7.1.1
DAM TUC Settlements – Internal Transactions
As part of the Transmission Usage Charge (TUC) charged to all Transmission Customers whose internal transmission service has been scheduled Day-Ahead, each such
Transmission Customer is charged or paid in its TUC the product of (a) the amount of Energy scheduled Day-Ahead to be withdrawn by that Transmission Customer in each hour, in megawatt hours; and (b) the Marginal Losses Component of the Day-Ahead LBMP at the Point of Delivery (i.e., Load Zone in which Energy is scheduled to be withdrawn) for the Transaction, in $/MWh, minus the Marginal Losses Component of the Day-Ahead LBMP at the internal Generator Bus Point of Receipt (Injection) for the Transaction, in $/MWh.
In addition, all Transmission Customers scheduling internal transmission service Day- Ahead, will be charged or paid, in their TUC, the product of (a) the difference between the amount of Energy scheduled Day-Ahead to be withdrawn by that Transmission Customer in each hour, in megawatts, and the megawatts of the associated grandfathered transmission right times one hour; and (b) the Congestion Component of the Day-Ahead LBMP at the internal Point of Delivery (i.e., Load Zone in which Energy is scheduled to be withdrawn) for the Transaction in $/MWh, minus the Congestion Component of the Day-Ahead LBMP at the internal Generator Bus Point of Receipt (Injection) for the Transaction, in $/MWh, plus the Adjustment to Congestion Relief; provided however the Transmission Customer acknowledged the associated grandfathered transmission right, if any, when scheduling the Transaction Day-Ahead.
The calculation of the Adjustment to Congestion Relief is described in Section 7.5 below. DAM TUC settlements for Internal Transactions are described formulaically in Appendix K of this manual.
7.1.1.1 DAM Replacement Energy to Support Internal Transactions
If the Internal Bilateral Transaction was scheduled in the Day-Ahead Market, and the Day- Ahead Schedule for the Generator designated as the Supplier of Energy for that Bilateral Transaction called for that Generator to produce less Energy than was scheduled Day- Ahead to be consumed in association with that Transaction, the NYISO will supply the Load with Energy from the Day-Ahead LBMP Market. The Transmission Customer scheduling the Bilateral Transaction will continue to pay the Day-Ahead TUC and in addition, the Generator designated as the Supplier of Energy for the Bilateral Transaction will pay the Day-Ahead LBMP price, at the internal Generator Bus Point of Receipt
(Injection) for the Transaction, for the replacement amount of Energy in (megawatt hours) purchased in the LBMP Market.
DAM Replacement Energy settlements for Generators designated as the Suppliers of Energy for Bilateral Transactions that are scheduled to produce less Energy than is
necessary to support the Internal Transactions are described formulaically in Appendix B of this manual.
7.1.2
Balancing Market TUC Settlements – Internal
Transactions
As part of the Transmission Usage Charge (TUC) charged to all Transmission Customers whose internal transmission service was scheduled after the determination of the Day- Ahead schedule, or either increased or decreased the amount of the internal transmission service after the determination of the Day-Ahead Transaction schedule, each such
Transmission Customer is charged or paid the product of (a) actual Energy Withdrawals by RTD in each hour, minus the amount of Energy scheduled Day-Ahead to be withdrawn by that Transmission Customer in that hour, in megawatt hours; and (b) the Marginal Losses Component of the Real-Time LBMP at the Point of Delivery (i.e., Load Zone in which Energy is scheduled to be withdrawn) for the Transaction, in $/MWh, minus the Marginal Losses Component of the Real-Time LBMP at the internal Generator Bus Point of Receipt (Injection) for the Transaction, in $/MWh.
Also as part of the TUC charged to all Transmission Customers whose internal transmission service was scheduled after the determination of the Day-Ahead schedule, or either
increased or decreased the amount of the internal transmission service after the
determination of the Day-Ahead Transaction schedule, each such Transmission Customer is charged or paid the product of (a) actual Energy Withdrawals by RTD in each hour, minus the amount of Energy scheduled Day-Ahead to be withdrawn by that Transmission
Customer in that hour, in megawatt hours; and (b) the Congestion Component of the Real- Time LBMP at the Point of Delivery (i.e., Load Zone in which Energy is scheduled to be withdrawn) for the Transaction, in $/MWh, minus the Congestion Component of the Real- Time LBMP at the internal Generator Bus Point of Receipt (Injection) for the Transaction, in $/MWh.
Balancing Market TUC settlements for Internal Transactions are described formulaically in Appendix K of this manual.
7.1.2.1 Real-Time Replacement Energy to Support Internal Transactions
If the Generator designated as the Supplier of Energy for that Bilateral Transaction is dispatched in real-time to produce less Energy than necessary to supply the Transaction, the NYISO will supply the Load with Energy from the Real-Time LBMP Market. The
Transmission Customer scheduling the Bilateral Transaction will continue to pay the respective TUC and in addition, the Generator designated as the Supplier of Energy for the Bilateral Transaction will pay the Real-Time LBMP price, at the internal Generator Bus Point of Receipt (Injection) for the Transaction, for any additional Replacement Energy (in megawatt hours) necessary to supply the Transaction.
Real-Time Replacement Energy settlements for Generators designated as the Suppliers of Energy for that Bilateral Transactions that are dispatched in real-time to produce less Energy than necessary to supply the Transactions are described formulaically in Appendix B of this manual.
7.1.2.2 Transactions Supplied by Certain Resources Pursuant to PURPA Contracts or Supplying Steam to NYC
The amount of Transmission Service scheduled hour-ahead in the RTC for Transactions supplied by one of the following Generators will retroactively be set equal to that Generator's actual output in each RTD interval: (i) Generators providing Energy under contracts executed and effective on or before November 18, 1999 (including PURPA contracts) in which the power purchaser does not control the operation of the supply source but would be responsible for penalties for being off-schedule; and (ii) Existing topping turbine Generators and extraction turbine Generators producing electric Energy resulting from the supply of steam to the district steam system located in New York City (LBMP Zone J) in operation on or before November 18, 1999 and/or topping or extraction turbine Generators utilized in replacing or repowering existing steam supplies from such units (in accordance with good engineering and economic design) that cannot follow schedules, up to a maximum total of 499 MW of such units. This procedure will not apply for those hours the Generator supplying that Transaction has bid in a manner that indicates it is available to provide Regulation Service or Operating Reserves.