Company: CNLHP
Filing Date: 2025-11-06
Form Type: 10-Q
Source: 0001628280-25-050033
Chunk: 178

Company: CONNECTICUT LIGHT & POWER CO
Filing Date: 2025-11-06
Form: 10-Q
Item: Item 8
Chunk 178
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)Other electric distribution costs50.6 106.2 Natural gas supply costs3.5 140.3 Transmission costs79.3 145.7 Eliminations(2.2)(7.4)Total Purchased Power, Purchased Natural Gas and Transmission$131.4 $213.1 

The variance in energy supply procurement costs is offset in Operating Revenues (tracked energy supply procurement revenues).  The increase in other electric distribution costs for the three month period is due primarily to higher long-term contractual energy-related costs and the cost of renewable energy credits that are recovered in the non-bypassable component of the FMCC mechanism at CL&P, higher stranded costs resulting from lower Regional Greenhouse Gas Initiative (RGGI) proceeds received at PSNH, which are credited back to customers, and an increase in the long-term renewable energy purchase contract cost deferral at NSTAR Electric.

The increase in other electric distribution costs for the nine month period is due primarily to an increase in the long-term renewable energy purchase contract cost deferral and in net metering costs at NSTAR Electric, higher long-term contractual energy-related costs that are recovered in the non-bypassable component of the FMCC mechanism at CL&P, and higher net metering costs at PSNH.

Costs at the natural gas distribution segment relate to supply procurement costs for retail customers.  Total natural gas costs increased for the three month period due primarily to higher average prices and an increase in the retail cost deferral, partially offset by lower average purchased volumes. Total natural gas costs increased for the nine month period due primarily to higher average prices and higher average purchased volumes, partially offset by a decrease in the retail cost deferral.

Included in transmission costs are charges that recover the cost of transporting electricity over high-voltage lines from generation facilities to substations, including costs allocated by ISO-NE to maintain the wholesale electric system.  The increase in transmission costs for the three month period was primarily the result of an increase in costs billed by ISO-NE that support regional grid investments and an increase in Local Network Service charges, which reflect the cost of transmission service provided by Eversource over our local transmission network.  These increases were partially offset by a decrease in the retail transmission cost deferral, which reflects the actual cost of transmission service compared to estimated amounts billed to customers.  The increase in transmission costs for the nine month period is the result of an increase in costs billed by ISO-NE that support regional grid investments, partially offset by a decrease