Company: CNLHP
Filing Date: 2025-02-14
Form Type: 10-K
Source: 0000072741-25-000007
Chunk: 222

Company: CONNECTICUT LIGHT & POWER CO
Filing Date: 2025-02-14
Form: 10-K
Item: Item 7
Chunk 222
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 average of total capital additions.  On December 26, 2023, the DPU approved a $104.9 million increase to NSTAR Electric’s base distribution rates effective January 1, 2024.  

On July 31, 2024, the NHPUC approved a settlement agreement to implement a temporary annual base distribution rate increase of $61.2 million effective August 1, 2024 at PSNH.

NSTAR Gas’ PBR mechanism allows for an annual adjustment to base distribution rates for inflation and exogenous events.  On October 30, 2023, the DPU approved a $25.4 million increase to NSTAR Gas’ base distribution rates, of which, $15.5 million was associated with a base rate adjustment and the remainder for a prior period exogenous cost adjustment, for effect on November 1, 2023.   On October 30, 2024, the DPU approved a $12.7 million increase to NSTAR Gas’ base distribution rates effective November 1, 2024.

EGMA was allowed two rate base resets in a DPU-approved October 7, 2020 rate settlement agreement, with the first rate base reset on November 1, 2024. The increase to base distribution rates was $85.6 million effective November 1, 2024 (of which $8.8 million is offset by a reduction in the GSEP revenue requirement and GSEP rate also taking effect on November 1, 2024 for a net distribution rate change on November 1, 2024 of $76.8 million). 

Tracked Distribution Revenues:  Tracked distribution revenues consist of certain costs that are recovered from customers in retail rates on a fully reconciling basis through regulatory commission-approved cost tracking mechanisms and therefore, recovery of these costs has no impact on earnings.  Costs recovered through cost tracking mechanisms include, among others, energy supply and natural gas supply procurement, state mandated energy purchase agreements and other energy-related costs, electric retail transmission charges, energy efficiency program costs, electric restructuring and stranded cost recovery revenues (including securitized RRB charges), certain capital tracking mechanisms for infrastructure improvements, and additionally for the Massachusetts utilities, pension and PBOP benefits, net metering for distributed generation, and solar-related programs.  Revenues from certain of these cost tracking mechanisms also include certain incentives earned, return on capital tracking mechanisms, and carrying charges that are billed in rates to customers, which do impact earnings.  Tr