Compute RTO Load Served by RTO Generation Sample Clauses

Compute RTO Load Served by RTO Generation. Using area load and losses for each load zone, compute the RTO Load, in MWs, by summing the load and losses for each load zone to determine the total zonal load for each RTO load zone. Twenty percent of RECo load shall be included in the Market Flow calculation as PJM load. See Section 6.2, of this Schedule D. __ = + , for each RTO load zone Where: zone = the relevant RTO load zone; Zonal_Total_Loadzone = the sum of the RTO’s load and transmission losses for the zone; Loadzone = the load within the zone; and Losseszone = the transmission losses for transfers through the zone. Next, reduce the Zonal Loads by the scheduled line real-time import transaction schedules that sink in that particular load zone: __ = __ − ∑ _ℎℎ_, Where: zone = the relevant RTO load zone; scheduled_line = each of the Transmission Facilities identified in Table 1 below; Zonal_Reduced_Loadzone = the sum of the RTO’s load and transmission losses in a zone reduced by the sum of import schedules over scheduled lines to the zone; Zonal_Total_Loadzone = the sum of the RTO’s load and transmission losses for the zone; and Import_Schedulesscheduled_line,zone = import schedules over a scheduled line to a zone. The real-time import schedules over scheduled lines will only reduce the load in the sink load zones identified in Table 1 below:
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Compute RTO Load Served by RTO Generation. Using area load and losses for each load zone, compute the RTO Load, in MWs, by summing the load and losses for each load zone to determine the total zonal load for each RTO load zone. Twenty percent of RECo load shall be included in the Market Flow calculation as PJM load. See Section 6.2, of this Schedule D. , for each RTO load zone Where: zone = the relevant RTO load zone; Zonal_Total_Loadzone = the sum of the RTO’s load and transmission losses for the zone; Loadzone = the load within the zone; and Losseszone = the transmission losses for transfers through the zone. Next, reduce the Zonal Loads by the scheduled line real-time import transaction schedules that sink in that particular load zone: Where: zone = the relevant RTO load zone; scheduled_line = each of the Transmission Facilities identified in Table 1 below; Zonal_Reduced_Loadzone = the sum of the RTO’s load and transmission losses in a zone reduced by the sum of import schedules over scheduled lines to the zone; Zonal_Total_Loadzone = the sum of the RTO’s load and transmission losses for the zone; and Import_Schedulesscheduled_line,zone = import schedules over a scheduled line to a zone. The real-time import schedules over scheduled lines will only reduce the load in the sink load zones identified in Table 1 below: Table 1. List of Scheduled Lines Scheduled Line NYISO Load Zone PJM Load Zone Xxxxxxxx Scheduled Line North Not Applicable Cross-Sound Scheduled Line Long Island Not Applicable HTP Scheduled Line New York City Mid-Atlantic Control Zone Linden VFT Scheduled Line New York City Mid-Atlantic Control Zone Neptune Scheduled Line Long Island Mid-Atlantic Control Zone Northport – Norwalk Scheduled Line Long Island Not Applicable Once import schedules over scheduled lines have been accounted for, it is then appropriate to reduce the net RTO Load by the remaining real-time import schedules at the proxies identified in Table 2 below: Table 2. List of Proxies* Proxy Balancing Authorities Responsible PJM shall post and maintain a list of its proxies on its OASIS website. PJM shall provide to NYISO notice of any new or deleted proxies prior to implementing such changes in its M2M software. PJM NYISO proxies are the Proxy Generator Buses that are not identified as Scheduled Lines in the table that is set forth in Section 4.4.4 of the NYISO’s Market Services Tariff. The NYISO shall provide to PJM notice of any new of deleted proxies prior to implementing such changes in its M2M software. NYISO *Sched...
Sample 1Sample 2Sample 3See All (31)
Compute RTO Load Served by RTO Generation. Using area load and losses for each load zone, compute the RTO Load, in MWs, by summing the load and losses for each load zone to determine the total zonal load for each RTO load zone. Twenty percent of RECo load shall be included in the Market Flow calculation as PJM load. See Section 6.2, below. Zonal_Total_Loadzone = Loadzone + Losseszone, for each RTO load zone Where: zone = the relevant RTO load zone; Zonal_Total_Loadzone = the sum of the RTO’s load and transmission losses for the zone; Loadzone = the load within the zone; and Losseszone = the transmission losses for transfers through the zone.
Sample 1
Compute RTO Load Served by RTO Generation. Using area load and losses for each load zone, compute the RTO Load, in MWs, by summing the load and losses for each load zone to determine the total zonal load for each RTO load zone. Twenty percent of RECo load shall be included in the Market Flow calculation as PJM load. See Section 6.2, below. 𝑍𝑜𝑛𝑎𝑙_𝑇𝑜𝑡𝑎𝑙_𝐿𝑜𝑎𝑑𝑧𝑜𝑛𝑒 = 𝐿𝑜𝑎𝑑𝑧𝑜𝑛𝑒 + 𝐿𝑜𝑠𝑠𝑒𝑠𝑧𝑜𝑛𝑒, for each RTO load zone Where: zone = the relevant RTO load zone; Zonal_Total_Loadzone = the sum of the RTO’s load and transmission losses for the zone; Loadzone = the load within the zone; and Losseszone = the transmission losses for transfers through the zone. Next, reduce the Zonal Loads by the scheduled line real-time import transaction schedules that sink in that particular load zone: 𝑍𝑜𝑛𝑎𝑙_𝑅𝑒𝑑𝑢𝑐𝑒𝑑_𝐿𝑜𝑎𝑑𝑧𝑜𝑛𝑒 = 𝑍𝑜𝑛𝑎𝑙_𝑇𝑜𝑡𝑎𝑙_𝐿𝑜𝑎𝑑𝑧𝑜𝑛𝑒 ‒ 𝑎𝑙𝑙 ∑ 𝐼𝑚𝑝𝑜𝑟𝑡_𝑆𝑐ℎ𝑒𝑑𝑢𝑙𝑒𝑠𝑠𝑐ℎ𝑒𝑑𝑢𝑙𝑒𝑑_𝑙𝑖𝑛𝑒,𝑧𝑜𝑛𝑒 𝑠𝑐ℎ𝑒𝑑𝑢𝑙𝑒𝑑_𝑙𝑖𝑛𝑒𝑠 = 1
Sample 1

Related to Compute RTO Load Served by RTO Generation

  • Synchronous Generation The Interconnection Customer shall design its Small Generating Facility to maintain a composite power delivery at continuous rated power output at the Point of Interconnection at a power factor within the range of 0.95 leading to 0.95 lagging, unless the NYISO or the Transmission Owner in whose Transmission District the Small Generating Facility interconnects has established different requirements that apply to all similarly situated generators in the New York Control Area or Transmission District (as applicable) on a comparable basis, in accordance with Good Utility Practice.

  • Non-Synchronous Generation The Interconnection Customer shall design its Small Generating Facility to maintain a composite power delivery at continuous rated power output at the high-side of the generator substation at a power factor within the range of 0.95 leading to 0.95 lagging, unless the NYISO or the Transmission Owner in whose Transmission District the Small Generating Facility interconnects has established a different power factor range that applies to all similarly situated non-synchronous generators in the control area or Transmission District (as applicable) on a comparable basis, in accordance with Good Utility Practice. This power factor range standard shall be dynamic and can be met using, for example, power electronics designed to supply this level of reactive capability (taking into account any limitations due to voltage level, real power output, etc.) or fixed and switched capacitors, or a combination of the two. This requirement shall only apply to newly interconnecting non-synchronous generators that have not yet executed a Facilities Study Agreement as of September 21, 2016.

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