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.