Determination of CECo’s Controlled and Purchased Resources Cost Sample Clauses

Determination of CECo’s Controlled and Purchased Resources Cost. All of CECo’s short-term purchases of power are considered dispatchable. For the purposes of this RCP Procedure 1, “short term purchases” means all hourly, balance of day, day-ahead (e.g., 1 day x 16 hours), balance of week (e.g., on-peak — up to 4 days, off-peak and round the clock – up to 6 days) and all dispatchable energy and capacity purchases. CECo has some long-term purchases that are also dispatchable. As of the date of this RCP Procedure 1, CECo’s long-term dispatchable purchases include (with the exception of MCV): (i) Ada Cogeneration Limited Partnership, (ii) Bio Energy Partners, (iii) Cadillac Renewable Energy LLC, (iv) Genesee Power Station Limited Partnership, (v) Gxxxxxx Electric Company (Grand Blanc Generating Station), (vi) Gxxxxxx Electric Company (Landfill No. 1), (vii) Gxxxxxx Electric Company (Landfill No. 2), and (viii) Grayling Generating Station Limited Partnership. The Incremental Costs of CECo’s controlled and purchased resources shall be determined in accordance with Good Utility Practice and shall be comprised of the following components: (a) The purchase price at the point of delivery, excluding any option premium amounts, capacity payments under dispatchable and energy contracts, and other similar fixed cost considerations. (b) The transmission service costs (including losses, if applicable) to transmit the power from the point of delivery to the CECo Bus (defined below), if applicable. If CECo transmitted the power to the CECo Bus by using a transmission service reservation that can accommodate purchases of greater size than that of a specific transaction, only the prorata cost for the MW transmitted are to be included. (c) For purchases that require transmission service to deliver the power to the CECo Bus, the Penalty Factor shall be applied which is based on a weighted average of (i) 70% of the Penalty Factor associated with power received at the Michigan Electric Transmission Company’s or any successor’s (“METC”) interconnection with the American Electric Power Company (or any successor) and (ii) 30% of the Penalty Factor associated with power received at the METC’s interconnection with the International Transmission Company (or any successor). The 70% / 30% allocation shall be reviewed and revised as necessary annually for implementation on February 1 of each year by mutual agreement of the Parties.
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Related to Determination of CECo’s Controlled and Purchased Resources Cost

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