XML 52 R24.htm IDEA: XBRL DOCUMENT
v3.25.0.1

Regulatory Matters | 12 Months Ended
--- | ---
Dec. 31, 2024
Regulated Operations [Abstract] |
Regulatory Matters | 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: Base Rates are designed to recover core costs of providing electric, gas or steam delivery service such as the costs of constructing, operating and maintaining a service’s system. 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 that 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 (including late payment charges and write-offs of customer accounts receivable balances) 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 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). 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). The Brooklyn Clean Energy Hub primarily addresses an identified reliability need in 2028 due to a forecasted increase in electric demand. Construction began in September 2023 and is expected to be completed by 2028. CECONY’s January 2025 electric rate case filing reflected the costs for the Brooklyn Clean Energy Hub 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 (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. CECONY's January 2025 electric rate case filing reflected the costs for the Idlewild Project in base rates. In January 2025, CECONY filed a request with the NYSPSC for an electric rate increase of $1,612 million, effective January 1, 2026. The filing reflects a return on common equity of 10.1 percent and a common equity ratio of 48 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a continued reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased power and fuel costs from customers. The filing includes supplemental information regarding electric rate plans for 2027 and 2028, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $932 million and $880 million effective January 2027 and 2028, respectively, were calculated based upon an assumed return on common equity of 10.1 percent and a common equity ratio of 48 percent.
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). In January 2025, CECONY filed a request with the NYSPSC for a gas rate increase of $441 million, effective January 1, 2026. The filing reflects a return on common equity of 10.1 percent and a common equity ratio of 48 percent. The company is requesting provisions pursuant to which expenses for pension and other post-retirement benefits, long-term debt, storm restoration, property taxes, municipal infrastructure support, the impact of new laws, late payment charges, and environmental site investigation and remediation are reconciled to amounts reflected in rates. In addition, the company is proposing a continued reconciliation and current recovery or surcharge mechanism of uncollectible write-offs to the level in rates. The company is proposing the continuation of earnings opportunities from Earnings Adjustment Mechanisms for meeting energy efficiency goals. The filing also reflects continuation of the revenue decoupling mechanism and the provisions pursuant to which the company recovers its purchased gas costs from customers. The filing includes supplemental information regarding gas rate plans for 2027 and 2028, which the company is not requesting, but would consider through settlement discussions. For purposes of illustration, rate increases of $266 million and $166 million effective January 2027 and 2028, respectively, were calculated based upon an assumed return on common equity of 10.1 percent and a common equity ratio of 48 percent.
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. 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 |  | 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. 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 |  |  |  | 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
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 November 2024, RECO filed a petition with the NJBPU for an order authorizing RECO to defer incremental preparation costs of $5 million associated with six storms that occurred during 2023 and 2024 until RECO’s next base rate case. Bill Relief Program In March 2024, CECONY and O&R received $91 million and $9 million, respectively, pursuant to a New York State bill relief program funded by the state that provided a one-time bill credit for electric and gas customers. The program was established to partially offset the costs all customers pay to fund utility energy affordability programs. Other Regulatory Matters In January 2023, CECONY initiated a review of welds on certain gas and steam mains following the company’s discovery of a leak from a gas main weld in Queens, New York. During the course of its review thus far, CECONY discovered a limited number of other non-conforming gas and steam main welds. New York regulations require utilities to perform and record weld films for certain gas and steam main welds. Upon reviewing these films, CECONY determined that in some instances third-party contractors engaged in misconduct by substituting duplicate weld films for different welds, while another third-party contractor had created poor quality weld films. CECONY voluntarily disclosed its initial review and findings to the NYSDPS which, in turn, initiated its own investigation. CECONY also reported the contractors’ misconduct to law enforcement. Given the nature of the non-conforming welds identified, CECONY does not anticipate significant impact to the operation of its gas and steam mains. CECONY continues to investigate this matter, is remediating and monitoring the known non-conforming welds and is cooperating with the NYSDPS on its investigation of this matter. CECONY is unable to estimate the amount or range of its possible loss, if any, related to this matter. At December 31, 2024, CECONY had not accrued a liability related to this matter. In May 2024, the NYSPSC issued an order denying an April 2023 petition by CECONY that requested permission to capitalize costs to implement its new customer billing and information system to the extent those costs exceeded the $421 million cap established in CECONY’s 2020 – 2022 electric and gas rate plans. CECONY’s final costs for the new system were $510 million ($89 million above the $421 million cap in the rate plans). CECONY believes that the incremental costs were both prudent and necessary for the successful deployment of the system for the benefit of its customers. In May 2024, CECONY expensed incremental costs of $51 million for the new system that were previously capitalized, in addition to a $38 million reserve established at December 31, 2023. In June 2024, CECONY filed a petition for rehearing with the NYSPSC. CECONY is unable to predict the NYSPSC's response to its rehearing petition. 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 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 ($1,078 million and $14 million for CECONY and O&R, respectively, as of December 31,2024 and $1,113 million and $18 million for CECONY and O&R, respectively, as of December 31, 2023) which are not earning a return. While the Utilities have properly calculated and paid their federal income taxes and there is no uncertain tax position related to this matter, this understatement of historical income tax expense materially reduced the amount of revenue collected from the Utilities' customers in the past relative to what it should have been. The Utilities’ rate plans have reflected the correct amount of federal income taxes recoverable from customers, including a proportionate recovery of the regulatory asset, beginning with O&R’s rate plans effective November 2015, CECONY’s electric and gas rate plans effective January 2017, and CECONY’s steam plan effective November 2023. As part of the audit, the Utilities plan to pursue a private letter ruling from the Internal Revenue Service (IRS) confirming that the Utilities’ inadvertent understatement of prior years’ income tax expense constitutes a normalization violation that can be cured through an increase in future years’ revenue requirements until such time as the regulatory asset is fully recovered in rates, and not through a write-down of all or a portion of the Utilities’ regulatory asset. Under Accounting Standards Codification Topic (ASC) 740, the Utilities recorded an unfunded deferred federal income tax liability (with a gross-up amount) and a corresponding regulatory asset. The income tax regulatory assets are netted against the related regulatory liability for future income tax and are shown in the line “Future income tax” in the following table of Regulatory Assets and Liabilities and on the Companies’ consolidated balance sheets in the line “Regulatory liabilities.” Management’s assessment is that the income tax regulatory assets as of December 31, 2024 are probable of collection through future rates. The IRS provides safe harbor relief for inadvertent normalization violations through the jurisdictional rate setting process of including in rates adequate revenue to fully recover the deferred tax balance. However, the Utilities would record a liability or impair a portion of the regulatory assets associated with this understatement if the NYSPSC were to issue an order that required the Utilities to write off all or a portion of their existing regulatory asset. The Utilities are unable to estimate the amount or range of their possible loss, if any, related to this matter. At December 31, 2024, the Utilities had not accrued a liability related to this matter. Regulatory Assets and 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. 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 $436 million and $278 million at December 31, 2024 and 2023, 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, 2024 and 2023 was 5.95 percent and 5.20 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 ($3,262 million and $2,541 million for Con Edison, and $3,024 million and $2,359 million for CECONY at December 31, 2024 and 2023, respectively). Regulatory assets of RECO for which a cash outflow has been made ($28 million and $24 million at December 31, 2024 and 2023, 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, 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. 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) | 2025 |  | 2026 |  | 2027 |  | 2028 |  | 2029 |  | All Years Thereafter
Con Edison |  |  |  |  |  |  |  |  |  |  |
Electricity power purchase agreements | $234 |  | $131 |  | $60 |  | $49 |  | $44 |  | $302
Natural gas | 383 |  | 11 |  | 8 |  | — |  | — |  | —
Gas transportation and storage | 510 |  | 497 |  | 450 |  | 376 |  | 212 |  | 2,390
CECONY |  |  |  |  |  |  |  |  |  |  |
Electricity power purchase agreements | 230 |  | 128 |  | 59 |  | 49 |  | 44 |  | 302
Natural gas | 331 |  | 10 |  | 7 |  | — |  | — |  | —
Gas transportation and storage | 445 |  | 434 |  | 394 |  | 329 |  | 185 |  | 2,083
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 2024, 2023 and 2022 were as follows:
| For the Years Ended December 31, |  |  |  |  |  |
(Millions of Dollars) | 2024 |  | 2023 |  | 2022 |  |  |  |  |  |
Con Edison |  |  |  |  |  |  |  |  |  |  |
Astoria Generating Company (a) | $75 |  | $40 |  | $45 |  |  |  |  |  |
Brooklyn Navy Yard (b) | 139 |  | 134 |  | 165 |  |  |  |  |  |
Gas Transportation and Storage (c) | 422 |  | 372 |  | 386 |  |  |  |  |  |
Total | $636 |  | $546 |  | $596 |  |  |  |  |  |
CECONY |  |  |  |  |  |  |  |  |  |  |
Astoria Generating Company (a) | $75 |  | $40 |  | $45 |  |  |  |  |  |
Brooklyn Navy Yard (b) | 139 |  | 134 |  | 165 |  |  |  |  |  |
Gas Transportation and Storage (c) | 372 |  | 327 |  | 340 |  |  |  |  |  |
Total | $586 |  | $501 |  | $550 |  |  |  |  |  |
(a) Capacity purchase agreements with terms ending in 2024 through 2028. (b) Contract for plant output, which started in 1996 and ends in 2036. (c) Contracts for various counterparties and terms extending through 2046.

X
- Definition The entire disclosure for public utilities. + References Reference 1: http://fasb.org/us-gaap/role/ref/legacyRef -Topic 980 -Name Accounting Standards Codification -Publisher FASB -URI https://asc.fasb.org/980/tableOfContent + Details
Name: | us-gaap_PublicUtilitiesDisclosureTextBlock
Namespace Prefix: | us-gaap_
Data Type: | dtr-types:textBlockItemType
Balance Type: | na
Period Type: | duration

X
- References No definition available. + Details
Name: | us-gaap_RegulatedOperationsAbstract
Namespace Prefix: | us-gaap_
Data Type: | xbrli:stringItemType
Balance Type: | na
Period Type: | duration