Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential incentives if performance targets related to gas leak backlog, leak prone pipe and service terminations are met: Yr. 1 – $20 million Yr. 2 – $22 million Yr. 3 – $25 million In 2020, 2021 and 2022, the company recorded $3 million, $26 million and $8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2020, 2021 and 2022, the company recorded positive incentives of $13 million, $7 million, and $9 million respectively. In 2021, the company reversed $6 million of positive incentives recorded in 2020 pursuant to an order issued by the NYSPSC in December 2021. |  | Retention of annual revenues from non-firm customers of up to $65 million and 15 percent of any such revenues above $65 million. Potential earnings adjusted mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $18 million Yr. 2 - $20 million Yr. 3 - $21 million In 2023, the company recorded $5 million of earnings adjustment mechanism incentives for energy efficiency. In 2023, the company recorded positive incentives of $3 million.
Revenue decoupling mechanisms |  | Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2020, 2021 and 2022, the company deferred for recovery from customers $27 million, $100 million and $141 million of revenues, respectively. |  | Continuation of reconciliation of actual to authorized gas delivery revenues, modified to be calculated based upon revenue per customer class instead of revenue per customer. In 2023, the company deferred for recovery from customers $162 million of revenues.
Recoverable energy costs |  | Continuation of current rate recovery of purchased gas costs. |  | Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments |  | Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $81 million Yr. 2 – $88 million Yr. 3 – $96 million In 2020 and 2021, the company did not record any negative revenue adjustments. In 2022, the company recorded negative revenue adjustments of $8 million. |  | Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $107 million Yr. 2 - $119 million Yr. 3 - $130 million In 2023, the company recorded negative revenue adjustments of $3 million.
Regulatory reconciliations |  | Continuation of reconciliation of expenses for pension and other postretirement benefits, variable-rate tax-exempt debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2020 and 2021, the company deferred $91 million and $14 million of net regulatory assets, respectively. In 2022, the company deferred $70 million of net regulatory liabilities. |  | Reconciliation of late payment charges (i) and expenses for uncollectibles, pension and other postretirement benefits, variable-rate debt, major storms, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates (f). In 2023, the company deferred $12 million of net regulatory liabilities.
Net utility plant reconciliations |  | Target levels reflected in rates: Gas average net plant target excluding AMI: Yr. 1 – $8,108 million Yr. 2 – $8,808 million Yr. 3 – $9,510 million AMI (g): Yr. 1 – $142 million Yr. 2 – $183 million Yr. 3 – $211 million In 2020 and 2021, the company deferred $24.7 million and $26 million, as a regulatory liability, respectively. In 2022, the company deferred $10.8 million as a regulatory asset. |  | Target levels reflected in rates: Gas average net plant target excluding AMI and CSS for Yr. 1: Yr. 1 - $10,466 million Yr. 2 - $11,442 million Yr. 3 - $12,142 million AMI (g): Yr. 1 - $234 million CSS: Yr. 1 - $2 million In 2023, the company deferred $15.5 million as a regulatory liability.
Average rate base |  | Yr. 1 – $7,171 million Yr. 2 – $7,911 million Yr. 3 – $8,622 million |  | Yr. 1 - $9,647 million Yr. 2 - $10,428 million Yr. 3 - $11,063 million
Weighted average cost of capital (after-tax) |  | Yr. 1 – Yr. 3 - 6.61 percent |  | Yr. 1 – 6.75 percent Yr. 2 – 6.79 percent Yr. 3 – 6.85 percent
Authorized return on common equity |  | 8.8 percent |  | 9.25 percent
Actual return on common equity (h) (i) |  | Yr. 1 – 8.4 percent Yr. 2 – 8.48 percent Yr. 3 – 8.93 percent |  | Yr. 1 – 9.00 percent
Earnings sharing |  | Most earnings above an annual earnings threshold of 9.3 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2020, 2021 and 2022, the company had no earnings above the threshold. |  | Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2023, the company had no earnings above the threshold.
Cost of long-term debt |  | Yr. 1 – Yr. 3 - 4.63 percent |  | Yr. 1 – 4.46 percent Yr. 2 – 4.54 percent Yr. 3 – 4.64 percent
Common equity ratio |  | 48 percent |  | 48 percent
(a)The gas base rate increases shown above will be implemented with increases of $47 million in Yr. 1; $176 million in Yr. 2; and $170 million in Yr. 3 in order to levelize customer bill impacts. Base rates reflect recovery by the company of certain costs of its energy efficiency program (Yr. 1 - $30 million; Yr. 2 - $37 million; and Yr. 3 - $40 million) over a ten-year period, including the overall pre-tax rate of return on such costs. (b) Amounts reflect amortization of t he remaining 2018 TCJA tax savings allocable to CECONY’s gas customers ($63 million) over a two year period ($32 million annually), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($725 million) over the remaining lives of the related assets ($14 million in Yr. 1, $14 million in Yr. 2, and $12 million in Yr. 3) and the unprotected portion of the net regulatory liability ($107 million) over five years ($21 million annually) (c) The gas base rate increases shown above will be implemented with increases of $187 million in Yr. 1; $187 million in Yr. 2; and $187 million in Yr. 3 in order to levelize the customer bill impact. New rates were effective as of January 1, 2023. CECONY began billing customers at the new levelized rate in August 2023. The shortfall in revenues due to the timing of billing to customers ($99 million) are being collected through a surcharge billed through 2025, including a carrying charge on the outstanding balance. Base rates reflect recovery by the company of certain costs of its energy efficiency programs (Yr. 1 - $45 million; Yr. 2 - $78 million; and Yr. 3 - $62 million) over a fifteen-year period, including the overall pre-tax rate of return on such costs. (d)-(h) See footnotes (d) - (h) to the table under “CECONY Electric,” above. (i) In November 2021, the NYSPSC issued an order that allowed CECONY to recover $7 million of late payment charges and fees that were not billed for the year ended December 31, 2020. The recalculated return on equity for 2020 which reflects the recovery of these fees is 8.56 percent. (j) Amounts reflect amortization of the TCJA allocable to CECONY’s gas customers ($32 million) over a two-year period ($16 million in Yr. 1 and Yr. 2), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s gas customers ($679 million) over the remaining lives of the related assets ($9 million in Yr. 1, $10 million in Yr. 2, and $10 million in Yr. 3) and the unprotected portion of the net regulatory liability ($42 million) over two years ($21 million annually).
CECONY – Steam |  |  |  |
Effective period |  | January 2014 – December 2016 (g) |  | November 2023 – October 2026
Base rate changes |  | Yr. 1 – $(22.4) million (h) Yr. 2 –$19.8 million (h) Yr. 3 –$20.3 million(h) Yr. 4 – None Yr. 5 – None Yr. 6 – None Yr. 7 – None Yr. 8 – None Yr. 9 - None Yr.10 - None |  | Yr. 1 – $110 million (a) Yr. 2 – $44 million (a) Yr. 3 – $45 million (a)
Amortizations to income of net regulatory (assets) and liabilities |  | $37 million over three years |  | Yr. 1 – $15 million (b) Yr. 2 – $3 million (b) Yr. 3 – $3 million (b)
Weather Normalization Adjustment |  |  |  | Implementation of a weather normalization adjustment to reflect normal weather conditions during the heating season.
Recoverable energy costs |  | Current rate recovery of purchased power and fuel costs. |  | Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments |  | Potential charges (up to $1 million annually) if certain performance targets are not met. In years 2014 through 2023, the company did not record any negative revenue adjustments. |  | Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 - $3.7 million Yr. 2 - $3.8 million Yr. 3 - $3.8 million
Regulatory reconciliations (i) (j) |  | In 2014, 2015, 2016, 2017, 2018, 2019, 2020, 2021, 2022 and 2023, the company deferred $42 million of net regulatory liabilities, $17 million of net regulatory assets, $8 million and $14 million of net regulatory liabilities, $1 million of net regulatory assets, $8 million of net regulatory liabilities, $35 million of net regulatory assets, $32 million of net regulatory assets, $11 million of net regulatory assets and $18 million net regulatory liabilities, respectively. |  | Reconciliation of uncollectible expenses and late payment charges (c) and expenses for pension and other postretirement benefits, variable-rate debt, property taxes (d), municipal infrastructure support costs (e), the impact of new laws and environmental site investigation and remediation to amounts reflected in rates. (f)
Net utility plant reconciliations |  | Target levels reflected in rates 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 in 2014 and immaterial amounts in 2015 and 2016 and no deferrals were recorded in 2017, 2018, 2019. In 2020 and 2021, the company deferred $2 million and $1 million as a regulatory liability, respectively. In 2022, the company deferred $0.1 million as a regulatory asset. No deferral was recorded in 2023. |  | Yr. 1 - $2,025 million Yr. 2 - $2,029 million Yr. 3 - $2,015 million
Average rate base |  | Yr. 1 – $1,511 million Yr. 2 – $1,547 million Yr. 3 – $1,604 million |  | Yr. 1 - $1,799 million Yr. 2 - $1,848 million Yr. 3 - $1,882 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 - 6.78 percent Yr. 2 - 6.81 percent Yr. 3 - 6.83 percent
Authorized return on common equity |  | 9.3 percent |  | 9.25 percent
Actual return on common equity (j) |  | Yr. 1 – 9.82 percent Yr. 2 – 10.88 percent Yr. 3 – 10.54 percent Yr. 4 – 9.51 percent Yr. 5 – 11.73 percent Yr. 6 – 10.45 percent Yr. 7 – 7.91 percent Yr. 8 – 5.99 percent Yr. 9 - 5.72 percent Yr. 10 - (0.10) 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. In 2018, actual earnings were $16.5 million above the threshold, and an additional $1.1 million related to 2017 was recorded. In 2019 actual earnings were $5 million above the threshold, offset in part by an adjustment related to 2018 of $2.3 million. In 2020, 2021, 2022 and 2023, the company had no earnings sharing above the threshold. Reserve adjustments of $0.4 million and $0.2 million were recorded in 2021 related to potential adjustment to the excess earnings sharing amounts for 2016 and 2018, respectively. |  | Most earnings above an annual earnings threshold of 9.75 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year.
Cost of long-term debt |  | Yr. 1 – 5.17 percent Yr. 2 – 5.23 percent Yr. 3 – 5.39 percent |  | Yr. 1 – 4.51 percent Yr. 2 – 4.58 percent Yr. 3 – 4.62 percent
Common equity ratio |  | 48 percent |  | 48 percent
(a)The base rate increases will be implemented with increases of $77.8 million in Yr. 1; $77.8 million in Yr. 2; and $77.8 million in Yr. 3 to levelize the customer bill impact. New rates were effective as of November 1, 2023. CECONY began billing customers at the new levelized rate in December 2023. (b)Amounts reflect amortization of the tax savings under the federal Tax Cuts and Jobs Act of 2017 (TCJA) for the unprotected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s steam customers (the entire $24 million in Yr.1), the protected portion of the regulatory liability for excess deferred income taxes allocable to CECONY’s steam customers over the remaining lives of the related assets ($3 million in Yr. 1; $5 million in Yr. 2; and $6 million in Yr. 3) and the non-plant portion of the regulatory asset for deficient deferred income taxes allocable to CECONY’s steam customers (the entire $11 million in Yr.1). (c)CECONY will defer the difference between its actual write-offs of uncollectible expenses and late payment fees (from January 1, 2020 through October 31, 2026) to amounts reflected in rates, with recovery/refund from or to customers via surcharge/sur-credit. Surcharge recoveries for write-offs of uncollectible expenses and late payment fees will each be subject to an annual cap that produces no more than a half percent (0.5 percent) total customer bill impact (estimated to be $2.5 million, $3.0 million, $3.5 million for Yr. 1, Yr. 2 and Yr. 3, respectively). Amounts in excess of the annual surcharge cap in a specific year may be rolled forward for recovery and will count towards the following year’s surcharge cap. Amounts in excess of the surcharge cap will be deferred as a regulatory asset for recovery in CECONY’s next steam base rate case. (d)Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity (Yr. 1 – 10.0 basis points; Yr. 2 – 7.5 basis points; and Yr. 3 – 5.0 basis points), with recovery/refund from or to customers via surcharge/sur-credit. Surcharge recoveries will be subject to an annual cap that produces no more than a half percent (0.5 percent) total customer bill impact (estimated to be $2.5 million, $3.0 million, $3.5 million for Yr. 1, Yr. 2 and Yr. 3, respectively). Amounts in excess of the annual surcharge cap in a specific year may be rolled forward for recovery and will count towards the following year’s surcharge cap. Amounts in excess of the surcharge cap will be deferred as a regulatory asset for recovery in CECONY’s next steam base rate case. (e)In general, if actual expenses for municipal infrastructure support (other than company labor) are below the amounts reflected in rates, CECONY will defer the difference for credit to customers, and if the actual expenses are above the amount reflected in rates, CECONY will defer for recovery from customers 80 percent of the difference subject to a maximum deferral, subject to certain conditions, of 30 percent of the amount reflected in the rate plan. (f)In addition, the NYSPSC continues its focused operations audit to investigate CECONY's income tax accounting. Any NYSPSC ordered adjustment to CECONY’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (g)Rates determined pursuant to this rate plan continued to be in effect until October 31, 2023. 2023 or Yr. 10 represents a partial year commencing January 1, 2023 through October 31, 2023. (h)The impact of these base rate changes was deferred which resulted in an $8 million regulatory liability at December 31, 2016. (i)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. (j)Calculated in accordance with the earnings calculation method prescribed in the rate order. Pursuant to the CECONY 2023-2026 steam rate plan, CECONY may file petitions for approval of future decarbonization projects and may defer/capitalize up to $3 million in total incremental operation and maintenance and/or capital costs for preliminary work on future decarbonization projects until there is a NYSPSC order on cost recovery.
O&R New York – Electric |  |  |  |
Effective period (a) |  | January 2019 – December 2021 |  | January 2022 – December 2024
Base rate changes |  | Yr. 1 – $13.4 million (a) Yr. 2 – $8.0 million (a) Yr. 3 – $5.8 million (a) |  | Yr. 1 – $4.9 million (h) Yr. 2 – $16.2 million (h) Yr. 3 – $23.1 million (h)
Amortizations to income of net regulatory (assets) and liabilities |  | Yr. 1 – $(1.5) million (b) Yr. 2 – $(1.5) million (b) Yr. 3 – $(1.5) million (b) |  | Yr. 1 – $11.8 million (i) Yr. 2 – $13.5 million (i) Yr. 3 – $15.2 million (i)
Other revenue sources |  | Potential earnings adjustment mechanism incentives for peak reduction, energy efficiency, Distributed Energy Resources utilization and other potential incentives of up to: Yr. 1 - $3.6 million Yr. 2 - $4.0 million Yr. 3 - $4.2 million Potential incentive if performance target related to customer service is met: $0.5 million annually. In 2019, 2020 and 2021, the company recorded $2.6 million, $1.9 million and $1.8 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2019 and 2020, the company recorded $0.2 million and $0.5 million of incentives for customer service, respectively. In 2021, the company did not record incentives for customer service. In 2021, the company reversed the $0.5 million of incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. |  | Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $3.3 million Yr. 2 – $2.3 million Yr. 3 – $4.0 million In 2022 and 2023, the company recorded $2.7 million and $1.5 million of earnings adjustment mechanism incentives for energy efficiency, respectively.
Revenue decoupling mechanisms |  | Continuation of reconciliation of actual to authorized electric delivery revenues. In 2019 and 2020, the company deferred $0.1 million and $6 million regulatory assets, respectively. In 2021, $10 million was deferred as regulatory liabilities. |  | Continuation of reconciliation of actual to authorized electric delivery revenues. In 2022 and 2023, the company deferred $6.9 million and $3.4 million regulatory assets respectively.
Recoverable energy costs |  | Continuation of current rate recovery of purchased power costs. |  | Continuation of current rate recovery of purchased power and fuel costs.
Negative revenue adjustments |  | Potential charges if certain performance targets relating to service, reliability and other matters are not met: Yr. 1 - $4.4 million Yr. 2 - $4.4 million Yr. 3 - $4.5 million In 2019,2020 and 2021, the company did not record any negative revenue adjustments. |  | Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $4.3 million Yr. 2 – $4.4 million Yr. 3 – $5.1 million In 2022 and 2023, the company did not record any negative revenue adjustments.
Regulatory reconciliations |  | Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (c), energy efficiency program (d), major storms, the impact of new laws and certain other costs to amounts reflected in rates (e). In 2019, 2020 and 2021, the company deferred $4.3 million, $30.3 million and $24 million as net regulatory assets, respectively. |  | Reconciliation of late payment charges (k) and reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (c), energy efficiency program (j), major storms, uncollectible expenses and certain other costs to amounts reflected in rates (e). In 2022 and 2023, the company deferred $9.4 million and $15.4 million as net regulatory liabilities, respectively.
Net utility plant reconciliations |  | Target levels reflected in rates were: Electric average net plant target excluding advanced metering infrastructure (AMI): Yr. 1 - $1,008 million Yr. 2 - $1,032 million Yr. 3 - $1,083 million AMI (f): Yr. 1 - $48 million Yr. 2 - $58 million Yr. 3 - $61 million The company increased regulatory asset by an immaterial amount in 2019, $0.4 million as a regulatory liability in 2020 and an immaterial amount as a regulatory liability in 2021. |  | Target levels reflected in rates: Electric average net plant target Yr. 1 – $1,175 million Yr. 2 – $1,198 million Yr. 3 – $1,304 million The company increased regulatory asset/liabilities by an immaterial amount in 2022 and 2023.
Average rate base |  | Yr. 1 – $878 million Yr. 2 – $906 million Yr. 3 – $948 million |  | Yr. 1 – $1,021 million Yr. 2 – $1,044 million Yr. 3 – $1,144 million
Weighted average cost of capital (after-tax) |  | Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent |  | Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent
Authorized return on common equity |  | 9.0 percent |  | 9.2 percent
Actual return on common equity (g) |  | Yr. 1 – 9.6 percent Yr. 2 – 8.76 percent Yr. 3 – 9.16 percent |  | Yr. 1 – 8.96 percent Yr. 2 - 8.73 percent
Earnings sharing |  | Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019, 2020 and 2021, earnings did not exceed the earnings threshold. |  | Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2022 and 2023, earnings did not exceed the earnings threshold.
Cost of long-term debt |  | Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent |  | Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent
Common equity ratio |  | 48 percent |  | 48 percent
(a)The electric base rate increases were implemented with increases of: Yr. 1 - $8.6 million; Yr. 2 - $12.1 million; and Yr. 3 - $12.2 million. (b)Reflects amortization of, among other things, the company’s net benefits under the TCJA prior to January 1, 2019, amortization of net regulatory liability for future income taxes and reduction of previously incurred regulatory assets for environmental remediation costs. Also reflects amortization over a six year period of previously incurred incremental major storm costs. (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 maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points. (d)Energy efficiency costs are expensed as incurred. Such costs are subject to a downward-only reconciliation over the terms of the electric and gas rate plans. The company will defer for the benefit of customers any cumulative shortfall over the terms of the electric and gas rate plans between actual expenditures and the levels provided in rates. (e)In addition, the NYSDPS continues its focused operations audit to investigate O&R’s income tax accounting. Any NYSPSC ordered adjustment to O&R’s income tax accounting is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. (f)Net plant reconciliation for AMI expenditures will be implemented for a single category of AMI capital expenditures that includes amounts allocated to both electric and gas customers. (g)Calculated in accordance with the earnings calculation method prescribed in the rate order. (h)The base rate changes will be implemented with increases of: Yr. 1 - $11.7 million; Yr. 2 - $11.7 million; and Yr. 3 - $11.7 million. (i)Reflects amortization of, among other things, previously incurred incremental deferred storm costs over a five-year period. (j)Energy efficiency costs are expensed as incurred. Such costs are subject to a cumulative reconciliation that is evenly distributed over the term of the rate plan subject to the caps set forth in the January 2020 NYSPSC New Efficiency New York (“NENY”) order. If the NYSPSC modifies O&R's NENY budgets during the rate term, such modifications will be reflected at the time of the cumulative reconciliations. (k)The rate plan includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over three years ($2.2 million); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. In January 2024, O&R filed a request with the NYSPSC for an increase in the rates it charges for electric service rendered in New York, effective January 1, 2025, of $18.1 million. The filing reflects a return on common equity of 10.25 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased power, and the reconciliation of actual expenses allocable to the electric business to the amounts for such costs reflected in electric rates for storm costs, uncollectible expense, pension and other postretirement benefit costs, environmental remediation and property taxes and recovery from customers for proposed climate change resilience investments.
O&R New York – Gas |  |  |  |
Effective period |  | January 2019 – December 2021 |  | January 2022 – December 2024
Base rate changes |  | Yr. 1 – $(7.5) million (a) Yr. 2 – $3.6 million (a) Yr. 3 – $0.7 million (a) |  | Yr. 1 – $0.7 million (h) Yr. 2 – $7.4 million (h) Yr. 3 – $9.9 million (h)
Amortization to income of net regulatory (assets) and liabilities |  | Yr. 1 – $1.8 million (b) Yr. 2 – $1.8 million (b) Yr. 3 – $1.8 million (b) |  | Yr. 1 – $0.8 million Yr. 2 – $0.7 million Yr. 3 – $0.3 million
Other revenue sources |  | Continuation of retention of annual revenues from non-firm customers of up to $4.0 million, with variances to be shared 80 percent by customers and 20 percent by company. Potential earnings adjustment mechanism incentives of up to $0.3 million annually. Potential incentives if performance targets related to gas leak backlog, leak prone pipe, emergency response, damage prevention and customer service are met: Yr. 1 - $1.2 million; Yr. 2 - $1.3 million; and Yr. 3 - $1.3 million. In 2019, 2020 and 2021, the company recorded $0.5 million of earnings adjustment mechanism incentives for energy efficiency. In 2019, 2020 and 2021, the company recorded $0.7 million, $0.3 million and $0.2 million of positive incentives, respectively. In 2021, the company reversed $0.3 million of positive incentives recorded in 2020 pursuant to the October 2021 Joint Proposal. |  | Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 - $0.2 million Yr. 2 - $0.2 million Yr. 3 - $0.4 million Potential positive rate adjustment for gas safety and performance of up to: Yr. 1 – $1.2 million Yr. 2 – $1.3 million Yr. 3 – $1.4 million In 2022 and 2023, the company recorded $0.2 million and immaterial amounts of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2022 and 2023, the company recorded $0.2 million and $0.2 million of positive incentives, respectively.
Revenue decoupling mechanisms |  | Continuation of reconciliation of actual to authorized gas delivery revenues. In 2019 and 2020, the company deferred $0.8 million and $0.5 million as regulatory assets, respectively. In 2021, $4 million was deferred as a regulatory liability. |  | Continuation of reconciliation of actual to authorized gas delivery revenues. In 2022 and 2023, the company deferred $2.0 million and $7.6 million as regulatory assets, respectively.
Recoverable energy costs |  | Continuation of current rate recovery of purchased gas costs. |  | Continuation of current rate recovery of purchased gas costs.
Negative revenue adjustments |  | Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 - $5.5 million; Yr. 2 - $5.7 million; and Yr. 3 - $6.0 million. In 2019, the company recorded a $0.2 million. In 2020 and 2021, the company recorded an immaterial amount of negative revenue adjustments. |  | Potential charges if performance targets relating to service, safety and other matters are not met: Yr. 1 – $6.3 million Yr. 2 – $6.7 million Yr. 3 – $7.3 million In 2022 and 2023, the company recorded $0.1 million and immaterial amounts of negative revenue adjustments, respectively.
Regulatory reconciliations |  | Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (c), energy efficiency program (d), the impact of new laws and certain other costs to amounts reflected in rates (e). In 2019 and 2020, the company deferred $6 million as net regulatory liabilities, $1.8 million as net regulatory assets, respectively. In 2021 $8 million were deferred as regulatory assets. |  | Reconciliation of late payment charges (k) and reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (i), energy efficiency program (j), major storms, uncollectible expenses and certain other costs to amounts reflected in rates. In 2022 and 2023, the company deferred $3.4 million and $12.1 million as net regulatory assets/liabilities, respectively.
Net utility plant reconciliations |  | Target levels reflected in rates were: Gas average net plant target excluding AMI: Yr. 1 - $593 million Yr. 2 - $611 million Yr. 3 - $632 million AMI (g): Yr. 1 - $20 million Yr. 2 - $24 million Yr. 3 - $25 million In 2019, 2020 and 2021, the company deferred immaterial amounts as regulatory assets. |  | Target levels reflected in rates: Gas average net plant target Yr. 1 – $720 million Yr. 2 – $761 million Yr. 3 – $803 million In 2022 and 2023, the company deferred immaterial amounts as regulatory assets/liabilities.
Average rate base |  | Yr. 1 – $454 million Yr. 2 – $476 million Yr. 3 – $498 million |  | Yr. 1 – $566 million Yr. 2 – $607 million Yr. 3 – $694 million
Weighted average cost of capital (after-tax) |  | Yr. 1 – 6.97 percent Yr. 2 – 6.96 percent Yr. 3 – 6.96 percent |  | Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent
Authorized return on common equity |  | 9.0 percent |  | 9.2 percent
Actual return on common equity (h) |  | Yr. 1 – 8.90 percent Yr. 2 – 9.58 percent Yr. 3 – 10.11 percent |  | Yr. 1 - 10.01 percent Yr. 2 - 10.40 percent
Earnings sharing |  | Most earnings above an annual earnings threshold of 9.6 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2019 and 2020, earnings did not exceed the earnings threshold. In 2021, actual earnings were $1.7 million above the threshold. |  | Most earnings above an annual earnings threshold of 9.7 percent are to be applied to reduce regulatory assets for environmental remediation and other costs accumulated in the rate year. In 2022 and 2023, actual earnings were $1.1 million and $2.8 million above the threshold, respectively.
Cost of long-term debt |  | Yr. 1 – 5.17 percent Yr. 2 – 5.14 percent Yr. 3 – 5.14 percent |  | Yr. 1 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent
Common equity ratio |  | 48 percent |  | 48 percent
(a)The gas base rate changes were implemented with changes of: Yr. 1 - $(5.9) million; Yr. 2 - $1.0 million; and Yr. 3 - $1.0 million. (b)-(g) See footnotes (c) - (h) to the table under “O&R New York - Electric,” above. (h) The base rate changes will be implemented with increases of: Yr. 1 – $4.4 million; Yr. 2 - $4.4 million; and Yr. 3 - $4.4 million. (i) Deferrals for property taxes are limited to 90 percent of the difference from amounts reflected in rates, subject to an annual maximum for the remaining difference of not more than a maximum number of basis points impact on return on common equity: Yr. 1 - 10.0 basis points; Yr. 2 - 7.5 basis points; and Yr. 3 - 5.0 basis points. (j) See footnote (j) to the table under "O&R New York - Electric," above. (k) The rate plan includes certain COVID-19 provisions, such as: recovery of 2020 late payment charges over three years ($0.6 million); reconciliation of late payment charges to amounts reflected in rates for years 2021 through 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity; and reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates from January 1, 2020 through December 31, 2024, with full recovery/refund via surcharge/sur-credit once the annual variance equals or exceeds 5 basis points of return on equity. In January 2024, O&R filed a request with the NYSPSC for an increase in the rates it charges for gas service rendered in New York, effective January 1, 2025, of $14.4 million. The filing reflects a return on common equity of 10.25 percent and a common equity ratio of 50 percent. The filing proposes continuation of the provisions with respect to recovery from customers of the cost of purchased power, and the reconciliation of actual expenses allocable to the gas business to the amounts for such costs reflected in gas rates for uncollectible expense, pension and other postretirement benefit costs, environmental remediation and property taxes. The filing requested a reduction in the service lives of certain gas assets by 15 years in anticipation of the transition from gas to electric that is expected to result from implementation of the CLCPA. Rockland Electric Company (RECO) In December 2021, the NJBPU approved an electric rate increase, effective January 1, 2022, of $9.65 million for RECO. The following table contains a summary of the terms of the distribution rate plans.
RECO |  |  |  |
Effective period |  | February 2020 – December 2021 |  | January 2022
Base rate changes |  | $12 million |  | $9.65 million
Amortization to income of net regulatory (assets) and liabilities |  | $4.8 million over four years. |  | $0.2 million over three years and $9.2 million of deferred storm costs over a three-year period (excluding $2.4 million of costs for Tropical Storm Henri which will be deferred over a three year period in base rates) and continuation of $10 million over 3 years
Recoverable energy costs |  | Current rate recovery of purchased power costs. |  | Current rate recovery of purchased power costs.
Cost reconciliations |  | None |  | Reconciliation of uncollectible accounts, Demand Side Management and Clean Energy Program.
Average rate base |  | $229.9 million |  | $262.8 million
Weighted average cost of capital (after-tax) |  | 7.11 percent |  | 7.08 percent
Authorized return on common equity |  | 9.5 percent |  | 9.6 percent
Actual return on common equity |  | Yr. 1 – 5.4 percent Yr. 2 – 2.3 percent |  | Yr. 1 - 9.6 percent Yr. 2 - 9.7 percent
Cost of long-term debt |  | 4.88 percent |  | 4.74 percent
Common equity ratio |  | 48.32 percent |  | 48.51 percent
Effective July 2021, the NJBPU authorized a conservation incentive program for RECO, that covers all residential and most commercial customers, under which RECO’s actual electric distribution revenues are compared with the authorized distribution revenues and the difference accrued, with interest, for refund to, or recovery from, customers, as applicable. The conservation incentive program is not permitted if RECO’s actual return on equity exceeds the approved base rate filing return on equity by 50 basis points or more. In December 2022, the NJBPU authorized a $47.8 million Infrastructure Investment Program (IIP) over a five-year period (2023 – 2027). RECO’s IIP provides accelerated infrastructure investments to enhance safety, reliability, and resiliency. In October 2023, FERC approved a July 2023 settlement agreement among RECO, the New Jersey Division of Rate Counsel and the NJBPU that resolves all issues set for hearing and increases RECO's annual transmission revenue requirement from $16.9 million to $18.2 million, effective August 30, 2022 through December 31, 2023 and to $20.7 million, effective January 1, 2024. In December 2023, the NJBPU authorized RECO to defer costs of $4.8 million related to major storms that occurred during 2022 and 2023 until RECO’s next base rate case. Infrastructure Investment and Jobs Act In January 2024, CECONY initiated an application for $100 million of federal grants for grid resilience, O&R and RECO jointly initiated an application for $100 million of federal grants for grid resilience, and CECONY, O&R and RECO initiated a joint application for $60 million of federal grants for smart grids under the Infrastructure Investment and Jobs Act (IIJA). Federal grants obtained pursuant to the IIJA are expected to be used to reduce customers’ costs for investments in CECONY’s, O&R’s, and RECO’s electric systems. COVID - 19 Regulatory Matters Due to the COVID-19 pandemic, New York State enacted laws prohibiting New York utilities, including CECONY and O&R, from disconnecting residential customers and small business customers. The Utilities largely suspended service disconnections, certain collection notices, final bill collection agency activity, new late payment charges and certain other fees from March 2020 through December 2021. In November 2021, the NYSPSC issued an order establishing a surcharge recovery mechanism for CECONY to collect late payment charges and fees that were not billed for the years ended December 31, 2020 and 2021. CECONY recorded $62 million and $11 million for electric and gas, respectively, as revenue for the year ended December 31, 2021, as permitted under the accounting rules for regulated utilities. Pursuant to its electric and gas rate plans, O&R recorded late payment charges and fees that were not billed for the years ended December 31, 2020 and December 31, 2021 of $1.7 million and $2 million, respectively, as revenue for the year ended December 31, 2021, as permitted under accounting rules for regulated utilities. In June 2020, the NYSPSC directed CECONY to implement a summer cooling credit program to help mitigate the cost of staying home and operating air conditioning for health-vulnerable low-income customers due to the limited availability of public cooling facilities as a result of the COVID-19 social distancing measures. The $63.4 million cost of the program is being recovered over a five-year period that began January 2021. In 2021, 2022, and 2023, New York implemented various programs providing arrears assistance to utility customers. One program is administered by the State Office of Temporary and Disability Assistance (OTDA) in coordination with the NYSDPS (the OTDA Program). Under the OTDA Program, CECONY and O&R qualify for a refundable tax credit for New York gross-receipts tax equal to the amount of arrears waived by the Utilities in the year that the arrears are certified by the NYSPSC. In addition, the NYSPSC authorized Phase 1 and Phase 2 COVID-19 arrears assistance programs whereby the Utilities were provided with customer credits towards reducing accounts receivable balances (the Phase 1 Order and Phase 2 Order, respectively). A portion of the Phase 1 Order credits were funded by New York State and the remaining Phase 1 Order credit amounts and all Phase 2 Order credit amounts will be recovered by the Utilities via surcharge mechanisms. For the year ended December 31, 2022, CECONY and O&R issued total credits of $359.9 million and $6.1 million, respectively, towards reducing customers’ accounts receivable balances. For the year ended December 31, 2022, the total credits for CECONY were comprised of: $164.5 million pursuant to the New York State funding; $108.4 million pursuant to the Phase 1 Order, that will be recovered via a surcharge mechanism over a four-year period that began September 2022; a $7 million reserve for CECONY; and $80 million in qualified tax credits and payments pursuant to the OTDA Program described above. For the year ended December 31, 2022, the total credits for O&R were comprised of: $1.6 million pursuant to the New York State funding; $3.2 million pursuant to the Phase 1 order, that was recovered via a surcharge mechanism over a one-year period that began September 2022; and $1.3 million in qualified tax credits and payments pursuant to the OTDA Program described above. For the year ended December 31, 2023, CECONY and O&R issued total net credits of $352.3 million and $2.9 million, respectively, towards reducing customers’ accounts receivable balances. For the year ended December 31, 2023, the total credits for CECONY were comprised of: $13.2 million pursuant to the Phase 1 Order; $327.6 million pursuant to the Phase 2 Order that will be recovered via a surcharge mechanism over a ten-year period that began June 2023; and $11.5 million in qualified tax credits and payments pursuant to the OTDA Program described above. For the year ended December 31, 2023, the total credits for O&R were comprised of: $0.1 million pursuant to the Phase 1 Order; $2.1 million pursuant to the Phase 2 Order that will be recovered via a surcharge mechanism over a one-year period that began April 2023; and $0.7 million in qualified tax credits and payments pursuant to the OTDA Program described above. Other Regulatory Matters In October 2023, CECONY and O&R replaced their separate existing customer billing and information systems with a single new customer billing and information system. In April 2023, CECONY filed a petition with the NYSPSC for permission to capitalize incremental costs for the new system above a $421 million limit on capital investments included in CECONY’s 2020 – 2022 electric and gas rate plans. At December 31, 2023, CECONY's incurred costs for the new system were approximately $496 million ($75 million above the $421 million limit in the rate plans), all of which have been capitalized. CECONY cannot predict the NYSPSC’s response to its April 2023 petition and the NYSPSC may prohibit CECONY from capitalizing some or all of the costs above the $421 million limit. O&R's 2022 - 2024 electric and gas rate plans do not include a limit on capitalization of new system costs. In January 2018, the NYSPSC issued an order initiating a focused operations audit of the Utilities’ financial accounting for income taxes. The audit is investigating the Utilities’ inadvertent understatement of a portion, the amount of which may be material, of their calculation of total federal income tax expense for ratemaking purposes. The understatement was related to the calculation of plant retirement-related cost of removal. As a result of such understatement, the Utilities accumulated significant income tax regulatory assets that were not reflected in O&R’s rate plans prior to 2014, CECONY’s electric and gas rate plans prior to 2015 and 2016, respectively, CECONY's steam plans prior to November 2023. This understatement of historical income tax expense materially reduced the amount of revenue collected from the Utilities' customers in the past. As part of the audit, the Utilities plan to pursue a private letter ruling from the Internal Revenue Service (IRS) that is expected to confirm, among other things, that in order to comply with IRS normalization rules, such understatement may not be corrected through a write-down of a portion of the regulatory asset and must be corrected through an increase in future years’ revenue requirements. The regulatory asset ($1,113 million and $18 million for CECONY and O&R, respectively, as of December 31, 2023 and $1,150 million and $22 million for CECONY and O&R, respectively, as of December 31, 2022 and which is not earning a return) is netted against the future income tax regulatory liability on the Companies’ consolidated balance sheet. The Utilities are unable to estimate the amount or range of their possible loss, if any, related to this matter. At December 31, 2023, the Utilities had not accrued a liability related to this matter. Regulatory Assets and Liabilities Regulatory assets and liabilities at December 31, 2023 and 2022 were comprised of the following items:
| Con Edison | CECONY
(Millions of Dollars) | 2023 | 2022 | 2023 | 2022
Regulatory assets |  |  |  |
Environmental remediation costs | $1,105 | $991 | $1,022 | $906
System peak reduction and energy efficiency programs (a) | 1,057 | 783 | 1,038 | 780
COVID - 19 pandemic deferrals (b) | 789 | 396 | 782 | 389
Revenue taxes | 476 | 436 | 455 | 417
Deferred storm costs (c) | 206 | 270 | 115 | 173
Property tax reconciliation (d) | 169 | 121 | 169 | 121
Deferred derivative losses - long term | 163 | 31 | 148 | 26
Electric vehicle make ready (e) | 73 | 33 | 68 | 30
MTA power reliability deferral (f) | 61 | 92 | 61 | 92
Pension and other postretirement benefits deferrals | 48 | 279 | 39 | 240
Gas service line deferred costs | 43 | 99 | 43 | 99
Legacy meters | 17 | 20 | — | —
Unrecognized pension and other postretirement costs (g) | — | 78 | — | 78
Other | 400 | 345 | 374 | 318
Regulatory assets – noncurrent | 4,607 | 3,974 | 4,314 | 3,669
Deferred derivative losses - short term | 269 | 184 | 253 | 178
Recoverable energy costs | 12 | 121 | 1 | 108
Regulatory assets – current | 281 | 305 | 254 | 286
Total Regulatory Assets | $4,888 | $4,279 | $4,568 | $3,955
Regulatory liabilities |  |  |  |
Future income tax* | $1,535 |  | $1,753 |  | $1,404 |  | $1,616 |
Allowance for cost of removal less salvage (h) | 1,456 | 1,315 | 1,266 | 1,137
Unrecognized pension and other postretirement costs (g) | 943 | 1,638 | 867 | 1,536
Pension and other postretirement benefit deferrals | 284 | 144 | 233 | 98
Net unbilled revenue deferrals | 278 | 204 | 278 | 204
2022 and 2023 late payment charge deferral | 167 | 127 | 161 | 123
System benefit charge carrying charge | 92 | 73 | 88 | 69
Deferred derivative gains - long term | 49 | 145 | 49 | 130
Net proceeds from sale of property | 48 | 69 | 47 | 69
Settlement of prudence proceeding (i) | 11 | 10 | 11 | 10
Other | 465 | 549 | 414 | 489
Regulatory liabilities – noncurrent | 5,328 | 6,027 | 4,818 | 5,481
Deferred derivative gains - short term | 74 | 311 | 71 | 287
Refundable energy costs | 71 | 34 | 36 | —
Revenue decoupling mechanism | — | 29 | — | 21 |
Regulatory liabilities—current | 145 | 374 | 107 | 308
Total Regulatory Liabilities | $5,473 | $6,401 | $4,925 | $5,789
* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L. (a) System Peak Reduction and Energy Efficiency Programs represent programs designed to increase energy efficiency achievements through a combination of responding to locational needs, bundling offerings, leveraging market-based approaches through market solicitations, time-variant pricing and other market transformation efforts. (b) COVID - 19 Deferrals include (1) the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY, (2) amounts related to the increase in the allowance for uncollectible accounts resulting from the COVID-19 pandemic and New York on PAUSE and related executive orders, for electric and gas operations for CECONY and electric operations for O&R, (3) deferrals under CECONY and O&R's electric and gas rate plans for the reconciliation of write-offs of customer accounts receivable balances to amounts reflected in rates a nd (4) deferral related to the arrears relief programs. Amounts deferred under the arrears relief programs were $398.6 million and $2.1 million for CECONY and O&R at December 31, 2023, respectively, and $93.5 million and $2.6 million at December 31, 2022, respectively, and receive a return at the pre-tax weighted average cost of capital. (c) Deferred storm costs represent response and restoration costs, other than capital investments, in connection with Tropical Storm Isaias and other major storms that were deferred by the Utilities. (d) Property tax reconciliation represents the amount deferred between actual property taxes incurred and the level included in rates subject to the provisions of the respective rate plans. (e) Supports the development of electric infrastructure and equipment necessary to accommodate an anticipated increase in the deployment of electric vehicles within New York State. (f) MTA power reliability deferral represents CECONY’s costs in excess of those reflected in its prior electric rate plan to take certain actions relating to the electrical equipment that serves the Metropolitan Transportation Authority (MTA) subway system. The company is recovering this regulatory asset pursuant to its current electric rate plan. See footnote (d) to the CECONY - Electric table under “Rate Plans,” above. (g) Unrecognized pension and other postretirement costs represent the net regulatory liability associated with the accounting rules for retirement benefits. See "Pension and Other Postretirement Benefits" in Note A. (h) Allowance for cost of removal less salvage represents cash previously collected from customers to fund future anticipated removal expenditures. (i) Settlement of prudence proceeding represents the remaining amount to be credited to customers pursuant to a Joint Proposal, approved by the NYSPSC in April 2016, with respect to the prudence of certain CECONY expenditures and related matters. The NYSPSC has authorized CECONY to accrue unbilled electric, gas and steam revenues. CECONY has deferred the differences between unbilled revenues and energy costs for the future benefit of customers by recording a regulatory liability of $278 million and $204 million at December 31, 2023 and 2022, respectively. In general, the Utilities receive or are being credited with a return at the Other Customer-Provided Capital rate for regulatory assets that have not been included in rate base, and receive or are being credited with a return at the pre-tax weighted average cost of capital once the asset is included in rate base. Similarly, the Utilities pay to or credit customers with a return at the Other Customer-Provided Capital rate for regulatory liabilities that have not been included in rate base, and pay to or credit customers with a return at the pre-tax weighted average cost of capital once the liability is included in rate base. The Other Customer-Provided Capital rate for the years ended December 31, 2023 and 2022 was 5.20 percent and 1.75 percent, respectively. In general, the Utilities are receiving or being credited with a return on their regulatory assets for which a cash outflow has been made ($2,541 million and $2,304 million for Con Edison, and $2,359 million and $2,097 million for CECONY at December 31, 2023 and 2022, respectively). Regulatory assets of RECO for which a cash outflow has been made ($24 million and $21 million at December 31, 2023 and 2022, respectively) are not receiving or being credited with a return. RECO recovers regulatory assets over a period of up to four years or until they are addressed in its next base rate case in accordance with the rate provisions approved by the NJBPU. Regulatory liabilities are treated in a consistent manner. Regulatory assets that represent future financial obligations and were deferred in accordance with the Utilities’ rate plans or orders issued by state regulators do not earn a return until such time as a cash outlay has been made. Regulatory liabilities are treated in a consistent manner. At December 31, 2023 and 2022, regulatory assets for Con Edison and CECONY that did not earn a return consisted of the following items: Regulatory Assets Not Earning a Return*
| Con Edison | CECONY
(Millions of Dollars) | 2023 | 2022 | 2023 | 2022
Unrecognized pension and other postretirement costs | $— | $78 | $— | $78
Environmental remediation costs | 1,105 | 987 | 1,022 | 903
Revenue taxes | 490 | 414 | 470 | 397
Deferred derivative losses - long term | 163 | 31 | 148 | 26
COVID-19 deferral for uncollectible accounts receivable | 291 | 253 | 288 | 249
Other | 29 | 28 | 28 | 27
Deferred derivative losses - current | 269 | 184 | 253 | 178
Total | $2,347 | $1,975 | $2,209 | $1,858
*This table presents regulatory assets not earning a return for which no cash outlay has been made. The recovery periods for regulatory assets for which a cash outflow has not been made and that do not earn a return have not yet been determined, except as noted below, and are expected to be determined pursuant to the Utilities’ future rate plans to be filed or orders issued by the state regulators in connection therewith. The Utilities recover unrecognized pension and other postretirement costs over 10 years, and the portion of investment gains or losses recognized in expense over 15 years, pursuant to NYSPSC policy. The deferral for revenue taxes represents the New York State metropolitan transportation business tax surcharge on the cumulative temporary differences between the book and tax basis of assets and liabilities of the Utilities, as well as the difference between taxes collected and paid by the Utilities to fund mass transportation. The Utilities recover the majority of the revenue taxes over the remaining book lives of the electric and gas plant assets, as well as the steam plant assets for CECONY. The Utilities recover deferred derivative losses – current within one year, and noncurrent generally within three years. Electricity and Gas Purchase Agreements The Utilities have electricity purchase agreements with non-utility generators and others for generating capacity and gas purchase agreements for natural gas supply, transportation and storage. The Utilities recover their purchased power and gas costs in accordance with provisions approved by the applicable state public utility regulators. See “Recoverable Energy Costs” in Note A. The Utilities also conducted auctions and have entered into various other electricity and gas purchase agreements. Assuming performance by the parties to the electricity purchase agreements, the Utilities are obligated over the terms of the agreements to make capacity and other fixed payments. The future capacity and other fixed payments under the electricity and gas purchase agreements are estimated to be as follows:
(Millions of Dollars) | 2024 |  | 2025 |  | 2026 |  | 2027 |  | 2028 |  | All Years Thereafter
Con Edison |  |  |  |  |  |  |  |  |  |  |
Electricity power purchase agreements | $155 |  | $89 |  | $59 |  | $44 |  | $44 |  | $346
Natural gas | 299 |  | 10 |  | 11 |  | 7 |  | — |  | —
Gas transportation and storage | 521 |  | 486 |  | 460 |  | 409 |  | 301 |  | 2,682
CECONY |  |  |  |  |  |  |  |  |  |  |
Electricity power purchase agreements | 151 |  | 85 |  | 58 |  | 44 |  | 44 |  | 346
Natural gas | 258 |  | 9 |  | 9 |  | 6 |  | — |  | —
Gas transportation and storage | 450 |  | 420 |  | 398 |  | 353 |  | 259 |  | 2,311
For energy delivered and gas purchased under most of the electricity and gas purchase agreements, the Utilities are obligated to pay variable prices. The company’s payments under the significant terms of the agreements for capacity, energy, gas transportation and storage, and other fixed payments in 2023, 2022 and 2021 were as follows:
| For the Years Ended December 31,
(Millions of Dollars) | 2023 |  | 2022 |  | 2021
Con Edison |  |  |  |  |
Astoria Generating Company (a) | $40 |  | $45 |  | $20
Brooklyn Navy Yard (b) | 134 |  | 165 |  | 139
Gas Transportation and Storage (c) | 372 |  | 386 |  | 393
Total | $546 |  | $596 |  | $552
CECONY |  |  |  |  |
Astoria Generating Company (a) | $40 |  | $45 |  | $20
Brooklyn Navy Yard (b) | 134 |  | 165 |  | 139
Gas Transportation and Storage (c) | 327 |  | 340 |  | 347
Total | $501 |  | $550 |  | $506
(a) Capacity purchase agreements with terms ending in 2023 through 2025. (b) Contract for plant output, which started in 1996 and ends in 2036. (c) Contracts for various counterparties and terms extending through 2044.

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