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Regulatory Matters (Tables) | 12 Months Ended
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Dec. 31, 2024
Regulated Operations [Abstract] |
Summary of Utilities Rate Plans | 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 and 2024, the company recorded $34.4 million and $52.3 million primarily related to earnings adjustment mechanism incentives for energy efficiency, respectively.
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 and 2024, the company deferred for recovery from customers $162 million and $164 million of revenues, respectively.
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 and 2024, 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 and 2024, the company deferred $140 million and $52 million of net regulatory liabilities, respectively.
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 and 2024, the company deferred $1.2 million and $(25.3) million as a regulatory asset and regulatory liability, respectively.
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 Yr. 2 - 9.21 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 and 2024, 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) were 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 financial accounting for income taxes. Any NYSPSC ordered adjustment to CECONY’s financial accounting for income taxes 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).
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 and 2024, the company recorded $5 million and $7 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2023 and 2024, the company recorded positive incentives of $3 million each year, respectively.
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 and 2024, the company deferred for recovery from customers $162 million and $93 million of revenues, 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 – $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 and 2024, the company recorded negative revenue adjustments of $3 million and $2 million, respectively.
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 and 2024, the company deferred $12 million and $29 million of net regulatory liabilities, respectively.
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 and 2024, the company deferred $15.5 million and $31.5 million as regulatory liabilities, respectively.
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 Yr. 2 - 9.82 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. In 2024, the company had $4.3 million 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. The company did not record any negative revenue adjustments under this rate plan. |  | 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 In Yr. 1, the company did not record any negative revenue adjustments.
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) In Yr. 1, the company deferred $7 million of net regulatory assets.
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 In Yr. 1, the company deferred $2.4 million as a regulatory liability.
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 . |  | Yr. 1 – 6.55 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. There were no earnings above the threshold in Yr. 1.
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 financial accounting for income taxes. Any NYSPSC ordered adjustment to CECONY’s financial accounting for income taxes 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 were 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.
O&R New York – Electric |  |  |  |
Effective period |  | January 2022 – December 2024 |  | January 2025 – December 2027 (a)
Base rate changes |  | Yr. 1 – $4.9 million (b) Yr. 2 – $16.2 million (b) Yr. 3 – $23.1 million (b) |  | Yr. 1 – $(13.1) million (c) Yr. 2 – $24.8 million (c) Yr. 3 – $44.1 million (c)
Amortizations to income of net regulatory (assets) and liabilities |  | Yr. 1 – $11.8 million (d) Yr. 2 – $13.5 million (d) Yr. 3 – $15.2 million (d) |  | Yr. 1 – $(4.5) million Yr. 2 – $(5.4) million Yr. 3 – $(6.4) million
Other revenue sources |  | 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, 2023 and 2024, the company recorded $2.7 million, $1.5 million and $2.6 million of earnings adjustment mechanism incentives for energy efficiency, respectively. |  | Potential earnings adjustment mechanism incentives for energy efficiency and other potential incentives of up to: Yr. 1 – $3.9 million Yr. 2 – $4.7 million Yr. 3 – $5.8 million
Revenue decoupling mechanisms |  | Continuation of reconciliation of actual to authorized electric delivery revenues. In 2022, and 2023, the company deferred $6.9 million, $3.4 million as regulatory assets, respectively. In 2024, the company deferred $18.6 million as regulatory liabilities. |  | Continuation of reconciliation of actual to authorized electric delivery 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 and other matters are not met: Yr. 1 - $4.3 million Yr. 2 - $4.4 million Yr. 3 - $5.1 million In 2022, 2023 and 2024, 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 – $7.6 million Yr. 2 – $8.5 million Yr. 3 – $11.5 million
Regulatory reconciliations |  | Reconciliation of late payment charges (e) and reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (f), energy efficiency program (g), major storms, uncollectible expenses and certain other costs to amounts reflected in rates (h). In 2022 and 2023, the company deferred $9.4 million and $15.4 million as net regulatory liabilities, respectively. In 2024, the company deferred $10.2 million as net regulatory assets. |  | Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (f), energy efficiency program (i), major storms, low-income bill credits, uncollectible expenses (j), late payment charges (j), and certain other costs to amounts reflected in rates.
Net utility plant reconciliations |  | 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 did not record any regulatory liabilities in 2022, 2023 and 2024. |  | Target levels reflected in rates: Electric average net plant target Yr. 1 – $1,398 million Yr. 2 – $1,471 million Yr. 3 – $1,737 million
Average rate base |  | Yr. 1 – $1,021 million Yr. 2 – $1,044 million Yr. 3 – $1,144 million |  | Yr. 1 – $1,293 million Yr. 2 – $1,393 million Yr. 3 – $1,646 million
Weighted average cost of capital (after-tax) |  | Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent |  | Yr. 1 – 7.25 percent Yr. 2 – 7.28 percent Yr. 3 – 7.31 percent
Authorized return on common equity |  | 9.2 percent |  | 9.75 percent
Actual return on common equity (k) |  | Yr. 1 – 8.96 percent Yr. 2 – 8.73 percent Yr. 3 – 9.86 percent |  |
Earnings sharing |  | 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. In 2024, actual earnings were 1.2 million above the threshold. |  | Most earnings above an annual earnings threshold of 10.25 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 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent |  | Yr. 1 – 4.95 percent Yr. 2 – 5.01 percent Yr. 3 – 5.08 percent
Common equity ratio |  | 48 percent |  | 48 percent
a.The November 2024 Joint Proposal is subject to NYSPSC approval. b.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. c.The Joint Proposal recommends that these base rate changes may be implemented with no change in Yr. 1 and increases of $17.7 million in each of Yr. 2 and Yr. 3. d.Reflects amortization of, among other things, previously incurred incremental deferred storm costs over a five-year period. e.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. 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 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. g.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. h.In addition, the New York State Department of Public Service (NYSDPS) continues its focused operations audit to investigate O&R’s financial accounting for income taxes. Any NYSPSC ordered adjustment to O&R’s financial accounting for income taxes is expected to be refunded to or collected from customers, as determined by the NYSPSC. See "Other Regulatory Matters," below. i.Energy efficiency costs are deferred as regulatory assets and amortized over a 15-year period. Balances are reconciled to the revenue requirement effect of actual level of cost incurred to the rate plan targets. If the NYSPSC authorizes modified energy efficiency spending budgets over the course of the rate plan, O&R will defer the impact of any variance between the level in rates and the authorized budgets for collection or refund to customers in the next base rate case. j.Reconciliation of uncollectible expenses and late payment charges are subject to a combined annual threshold of $0.9 million. Once the threshold is met, O&R will defer the variance between actual uncollectible expense and late payment charge, and the level set forth in rates that is above the threshold. Recovery/refunds will be made via surcharge/sur-credit. Surcharge recovery is subject to an annual cap that produces no more than a 0.5 percent total customer bill impact. k.Calculated in accordance with the earnings calculation method prescribed in the rate order.
O&R New York – Gas |  |  |  |
Effective period |  | January 2022 – December 2024 |  | January 2025 – December 2027 (a)
Base rate changes |  | Yr. 1 – $0.7 million (b) Yr. 2 – $7.4 million (b) Yr. 3 – $9.9 million (b) |  | Yr. 1 – $3.6 million (c) Yr. 2 – $18.0 million (c) Yr. 3 – $16.5 million (c)
Amortization to income of net regulatory (assets) and liabilities |  | Yr. 1 – $0.8 million Yr. 2 – $0.7 million Yr. 3 – $0.3 million |  | Yr. 1 – $8.4 million Yr. 2 – $8.2 million Yr. 3 – $8.0 million
Other revenue sources |  | 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, 2023 and 2024, the company recorded $0.2 million, immaterial amounts, and $1.4 million of earnings adjustment mechanism incentives for energy efficiency, respectively. In 2022, 2023 and 2024 the company recorded $0.2 million, $0.2 million and $0.3 million of positive incentives, respectively. |  | Potential positive rate adjustment for gas safety and performance of up to: Yr. 1 – $1 million Yr. 2 – $1.1 million Yr. 3 – $1.2 million
Revenue decoupling mechanisms |  | Continuation of reconciliation of actual to authorized gas delivery revenues. In 2022, 2023 and 2024, the company deferred $2 million, $7.6 million and $20.6 million as regulatory assets, respectively. |  | Continuation of reconciliation of actual to authorized gas delivery 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 – $6.3 million Yr. 2 – $6.7 million Yr. 3 – $7.3 million In 2022, the company recorded $0.1 million and immaterial amounts in 2023 and 2024 of negative revenue adjustments, respectively. |  | Potential charges if certain performance targets relating to service, reliability, safety and other matters are not met: Yr. 1 – $8.4 million Yr. 2 – $9.4 million Yr. 3 – $11.1 million
Regulatory reconciliations |  | Reconciliation of late payment charges (d) and reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (e), energy efficiency program (f), 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, respectively. In 2024, the company deferred $5.1 million as net regulatory liabilities. |  | Reconciliation of expenses for pension and other postretirement benefits, environmental remediation costs, property taxes (e), energy efficiency program (g), low-income bill credits, uncollectible expenses (h), late payment charges (h), and certain other costs to amounts reflected in rates.
Net utility plant reconciliations |  | Target levels reflected in rates: Gas average net plant target Yr. 1 – $720 million Yr. 2 – $761 million Yr. 3 – $803 million The company did not record any regulatory liabilities in 2022, 2023 and 2024. |  | Target levels reflected in rates: Gas average net plant target Yr. 1 – $877 million Yr. 2 – $934 million Yr. 3 – $1,010 million
Average rate base |  | Yr. 1 – $566 million Yr. 2 – $607 million Yr. 3 – $694 million |  | Yr. 1 – $720 million Yr. 2 – $791 million Yr. 3 – $863 million
Weighted average cost of capital (after-tax) |  | Yr. 1 – 6.77 percent Yr. 2 – 6.73 percent Yr. 3 – 6.72 percent |  | Yr. 1 – 7.25 percent Yr. 2 – 7.28 percent Yr. 3 – 7.31 percent
Authorized return on common equity |  | 9.2 percent |  | 9.75 percent
Actual return on common equity (i) |  | Yr. 1 - 10.01 percent Yr. 2 - 10.40 percent Yr. 3 – 9.91 percent |  |
Earnings sharing |  | 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, 2023 and 2024, actual earnings were $1.1 million, $2.8 million and $0.9 million above the threshold, respectively. |  | Most earnings above an annual earnings threshold of 10.25 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 – 4.58 percent Yr. 2 – 4.51 percent Yr. 3 – 4.49 percent |  | Yr. 1 – 4.95 percent Yr. 2 – 5.01 percent Yr. 3 – 5.08 percent
Common equity ratio |  | 48 percent |  | 48 percent
(a)The November 2024 Joint Proposal is subject to NYSPSC approval. (b)The gas base rate changes were implemented with increases of: Yr. 1 - $4.4 million; Yr. 2 - $4.4 million; and Yr. 3 - $4.4 million. (c)The Joint Proposal recommends that these base rate changes may be implemented with increases of: Yr. 1 – $10.4 million; Yr. 2 - $10.4 million; and Yr. 3 -$10.4 million. (d)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. (e)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. (f)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 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. (g)Energy efficiency costs are deferred as regulatory assets and amortized over a 15-year period. Balances are reconciled to the revenue requirement effect of actual level of cost incurred to the rate plan targets. If the NYSPSC authorizes modified energy efficiency spending budgets over the course of the rate plan, O&R will defer the impact of any variance between the level in rates and the authorized budgets for collection or refund to customers in the next base rate case. (h)Reconciliation of uncollectible expenses and late payment charges are subject to a combined annual threshold of $0.5 million. Once the threshold is met, O&R will defer the variance between actual uncollectible expense and late payment charge, and the level set forth in rates that is above the threshold. Recovery/refunds will be made via surcharge/sur-credit. Surcharge recovery is subject to an annual cap that produces no more than a 0.5 percent total customer bill impact. (i)Calculated in accordance with the earnings calculation method prescribed in the rate order. The following table contains a summary of the terms of the distribution rate plans.
RECO |  |  |  |
Effective period |  |  |  | January 2022
Base rate changes |  |  |  | $9.65 million
Amortization to income of net regulatory (assets) and liabilities |  |  |  | $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.
Cost reconciliations |  |  |  | Reconciliation of uncollectible accounts, Demand Side Management and Clean Energy Program.
Average rate base |  |  |  | $262.8 million
Weighted average cost of capital (after-tax) |  |  |  | 7.08 percent
Authorized return on common equity |  |  |  | 9.6 percent
Actual return on common equity |  |  |  | Yr. 1 - 9.6 percent Yr. 2 - 9.7 percent Yr. 3 - 8.3 percent
Cost of long-term debt |  |  |  | 4.74 percent
Common equity ratio |  |  |  | 48.51 percent
Schedule of Regulatory Assets | Regulatory assets and liabilities at December 31, 2024 and 2023 were comprised of the following items:
| Con Edison | CECONY
(Millions of Dollars) | 2024 | 2023 | 2024 | 2023
Regulatory assets |  |  |  |
Energy efficiency and other clean energy programs (a) | $1,656 | $1,251 | $1,598 | $1,223
Customer account deferrals (b) | 1,073 | 789 | 1,058 | 782
Environmental remediation costs | 1,038 | 1,105 | 952 | 1,022
Revenue taxes | 540 | 476 | 517 | 455
Legacy meters (c) | 413 | 17 | 398 | —
Deferred storm costs (d) | 147 | 206 | 53 | 115
Property tax reconciliation (e) | 131 | 169 | 131 | 169
Deferred derivative losses - long term | 106 | 163 | 94 | 148
MTA power reliability deferral (f) | 31 | 61 | 31 | 61
Gas service line deferred costs | 18 | 43 | 18 | 43
Pension and other postretirement benefits deferrals | 2 | 48 | 2 | 39
Other | 368 | 279 | 306 | 257
Regulatory assets – noncurrent | 5,523 | 4,607 | 5,158 | 4,314
Deferred derivative losses - short term | 102 | 269 | 92 | 253
Recoverable energy costs | 39 | 12 | 14 | 1
Regulatory assets – current | 141 | 281 | 106 | 254
Total Regulatory Assets | $5,664 | $4,888 | $5,264 | $4,568
Regulatory liabilities |  |  |  |
Allowance for cost of removal less salvage (g) | $1,527 | $1,456 | $1,322 | $1,266
Future income tax* | 1,224 |  | 1,535 |  | 1,112 |  | 1,404 |
Unrecognized pension and other postretirement costs (h) | 1,054 | 943 | 984 | 867
Net unbilled revenue deferrals | 436 | 278 | 436 | 278
Pension and other postretirement benefit deferrals | 368 | 284 | 304 | 233
Late payment charge deferral | 231 | 167 | 224 | 161
System benefit charge carrying charge | 115 | 92 | 110 | 88
Net proceeds from sale of property | 25 | 48 | 24 | 47
Settlement of prudence proceeding (i) | 10 | 11 | 10 | 11
Deferred derivative gains - long term | 8 | 49 | 6 | 49
Other | 446 | 465 | 408 | 414
Regulatory liabilities – noncurrent | 5,444 | 5,328 | 4,940 | 4,818
Refundable energy costs | 59 | 71 | 18 | 36
Deferred derivative gains - short term | 25 | 74 | 22 | 71
Revenue decoupling mechanism | 18 | — | — | — |
Regulatory liabilities—current | 102 | 145 | 40 | 107
Total Regulatory Liabilities | $5,546 | $5,473 | $4,980 | $4,925
* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L. (a) Energy Efficiency and Other Clean Energy Programs represent programs designed to increase energy efficiency achievements and other clean energy transformation efforts. (b) Customer account deferrals include (1) the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY, (2) 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 as well as for increases to the allowance for uncollectible accounts receivable and (3) deferral related to the arrears relief programs. Amounts deferred under the arrears relief programs were $323.7 million and $1.4 million for CECONY and O&R at December 31, 2024, respectively, and $398.6 million and $2.1 million at December 31, 2023, respectively, and receive a return at the pre-tax weighted average cost of capital. (c) Pursuant to their rate plans, CECONY and O&R are recovering the costs of legacy meters over a 15-year period beginning January 1, 2024 and a 12-year period beginning January 1, 2022, respectively. (d) Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Tropical Storm Isaias and other major storms that were deferred by the Utilities. (e) 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. (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) Allowance for cost of removal less salvage represents cash previously collected from customers to fund future anticipated removal expenditures. (h) Unrecognized pension and other postretirement costs represent the deferrals associated with the accounting rules for retirement benefits. See "Pension and Other Postretirement Benefits" in Note A. (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.
Schedule of Regulatory Liabilities | Regulatory assets and liabilities at December 31, 2024 and 2023 were comprised of the following items:
| Con Edison | CECONY
(Millions of Dollars) | 2024 | 2023 | 2024 | 2023
Regulatory assets |  |  |  |
Energy efficiency and other clean energy programs (a) | $1,656 | $1,251 | $1,598 | $1,223
Customer account deferrals (b) | 1,073 | 789 | 1,058 | 782
Environmental remediation costs | 1,038 | 1,105 | 952 | 1,022
Revenue taxes | 540 | 476 | 517 | 455
Legacy meters (c) | 413 | 17 | 398 | —
Deferred storm costs (d) | 147 | 206 | 53 | 115
Property tax reconciliation (e) | 131 | 169 | 131 | 169
Deferred derivative losses - long term | 106 | 163 | 94 | 148
MTA power reliability deferral (f) | 31 | 61 | 31 | 61
Gas service line deferred costs | 18 | 43 | 18 | 43
Pension and other postretirement benefits deferrals | 2 | 48 | 2 | 39
Other | 368 | 279 | 306 | 257
Regulatory assets – noncurrent | 5,523 | 4,607 | 5,158 | 4,314
Deferred derivative losses - short term | 102 | 269 | 92 | 253
Recoverable energy costs | 39 | 12 | 14 | 1
Regulatory assets – current | 141 | 281 | 106 | 254
Total Regulatory Assets | $5,664 | $4,888 | $5,264 | $4,568
Regulatory liabilities |  |  |  |
Allowance for cost of removal less salvage (g) | $1,527 | $1,456 | $1,322 | $1,266
Future income tax* | 1,224 |  | 1,535 |  | 1,112 |  | 1,404 |
Unrecognized pension and other postretirement costs (h) | 1,054 | 943 | 984 | 867
Net unbilled revenue deferrals | 436 | 278 | 436 | 278
Pension and other postretirement benefit deferrals | 368 | 284 | 304 | 233
Late payment charge deferral | 231 | 167 | 224 | 161
System benefit charge carrying charge | 115 | 92 | 110 | 88
Net proceeds from sale of property | 25 | 48 | 24 | 47
Settlement of prudence proceeding (i) | 10 | 11 | 10 | 11
Deferred derivative gains - long term | 8 | 49 | 6 | 49
Other | 446 | 465 | 408 | 414
Regulatory liabilities – noncurrent | 5,444 | 5,328 | 4,940 | 4,818
Refundable energy costs | 59 | 71 | 18 | 36
Deferred derivative gains - short term | 25 | 74 | 22 | 71
Revenue decoupling mechanism | 18 | — | — | — |
Regulatory liabilities—current | 102 | 145 | 40 | 107
Total Regulatory Liabilities | $5,546 | $5,473 | $4,980 | $4,925
* See "Federal Income Tax" in Note A, "Other Regulatory Matters," above, and Note L. (a) Energy Efficiency and Other Clean Energy Programs represent programs designed to increase energy efficiency achievements and other clean energy transformation efforts. (b) Customer account deferrals include (1) the amount to be collected from customers related to the Emergency Summer Cooling Credits program for CECONY, (2) 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 as well as for increases to the allowance for uncollectible accounts receivable and (3) deferral related to the arrears relief programs. Amounts deferred under the arrears relief programs were $323.7 million and $1.4 million for CECONY and O&R at December 31, 2024, respectively, and $398.6 million and $2.1 million at December 31, 2023, respectively, and receive a return at the pre-tax weighted average cost of capital. (c) Pursuant to their rate plans, CECONY and O&R are recovering the costs of legacy meters over a 15-year period beginning January 1, 2024 and a 12-year period beginning January 1, 2022, respectively. (d) Deferred storm costs represent response and restoration costs, other than capital expenditures, in connection with Tropical Storm Isaias and other major storms that were deferred by the Utilities. (e) 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. (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) Allowance for cost of removal less salvage represents cash previously collected from customers to fund future anticipated removal expenditures. (h) Unrecognized pension and other postretirement costs represent the deferrals associated with the accounting rules for retirement benefits. See "Pension and Other Postretirement Benefits" in Note A. (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.
Schedule of Regulatory Assets Not Earning Return | At December 31, 2024 and 2023, 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) | 2024 | 2023 | 2024 | 2023
Environmental remediation costs | $1,037 | $1,105 | $942 | $1,022
Revenue taxes | 567 | 490 | 543 | 470
UB deferral for uncollectible accounts receivable | 551 | 291 | 541 | 288
Deferred derivative losses - long term | 106 | 163 | 94 | 148
Deferred derivative losses - short term | 102 | 269 | 92 | 253
Other | 39 | 29 | 28 | 28
Total | $2,402 | $2,347 | $2,240 | $2,209
*This table presents regulatory assets not earning a return for which no cash outlay has been made.

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