Company: AILIM
Filing Date: 2025-05-05
Form Type: 10-Q
Source: 0001002910-25-000098
Chunk: 112

Company: Ameren Illinois Co
Filing Date: 2025-05-05
Form: 10-Q
Item: Part I, Item 1
Chunk 112
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 liability related to the Rush Island Energy Center since its October 15, 2024 retirement date. The regulatory liability will be refunded through base rates, effective June 1, 2025, as a result of the April 2025 MoPSC electric rate order. See Note 2 – Rate and Regulatory Matters under Part I, Item 1, of this report for additional information regarding the April 2025 MoPSC electric rate order.

•Excluding the estimated effects of weather and the MEEIA customer energy-efficiency programs, electric revenues decreased an estimated $13 million, due to lower realized prices related to changes in customer usage patterns, and decreased retail sales volumes, which were, in part, unfavorably affected by the absence of an additional day as a result of the leap year in 2024.

•Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” decreased $12 million, due to decreased revenue related to the amortization of costs previously deferred under the FAC that were reflected in customer rates. The changes to “Cost recovery mechanisms - offset in fuel and purchased power” are fully offset by changes to “Cost recovery mechanisms - offset in electric revenue” in fuel and purchased power.

Ameren Illinois

Ameren Illinois’ electric revenues increased $80 million, or 13%, for the three months ended March 31, 2025, compared with the year-ago period, driven by increased revenues at Ameren Illinois Electric Distribution and Ameren Illinois Transmission.

Ameren Illinois Electric Distribution

Ameren Illinois Electric Distribution’s revenues increased $66 million, or 13%, for the three months ended March 31, 2025, compared with the year-ago period.

The following items increased Ameren Illinois Electric Distribution’s revenues between periods:

•Base rates increased revenues by $22 million, due to higher recoverable non-purchased power expenses (+$19 million) and increased capital investment (+$3 million).

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•Revenues associated with “Cost recovery mechanisms – offset in fuel and purchased power” increased $20 million due to increased purchased power expenses recovered from customers. The increase in electric revenues are fully offset by an increase in purchased power expenses under cost recovery mechanisms for purchased power, as discussed below.

•Other cost recovery mechanisms increased revenues by $13 million, primarily due to a higher amount of bad debt costs included in customer rates pursuant to the associated rider.

•Revenues increased $5 million due to the recovery