Day- Ahead Market Energy - NYISO · NYISO Proprietary Information 2 Description of Settlement •...

NYISO Proprietary Information 1

Day- Ahead Market Energy

Load Serving Entity Settlements


Description of Settlement

• LSE Day Ahead Market Energy Settlement is intended to charge Load Serving Entities for DAM energy purchased via load schedules in the NYISO DAM.

• DAM Load Schedules are NYCA purchases of energy by Market Participants (acting as LSE’s) which are scheduled by NYISO in the DAM.

Day-Ahead Market Energy - LSE


References

• Tariff: Market Services Tariff Article 4, Section 4.16

• Billing & Accounting Manual: Version 1.24, Section 1.2.1

• DSS Corporate Report: ‘Settlement Detail Report – Load Serving Entity –Day Ahead Market Energy’



Flow Chart

InvoiceTransmission Customer

Daily Bill Codes700701702703

Hourly Bill Codes402403404405406

Corporate Report:Load Serving Entity – Day Ahead Market Energy



Eligibility Rules / Requirements

• LSE’s load bus is scheduled to purchase energy in the NYISO DAM(Hr DAM Sched Load (MW) > 0).



Inputs

• Hr DAM Energy Price :LSE ($/MW)• Hr DAM Loss Price :LSE ($/MW)• Hr DAM Cong Price :LSE ($/MW)• Hr DAM Load Bid :Fix Load (MW)• Hr DAM Sched PrCap Load (MW)

Note: Hr DAM Total Price :LSE ($/MW) - Bill Code 403= Hr DAM Energy Price :LSE ($/MW) + Hr DAM Loss Price :LSE ($/MW) – Hr DAM Cong Price :LSE ($/MW)



Outputs

• Hr DAM Energy Stlmnt :LSE ($) - Bill Code 404• Hr DAM Loss Stlmnt :LSE ($) - Bill Code 405• Hr DAM Cong Stlmnt :LSE ($) - Bill Code 406• Hr Total DAM Stlmnt :LSE ($)



Outputs cont.

Note:Day DAM Energy Stlmnt :LSE ($) - Bill Code 701= Σ Hr DAM Energy Stlmnt :LSE ($)

Day DAM Loss Stlmnt :LSE ($) - Bill Code 702= Σ Hr DAM Loss Stlmnt :LSE ($)

Day DAM Cong Stlmnt :LSE ($) - Bill Code 703= Σ Hr DAM Cong Stlmnt :LSE ($)

Day Total DAM Stlmnt :LSE ($) = Σ Hr Total DAM Stlmnt :LSE ($)



Settlement Algorithm

Hr Total DAM Stlmnt :LSE ($) =Hr DAM Energy Stlmnt :LSE ($)

+ Hr DAM Loss Stlmnt :LSE ($) – Hr DAM Cong Stlmnt :LSE ($)



Example

Hr DAM Sched Load (MW) - Bill Code 402= Hr DAM Load Bid :Fix Load (MW) + Hr DAM Sched PrCap Load (MW)= 150 MW + 0 MW= 150 MW

Note: Day DAM Sched Load (MW) - Bill Code 700= Σ Hr DAM Sched Load (MW)

Hr DAM Energy Stlmnt :LSE ($) - Bill Code 404= Hr DAM Sched Load :LSE (MW) * Hr DAM Energy Price :LSE ($/MW)= 150 MW * ($35/MW)= $5250



Example cont.

Hr DAM Loss Stlmnt :LSE ($) - Bill Code 405= Hr DAM Sched Load :LSE (MW) * Hr DAM Loss Price :LSE ($/MW)= 150 MW * ($3/MW)= $450

Hr DAM Cong Stlmnt :LSE ($) - Bill Code 406= Hr DAM Sched Load :LSE (MW) * Hr DAM Cong Price :LSE ($/MW)= 150 MW * -$1/MW= -$150

Hr Total DAM Stlmnt :LSE ($) == Hr DAM Energy Stlmnt :LSE ($) + Hr DAM Loss Stlmnt :LSE ($)

– Hr DAM Cong Stlmnt :LSE ($)= $5250 + $450 - (-$150)= $5850



Balancing Market Energy

Load Serving Entity Settlements



• Balancing Market Energy Settlement addresses energy variations from the Day Ahead Market.

• Intended to charge or credit Market Participants (acting as Load Serving Entities) for energy purchased or sold in the NYISO Balancing Energy Market.

Balancing Market Energy - LSE


References



• DSS Corporate Report: ‘Settlement Detail Report – Load Serving Entity –Balancing Energy’



Flow Chart

InvoiceTransmission Customer



Corporate Report:Load Serving Entity – Balancing Energy




• LSE will be charged for Balancing Market Energy if:LSE’s load bus purchases energy from NYISO Balancing Market.(SCD BalMkt Load :LSE (MW) > 0)

• LSE will be credited for Balancing Market Energy if:LSE’s load bus sells energy to NYISO Balancing Market.(SCD BalMkt Load :LSE (MW) < 0)



Inputs

• SCD RT Energy Price :LSE ($/MW)• SCD RT Loss Price :LSE ($/MW)• SCD RT Cong Price :LSE ($/MW)• SCD RT Actual Load (MW)• Hr DAM Sched Load (MW)• SCD RT Sched Trans :Load Bus (MW)• SCD Interval Seconds

Note: SCD RT Total Price :LSE ($/MW) = SCD RT Energy Price :LSE ($/MW) + SCD RT Loss Price :LSE ($/MW) - SCD RT Cong Price :LSE ($/MW)

Hr RT Total Price :LSE ($/MW) - Bill Code 408= Σ [SCD RT Total Price :LSE ($/MW) * (SCD Int. Seconds ÷ 3600)]



Outputs

• SCD BalMkt Energy Stlmnt :LSE ($)

Note: Hr BalMkt Energy Stlmnt :LSE ($) = Σ SCD BalMkt Energy Stlmnt :LSE ($) B.C. 409Day BalMkt Energy Stlmnt :LSE ($) = Σ Hr BalMkt Energy Stlmnt :LSE ($) B.C. 705

• SCD BalMkt Loss Stlmnt :LSE ($)

Note: Hr BalMkt Loss Stlmnt :LSE ($) = Σ SCD BalMkt Loss Stlmnt :LSE ($) B.C. 410Day BalMkt Loss Stlmnt :LSE ($) = Σ Hr BalMkt Loss Stlmnt :LSE ($) B.C. 706



Outputs cont.

• SCD BalMkt Cong Stlmnt :LSE ($)

Note: Hr BalMkt Cong Stlmnt :LSE ($) = Σ SCD BalMkt Cong Stlmnt :LSE ($) B.C. 411Day BalMkt Cong Stlmnt :LSE ($) = Σ Hr BalMkt Cong Stlmnt :LSE ($) B.C. 707

• SCD Total BalMkt Stlmnt :LSE ($)

Note: Hr Total BalMkt Stlmnt :LSE ($) = Σ SCD Total BalMkt Stlmnt :LSE ($) Day Total BalMkt Stlmnt :LSE ($) = Σ Hr Total BalMkt Stlmnt :LSE ($)




SCD Total BalMkt Stlmnt :LSE ($) =SCD BalMkt Energy Stlmnt :LSE ($)

+ SCD BalMkt Loss Stlmnt :LSE ($) - SCD BalMkt Cong Stlmnt :LSE ($)



Example

SCD BalMkt Load :LSE (MW)= [SCD RT Actual Load (MW) – Hr DAM Sched Load (MW) – SCD RT Sched Trans (MW)]

* SCD Interval Seconds ÷ 3600 seconds= [200 MW – 150 MW – 40 MW] * 180 ÷ 3600= 10 MW * .05 = 0.5 MW

Note: Hr BalMkt Load :LSE (MW) = Σ SCD BalMkt Load :LSE (MW) - Bill Code 407Day BalMkt Load :LSE (MW) = Σ Hr BalMkt Load :LSE (MW) - Bill Code 704

SCD BalMkt Energy Stlmnt :LSE ($)= SCD BalMkt Load :LSE (MW) * SCD RT Energy Price :LSE ($/MW)= (0.5 MW) * ($30/MW) = $15.00



Example cont.

SCD BalMkt Loss Stlmnt :LSE ($)= SCD BalMkt Load :LSE (MW) * SCD RT Loss Price :LSE ($/MW)= (0.5 MW) * ($2/MW) = $1.00

SCD BalMkt Cong Stlmnt :LSE ($)= SCD BalMkt Load :LSE (MW) * SCD RT Cong Price :LSE ($/MW)= (0.5 MW) * (-$3/MW) = -$1.50

SCD Total BalMkt Stlmnt :LSE ($)= SCD BalMkt Energy Stlmnt :LSE ($) + SCD BalMkt Loss Stlmnt :LSE ($)

- SCD BalMkt Cong Stlmnt :LSE ($) = $15.00 + $1.00 - (-$1.50)= $17.50



Transaction Day-Ahead Market Energy

Transmission Customer Settlements



• ImportsTransaction Day Ahead Market Energy Settlement for imports is intended to credit Transaction Customers for day ahead energy scheduled via Market Energy Import Transactions.

• ExportsTransaction Day Ahead Market Energy Settlement for exports is intended to charge Transaction Customers for day ahead energy scheduled via Market Energy Export Transactions.

Transaction Day-Ahead Market Energy - TC


References



• DSS Corporate Report: ‘Settlement Details Report – Transaction Customer Day Ahead Market LBMP Energy’



Flow Chart

InvoiceTransaction Customer



Corporate Report:Transaction Customer Day Ahead Market LBMP Energy




Import Transactions· Transaction Contract is DAM Energy Import

Transaction– Source Location is NYISO external control area proxy

bus– Sink Location is NYISO market reference proxy bus– TransCnt Transaction Category = Import

· Transaction Contract is scheduled in NYISO Day Ahead




Export Transactions· Transaction Contract is DAM Energy Export

Transaction– Source Location is NYISO market reference proxy bus – Sink Location is NYISO external control area proxy bus– TransCnt Transaction Category = Export

· Transaction Contract is scheduled in NYISO Day Ahead



Inputs

For Imports & Exports:

• Hr DAM Energy Price :Src ($/MW)• Hr DAM Loss Price :Src ($/MW)• Hr DAM Congestion Price :Src ($/MW)• Hr DAM Sched Trans :Trans (MW)

Note: Source price is used for imports; sink price is used for exports.



Outputs


• Hr DAM Total LBMP Stlmnt ($) - Bill Code 515*

• DAM Total LBMP Stlmnt ($) - Bill Code 762*

Note: DAM Total LBMP Stlmnt ($) =∑ Hr DAM Total LBMP Stlmnt ($)

*Bill Codes 515 and 762 also include Replacement Energy Stlmnt ($).Reference section 1.3.6 of B&A Manual.





Hr DAM Total LBMP Stlmnt ($) =Hr DAM LBMP Energy Stlmnt ($)

+ Hr DAM LBMP Loss Stlmnt ($) - Hr DAM LBMP Cong Stlmnt ($)



ExampleHr DAM LBMP Energy (MW) = Hr DAM Sched Trans :Trans (MW)

= 100 MW

Note: Hr DAM LBMP Energy (MW) - Bill Code 511Day DAM LBMP Energy (MW) = ∑ Hr DAM LBMP Energy (MW) - Bill Code 758*

Hr DAM LBMP Energy Stlmnt ($) = Hr DAM LBMP Energy (MW) * Hr DAM Energy Price :Src ($/MW)

= 100 MW * $10/MW= $1000

Note: Hr DAM LBMP Energy Stlmnt ($) - Bill Code 512*Day DAM LBMP Energy Stlmnt ($) = ∑ Hr DAM LBMP Energy Stlmnt ($) - Bill Code 759*

* Bill Codes also include Replacement Energy Stlmnt ($).



Example cont.Hr DAM LBMP Loss Stlmnt ($) = Hr DAM LBMP Energy (MW)

* Hr DAM Loss Price :Src ($/MW)= 100 MW * $2/MW = $200

Note: Hr DAM LBMP Loss Stlmnt ($) - Bill Code 513*Day DAM LBMP Loss Stlmnt ($) = ∑ Hr DAM LBMP Loss Stlmnt ($) - Bill Code 760*

Hr DAM LBMP Cong Stlmnt ($) = Hr DAM LBMP Energy (MW)* Hr DAM Cong Price :Src ($/MW)

= 100 MW * - $3/MW = - $300

Note: Hr DAM LBMP Cong Stlmnt ($) - Bill Code 514*Day DAM LBMP Cong Stlmnt ($) = ∑ Hr DAM LBMP Cong Stlmnt ($) - Bill Code 761*




Example cont.

Hr DAM Total LBMP Stlmnt ($) = Hr DAM LBMP Energy Stlmnt ($)

+ Hr DAM LBMP Loss Stlmnt ($)- Hr DAM LBMP Cong Stlmnt ($)

= $1000 + $200 – (-$300)= $1200 + $300= $1500

Note: Hr DAM Total LBMP Stlmnt ($) - Bill Code 515*Day DAM Total LBMP Stlmnt ($) = ∑ Hr DAM Total LBMP Stlmnt ($) - Bill Code 762*




Additional Information

Transaction Day Ahead Market Replacement Energy

• Settlement is intended to address any shortfall between the amount of DAM Transaction Bid Energy (MW) and the DAM Energy Scheduled (MW) via Bilateral Import Transactions.

• Transaction Customers are required to purchase DAM Replacement Energy from the NYISO DAM Market if their DAM schedule is less than their DAM Bid Energy (MW).

• B & A Manual: Version 1.24, Section 1.3.6



Additional InformationSettlement Algorithm:Hr DAM Repl Energy (MW) =

Hr DAM Trans Bid Fixed Energy (MW) – Hr DAM SchedTrans :Trans (MW)

Hr DAM Repl Energy Stlmnt ($) = - part of Bill Code 512

Hr DAM Repl Energy (MW) * Hr DAM Energy Price :Src ($/MW)

Hr DAM Repl Loss Stlmnt ($) = - part of Bill Code 513

Hr DAM Repl Energy (MW) * Hr DAM Loss Price :Src ($/MW)



Additional InformationSettlement Algorithm cont.

Hr DAM Repl Cong Stlmnt ($) = - part of Bill Code 514

Hr DAM Repl Energy (MW) * Hr DAM Cong Price :Src ($/MW)

Hr Total DAM Repl Stlmnt ($) = - part of Bill Code 515

Hr DAM Repl Energy Stlmnt ($) + Hr DAM Repl Loss Stlmnt ($) – Hr DAM Repl Cong Stlmnt ($)



Transaction Balancing Market Energy




ImportsTransaction Balancing Market Energy Settlement is

intended to address differences between Real-Time and Day-Ahead Market energy.

ExportsTransaction Balancing Market Energy Settlement is

intended to address differences between Real-Time and higher of Day-Ahead Market and HAM energy.

Transaction Balancing Market Energy - TC


References



• DSS Corporate Report: ‘Settlement Details Report – Transaction Customer LBMP Balancing Energy’



Flow Chart




Corporate Report:Transaction Customer LBMP Balancing Energy




Import Transactions· Transaction Contract is Real-Time Energy Import

Transaction– Source Location is NYISO external control area

proxy bus– Sink Location is NYISO market reference proxy

bus– TransCnt Transaction Category = Import




Export Transactions· Transaction Contract is Real-Time Energy Export

Transaction– Source Location is NYISO market reference

proxy bus – Sink Location is NYISO external control area

proxy bus– TransCnt Transaction Category = Export



InputsFor Imports & Exports:

• SCD RT Energy Price :Src ($/MW)• SCD RT Loss Price :Src ($/MW)• SCD RT Congestion Price :Src ($/MW)• Hr DAM Sched Trans :Trans (MW)• SCD RT Sched Trans :Trans (MW)• SCD Interval Seconds

Note: Source price is used for imports; sink price is used for exports.



OutputsFor Imports & Exports:

• Hr BalMkt Total LBMP Stlmnt ($) - Bill Code 520*

• Day BalMkt Total LBMP Stlmnt ($) - Bill Code 767*

Note: Hr BalMkt Total LBMP Stlmnt ($) =∑ SCD BalMkt Total LBMP Stlmnt ($)

Day BalMkt Total LBMP Stlmnt ($) =∑ Hr BalMkt Total LBMP Stlmnt ($)

*Bill Codes 520 and 767 also include Replacement Energy Stlmnt ($).Reference section 1.3.8 of B&A Manual.





SCD BalMkt Total LBMP Stlmnt ($) =SCD BalMkt LBMP Energy Stlmnt ($)

+ SCD BalMkt LBMP Loss Stlmnt ($) - SCD BalMkt LBMP Cong Stlmnt ($)



Example

SCD BalMkt LBMP Energy (MW) = {SCD RT Sched Trans :Trans (MW)- Hr DAM Sched Trans:Trans (MW)} * {SCD Interval Seconds / 3600 seconds}= 10 MW

Note: Hr BalMkt LBMP Energy (MW) = ∑ SCD BalMkt LBMP Energy (MW) - Bill Code 516*Day BalMkt LBMP Energy (MW) = ∑ Hr BalMkt LBMP Energy (MW) - Bill Code 763*

SCD BalMkt LBMP Energy Stlmnt ($) = SCD BalMkt LBMP Energy (MW) * SCD RT Energy Price :Src ($/MW)

= 10 MW * $5/MW= $50

Note: Hr BalMkt LBMP Energy Stlmnt ($) = ∑ SCD BalMkt LBMP Energy Stlmnt ($) - B.C. 517*Day BalMkt LBMP Energy Stlmnt ($) = ∑ Hr BalMkt LBMP Energy Stlmnt ($) - B.C. 764*




Example cont.

SCD BalMkt LBMP Loss Stlmnt ($) = SCD BalMkt LBMP Energy (MW) * SCD RT Loss Price :Src ($/MW)

= 10 MW * $3/MW= $30

Note: Hr BalMkt LBMP Loss Stlmnt ($) = ∑ SCD BalMkt LBMP Loss Stlmnt ($) - Bill Code 518*Day BalMkt LBMP Loss Stlmnt ($) = ∑ Hr BalMkt LBMP Loss Stlmnt ($) - Bill Code 765*

SCD BalMkt LBMP Cong Stlmnt ($) = SCD BalMkt LBMP Energy (MW)* SCD RT Cong Price :Src ($/MW)

= 10 MW * - $2/MW= - $20

Note: Hr BalMkt LBMP Cong Stlmnt ($) = ∑ SCD BalMkt LBMP Cong Stlmnt ($) - Bill Code 519*Day BalMkt LBMP Cong Stlmnt ($) = ∑ Hr BalMkt LBMP Cong Stlmnt ($) - Bill Code 766*




Example cont.

SCD BalMkt Total LBMP Stlmnt ($) = SCD BalMkt LBMP Energy Stlmnt ($)

+ SCD BalMkt LBMP Loss Stlmnt ($)- SCD BalMkt LBMP Cong Stlmnt ($)

= $50 + $30 – (-$20)= $80 + $20= $100

Note: Hr BalMkt Total LBMP Stlmnt ($) = ∑ SCD BalMkt Total LBMP Stlmnt ($) - Bill Code 520*Day BalMkt Total LBMP Stlmnt ($) = ∑ Hr BalMkt Total LBMP Stlmnt ($) - Bill Code 767*





Transaction Balancing Market Replacement Energy

• Settlement is intended to address any shortfall between the amount of HAM Transaction Bid Energy (MW) and the actual Real-Time Energy Scheduled (MW) via Bilateral Import Transactions.

• Transaction Customers are required to purchase Balancing Market Replacement Energy from the NYISO Balancing Market if their Real-Time schedule is less than their HAM Bid Energy (MW).

• B & A Manual: Version 1.24, Section 1.3.8




Settlement AlgorithmSCD BalMkt Repl Energy (MW) =[Max { Hr HAM Trans Bid Fixed Energy (MW), Hr DAM Trans Bid Fixed Energy (MW) }

– SCD RT Sched Trans :Trans (MW) – { Hr DAM Trans Bid Fixed Energy (MW) –Hr DAM Sched Trans :Trans (MW) }] * SCD Interval Seconds ÷ 3600 seconds

SCD BalMkt Repl Energy Stlmnt ($) = SCD BalMkt Repl Energy (MW) * SCD RT Energy Price :Src ($/MW)

Hr BalMkt Repl Energy Stlmnt ($) = Σ SCD BalMkt Repl Energy Stlmnt ($) - part of B.C. 517

SCD BalMkt Repl Loss Stlmnt ($) =SCD BalMkt Repl Energy (MW) * SCD RT Loss Price :Src ($/MW)

Hr BalMkt Repl Loss Stlmnt ($) = Σ SCD BalMkt Repl Loss Stlmnt ($) - part of B.C. 518




Settlement Algorithm cont.

SCD BalMkt Repl Cong Stlmnt ($) =SCD BalMkt Repl Energy (MW) * SCD RT Cong Price :Src ($/MW)

Hr BalMkt Repl Cong Stlmnt ($) = Σ SCD BalMkt Repl Cong Stlmnt ($) - part of B.C. 519

SCD BalMkt Total Repl Stlmnt ($) = SCD BalMkt Repl Energy Stlmnt ($) + SCD BalMkt Repl Loss Stlmnt ($) – SCD BalMkt Repl Cong Stlmnt ($)

Note: Hr Total BalMkt Repl Stlmnt ($) = - part of B.C. 520Σ SCD BalMkt Total Repl Stlmnt ($)




Emergency Corrective Actions (ECA’s)

• NYISO Market Monitoring is required by Tariff to identify all transactions that are curtailed due to Marketer Design.

• Intent of ECA is to discourage Market Participants from impacting prices by bidding transactions that are designed to fail at check out.



Additional InformationIntent of Original ECA’s• ECA “A”

– Imports curtailed as the result of MP action are charged the higher of the real-time LBMP less the BME-calculated LBMP multiplied by the curtailed MWh, or $0.

– Exports curtailed as the result of MP action are charged the higher of the BME-calculated LBMP less the real-time LBMP multiplied by the curtailed MWh, or $0.

– Failed wheels are treated as a failed import and a failed export.• ECA “B”

– If the external proxy is constrained, the BME-calculated LBMP is used.– Therefore, the BME-calculated and real-time LBMPs may be the same.



Additional InformationIssues with Current Settlement

• BME and Real-Time prices may be the same.

• Any “penalty” for a transaction failure is included as part of the four-month energy settlement and is identifiable as a manual adjustment on the consolidated invoice.

• Settlement imbalances will occur– Over collections from failed imports– Under payments to failed exports– These imbalances are not clearly discernable in Schedule 1




Post-SMD2: Financial Impact Charge (FIC)• Intent is to restructure the settlement and charges for failed

transactions to provide billing clarity– Transactions will see the FIC as a charge separate from the energy

settlement

• The appropriate allocation of billing dollars will be assured– Revenue from the charges will be reported as a credit to Schedule 1

• Replaces ECA “A”

• References: Market Services Tariff Article 4, Section 4.5 & SMD2 Draft B&A Manual, Section 3.2.3

Transaction Balancing Market Energy – TC Post-SMD2


Additional InformationPost-SMD2: Financial Impact Charge

• Transactions that fail checkout after RTC15 will settle their energy contracts at prevailing real-time prices.

• In addition, the MP causing the failure will incur a Financial Impact Charge (FIC)

• For a failed import, the charge shall be:(SchedRTC – ActRT) X Max [(PriceRTD – PriceRTC),0]

• For a failed export, the charge shall be:(SchedRTC – ActRT) X Max [(PriceRTC – PriceRTD),0]

• Failed wheels are treated as a failed import and a failed exportTransaction Balancing Market Energy – TC Post-SMD2


Additional InformationPost-SMD2: ECA “B”• Invoked in response to interface constraints

• Not changing significantly with SMD2

• Pre-SMD2: Real-time price for all SCD intervals in the hour is replaced with the BME price

• Post-SMD2: RTD LBMP is replaced with the average RTC LBMP for the hour




FIC – ImportsEligibility

Transaction is liable for an FIC-Import if all of the following are true:

• Transaction is an import• Real time energy on the transaction is less than RTC15

scheduled energy (RTD RT Sched Trans (MW) < Hr RTC Sched Trans (MW)

• Transaction failed post RTC15 checkout due to MP action (Trans Cut By Desc = market participant)



Additional InformationFIC – Imports


RTC15 Avg Total Price: Src ($/MW) =

[ RTC15 Int 3 Total Price : Src ($/MW) +RTC15 Int 4 Total Price : Src ($/MW) +RTC15 Int 5 Total Price : Src ($/MW) +RTC15 Int 6 Total Price : Src ($/MW) ] ÷ 4





RTD Fin Imp Ch Stlmnt: Import Trans ($) =

[Hr RTC Sched Trans (MW) – RTD RT Sched Trans (MW)] * Max { [RTD Calc Total Price : Src ($/MW) - RTC15 Avg Total

Price: Src ($/MW)] , 0 } * (RTD Interval Seconds ÷ 3600)

Where: RTD Calc Total Price : Src ($/MW) is the RTD calculated price at the source generator per interval (LBMP energy component + LBMP losses component –LBMP congestion component.





Hr Fin Imp Ch Stlmnt: Import Trans ($) = - part of B.C. 531Σ RTD Fin Imp Ch Stlmnt: Import Trans ($)

Day Fin Imp Ch Stlmnt: Import Trans ($) = - part of B.C. 777Σ Hr Fin Imp Ch Stlmnt: Import Trans ($)



Additional InformationFIC – Exports

EligibilityTransaction is liable for an FIC-Export if all of the following are true:

• Transaction is an export• Real time energy on the transaction is less than RTC15





Additional InformationFIC – Exports


RTC15 Avg Total Price: Sink ($/MW) =

[ RTC15 Int 3 Total Price : Sink ($/MW) +RTC15 Int 4 Total Price : Sink ($/MW) +RTC15 Int 5 Total Price : Sink ($/MW) +RTC15 Int 6 Total Price : Sink ($/MW) ] ÷ 4



Additional InformationFIC – ExportsSettlement Algorithm cont.

RTD Fin Imp Ch Stlmnt: Export Trans ($) =

[Hr RTC Sched Trans (MW) – RTD RT Sched Trans (MW)] * Max { [RTC15 Avg Total Price: Sink ($/MW) - RTD Calc Total

Price : Sink ($/MW)] , 0 } * (RTD Interval Seconds ÷ 3600)

Where: RTD Calc Total Price : Sink ($/MW) is the RTD calculated price at the sink load bus per interval (LBMP energy component + LBMP losses component – LBMP congestion component.




FIC – Exports


Hr Fin Imp Ch Stlmnt: Export Trans ($) = - part of B.C. 531Σ RTD Fin Imp Ch Stlmnt: Export Trans ($)

Day Fin Imp Ch Stlmnt: Export Trans ($) = - part of B.C. 777Σ Hr Fin Imp Ch Stlmnt: Export Trans ($)



Additional InformationFIC – WheelThroughs

EligibilityTransaction is liable for an FIC-Wheelthrough if all of the following are true:

• Transaction is a wheelthrough• Real time energy on the transaction is less than RTC15






FIC – Wheelthroughs


RTD Fin Imp Ch Stlmnt: Whl Trans ($) = RTD Fin Imp Ch Stlmnt: Export Trans ($) +RTD Fin Imp Ch Stlmnt: Import Trans ($)



Additional InformationFIC – Wheelthroughs


Hr Fin Imp Ch Stlmnt: Whl Trans ($) = - part of B.C. 531Σ RTD Fin Imp Ch Stlmnt: Whl Trans ($)

Day Fin Imp Ch Stlmnt: Whl Trans ($) = - part of B.C. 777Σ Hr Fin Imp Ch Stlmnt: Whl Trans ($)




FIC Total

Note:Hr Fin Impact Ch Stlmnt :Trans ($) = - Bill Code 531

Hr Fin Imp Ch Stlmnt: Import Trans ($) +Hr Fin Imp Ch Stlmnt: Export Trans ($) +Hr Fin Imp Ch Stlmnt: Whl Trans ($)

Day Fin Impact Ch Stlmnt: Trans ($) = - Bill Code 777Day Fin Imp Ch Stlmnt: Import Trans ($) +Day Fin Imp Ch Stlmnt: Export Trans ($) +Day Fin Imp Ch Stlmnt: Whl Trans ($)



Day-Ahead Market TUC




Day Ahead Market Transmission Usage Charge (TUC) settlement for Import, Export, Wheel-Through, and Internal Transactions:

• Intended to charge TUC’s to Transaction Customers with bilateral Transaction Contracts in the NYISO DAM for usage of the NYCA transmission grid (losses and congestion).

• Transaction Customers holding Grandfathered Transmission Rights (GTR) may be exempt (up to a pre-determined MW amount) from paying the congestion component of the TUC.

Day-Ahead Market TUC - TC


References



• DSS Corporate Report: ‘Settlement Detail Report – Transaction Customer -Day Ahead Market Transmission Usage Charges’



Flow Chart




Corporate Report:Transaction Customer Day Ahead Market Transmission Usage Charges




Import Transactions· Transaction Contract is DAM Bilateral Import

Transaction– Source Location is NYISO external control area proxy bus– Sink Location is NOT NYISO market reference proxy bus– TransCnt Transaction Category = Import

· Transaction Contract is bid into NYISO DAM

Note: If import transaction is curtailed, scheduling party purchases replacement energy. Reference section 1.3.6 of B&A Manual.




Export Transactions· Transaction Contract is DAM Bilateral Export

Transaction– Source Location is a NYISO generation bus – Sink Location is NYISO external proxy bus– TransCnt Transaction Category = Export

· Transaction Contract is scheduled in NYISO DAM




Wheel-Through Transactions· Transaction Contract is DAM Bilateral Wheel-

Through Transaction– Source Location is a NYISO external proxy bus – Sink Location is a NYISO external proxy bus– TransCnt Transaction Category = Wheel-Through





Internal Transactions· Transaction Contract is DAM Bilateral Internal

Transaction– Source Location is a NYISO load bus – Sink Location is a NYISO generation bus– TransCnt Transaction Category = Internal




Inputs• Hr DAM Loss Price :Sink ($/MW)• Hr DAM Loss Price :Src ($/MW)• Hr DAM Cong Price :Sink ($/MW)• Hr DAM Cong Price :Src ($/MW)• Hr DAM Trans Bid Fixed Energy (MW)• Hr DAM Sched Trans :Trans (MW)

For holders of GTR’s, also need:• Hr GTR Contract :Summer (MW)• Hr GTR Contract :Winter (MW)• Hr DAM TUC Energy (MW)• Hr Total DAM TUC Energy (MW)• Hr DAM GTR Cong Price :Sink ($/MW)• Hr DAM GTR Cong Price :Src ($/MW)



Outputs

Hr Total DAM TUC Stlmnt ($) - Bill Code 504

Note: Day Total DAM TUC Stlmnt ($) - Bill Code 753= ∑ Hr Total DAM TUC Stlmnt ($)



Settlement AlgorithmHr Total DAM TUC Stlmnt ($) =

Hr DAM TUC Loss Stlmnt ($) - Bill Code 503- Hr DAM TUC Cong Stlmnt ($) - Bill Code 502

where:Hr DAM TUC Loss Stlmnt ($) = Hr DAM TUC Energy (MW) *

{ Hr DAM Loss Price :Sink ($/MW) – Hr DAM Loss Price :Src ($/MW) }

and (Without Grandfathered Transmission Rights):Hr DAM TUC Cong Stlmnt ($) = Hr DAM TUC Energy (MW) *

{ Hr DAM Cong Price :Sink ($/MW) – Hr DAM Cong Price :Src ($/MW) }



Settlement Algorithm cont.Note:For Imports: Hr DAM TUC Energy (MW) - Bill Code 501

= Hr DAM Trans Bid Fixed Energy (MW).For Exports, Wheel-Throughs and Internals:

Hr DAM TUC Energy (MW) = Hr DAM Sched Trans :Trans (MW).

Also:Day DAM TUC Energy (MW) - Bill Code 750

= ∑ Hr DAM TUC Energy (MW)

Day DAM TUC Loss Stlmnt ($) - Bill Code 751= ∑ Hr DAM TUC Loss Stlmnt ($)

Day DAM TUC Cong Stlmnt ($) - Bill Code 752= ∑ Hr DAM TUC Cong Stlmnt ($)



Example(Without GTR’s):

Hr DAM TUC Loss Stlmnt ($) = Hr DAM TUC Energy (MW) * { Hr DAM Loss Price :Sink ($/MW)

– Hr DAM Loss Price :Src ($/MW) }= 50 MW * { $4/MW - $3/MW } = $50

Hr DAM TUC Cong Stlmnt ($) = Hr DAM TUC Energy (MW) * { Hr DAM Cong Price :Sink ($/MW)

– Hr DAM Cong Price :Src ($/MW) }= 50 MW * { -$15/MW – (-$12/MW) }= 50 MW * { - $3/MW } = -$150

Hr Total DAM TUC Stlmnt ($) =Hr DAM TUC Loss Stlmnt ($) - Hr DAM TUC Cong Stlmnt ($) = $50 – (-$150) = $200




Congestion Component With Grandfathered Transmission Rights:

Transaction Customers (TC) holding GTR’s may be exempt (up to a pre-determined MW amount) from paying the congestion component of the TUC.

To receive the GTR credit, the TC must:– Schedule the bilateral transaction in the DAM– Follow its DAM transaction schedule





If there is more DAM TUC Energy (MW) than what is covered by grandfathered rights (Hr DAM TUC Energy (MW) > Hr GTR Cong Relief (MW):

Hr DAM TUC Cong Stlmnt ($) =[ {Hr DAM TUC Energy (MW) – Hr GTR Cong Relief (MW)} * {Hr DAM Cong Price :Sink ($/MW) - Hr DAM Cong Price :Src ($/MW)} ] -[Max [ [ Hr GTR Cong Relief (MW) * {Hr DAM Cong Price :Sink ($/MW) - Hr DAM Cong Price :Src ($/MW)} } – Hr DAM TUC Relief Credit ($)] , 0 ]





Else all DAM TUC Energy (MW) is covered by grandfathered rights:

Hr DAM TUC Cong Stlmnt ($) =[ Hr DAM TUC Energy (MW) * {Hr DAM Cong Price :Sink($/MW) - Hr DAM Cong Price :Src ($/MW)} ] – Hr DAM TUC Relief Credit ($)





Hr DAM TUC Relief Credit ($) = Hr GTR Cong Relief (MW) * {Hr DAM GTR Cong Price :Sink

($/MW) - Hr DAM GTR Cong Price :Src ($/MW)}

If HR DAM TUC Energy (MW) * Hr GTR Cong Relief Ratio >= Hr GTR Contract (MW):

Hr GTR Cong Relief (MW) = Hr GTR Contract (MW)Else

Hr GTR Cong Relief (MW) = Hr DAM TUC Energy (MW) * Hr GTR Cong Relief Ratio





Note:Hr DAM GTR Cong Price :Sink ($/MW) is the Hr DAM Cong Price ($/MW)

corresponding to either the Subzone or Zone which contains the Transaction Contract’s sink location, based on the GTR’s sink location definition (use zonal price if GTR’s sink definition is the zone; use sub-zonal price if GTR’s definition is the sub-zone).

Hr DAM GTR Cong Price :Src ($/MW) is the Hr DAM Cong Price ($/MW) corresponding to either the source location itself, or the Zone which contains the Transaction Contract’s source location, based on the GTR’s source location definition (use source location price if GTR’s source definition is the source location; use zonal price if GTR’s definition is the zone).





Hr GTR Contract (MW) =Hr GTR Contract (MW) :Summer (MW) or Hr GTR Contract (MW) :Winter (MW), depending on capabilityperiod.

If Hr Total DAM TUC Energy (MW) > Hr GTR Contract (MW):Hr GTR Cong Relief Ratio =

Hr GTR Contract (MW) ÷ Hr Total DAM TUC Energy (MW)Else

Hr GTR Cong Relief Ratio = 1.0



Example(With GTR’s):

Hr DAM TUC Loss Stlmnt ($) = Hr DAM TUC Energy (MW) * { Hr DAM Loss Price :Sink ($/MW) – Hr DAM Loss Price :Src ($/MW) }= 50 MW * { $4/MW - $3/MW } = $50

Assumptions:Hr GTR Cong Relief Ratio = 1.0, Capability Period = “Summer”, and all DAM

TUC Energy (MW) is covered by GTR’s.

Hr GTR Cong Relief (MW) = Hr DAM TUC Energy (MW) * Hr GTR Cong Relief Ratio= 50 MW * 1.0 = 50 MW



Example cont.

(With GTR’s):

Hr DAM TUC Relief Credit ($) =Hr GTR Cong Relief (MW) * {Hr DAM GTR Cong Price :Sink ($/MW)

- Hr DAM GTR Cong Price :Src ($/MW)} = 50 MW * { -$15/MW – (-$12/MW) }= 50 MW * -$3/MW = -$150

Hr DAM TUC Cong Stlmnt ($) = [ Hr DAM TUC Energy (MW) * {Hr DAM Cong Price :Sink ($/MW) - Hr DAM Cong Price :Src ($/MW)} ] – Hr DAM TUC Relief Credit ($)= [ 50 MW * { -$15/MW – (-$12/MW)} ] - (-$150)= [ -$150 ] + $150 = 0



Example cont.

(With GTR’s):

Hr Total DAM TUC Stlmnt ($) =Hr DAM TUC Loss Stlmnt ($) - Hr DAM TUC Cong Stlmnt ($) = $50 – ($0) = $50



Balancing Market TUC




Balancing Market Transmission Usage Charge (TUC) settlement for Import, Export, Wheel-Through, and Internal Transactions:

• Intended to charge any additional TUC’s (as a result of additional transaction bidding) to Transaction Customers with bilateral Transaction Contracts in the NYISO HAM for usage of the NYCA transmission grid (losses and congestion).

• Transaction Customers holding Grandfathered Transmission Rights (GTR) may be exempt (up to a pre-determined MW amount) from paying the congestion component of the TUC.

Balancing Market TUC - TC


References



• DSS Corporate Report: ‘Settlement Detail Report – Transaction Customer –Balancing Energy TUCs’



Flow Chart




Corporate Report:Transaction Customer Balancing Energy TUCs




Import Transactions· Transaction Contract is HAM Bilateral Import Transaction

– Source Location is NYISO external control area proxy bus– Sink Location is NOT NYISO market reference proxy bus– TransCnt Transaction Category = Import

· Transaction Contract is bid into NYISO HAM above that in DAM

Note: If import transaction is curtailed, scheduling party purchases replacement energy. Reference section 1.3.8 of B&A Manual.




Export Transactions· Transaction Contract is Real-Time Bilateral Export

Transaction– Source Location is a NYISO generation bus – Sink Location is NYISO external proxy bus– TransCnt Transaction Category = Export

· Transaction Contract is scheduled in NYISO Real-Time Market in excess of DAM




Wheel-Through Transactions· Transaction Contract is Real-Time Bilateral Wheel-

Through Transaction– Source Location is a NYISO external proxy bus – Sink Location is a NYISO external proxy bus– TransCnt Transaction Category = Wheel-Through





Internal Transactions· Transaction Contract is Real-Time Bilateral Internal

Transaction– Source Location is a NYISO load bus – Sink Location is a NYISO generation bus– TransCnt Transaction Category = Internal




Inputs• SCD RT Loss Price :Sink ($/MW)• SCD RT Loss Price :Src ($/MW)• SCD RT Cong Price :Sink ($/MW)• SCD RT Cong Price :Src ($/MW)• Hr DAM Trans Bid Fixed Energy (MW)• Hr HAM Trans Bid Fixed Energy (MW)• Hr DAM Sched Trans :Trans (MW)• SCD RT Sched Trans :Trans (MW)• SCD Interval Seconds



Outputs

SCD Total BalMkt TUC Stlmnt ($)

Note: Hr Total BalMkt TUC Stlmnt ($) - Bill Code 508

= ∑ SCD Total BalMkt TUC Stlmnt ($)

Day Total BalMkt TUC Stlmnt ($) - Bill Code 757= ∑ Hr Total BalMkt TUC Stlmnt ($)




SCD Total BalMkt TUC Stlmnt ($) =SCD BalMkt TUC Loss Stlmnt ($)

- SCD BalMkt TUC Cong Stlmnt ($)




Note:

For Imports:SCD BalMkt TUC Sched (MW) =

Max { Hr DAM Trans Bid Fixed Energy (MW), Hr HAM Trans Bid Fixed Energy (MW) } - Hr DAM Trans Bid Fixed Energy (MW)

For Exports, Wheel-Throughs, and Internals:SCD BalMkt TUC Sched (MW) =

SCD RT Sched Trans :Trans (MW) - Hr DAM Sched Trans :Trans (MW)



ExampleAssume transaction is an Export.

SCD BalMkt TUC Sched (MW) ={SCD RT Sched Trans :Trans (MW) - Hr DAM Sched Trans :Trans (MW)}

* SCD Interval Seconds ÷ 3600 seconds= (70 MW – 50 MW) * 270 ÷ 3600 = 1.5 MW

Note: Hr BalMkt TUC Sched (MW) = Σ SCD BalMkt TUC Sched (MW) B.C. 505Day BalMkt TUC Sched (MW) = Σ Hr BalMkt TUC Sched (MW) B.C. 754

SCD BalMkt TUC Loss Stlmnt ($) =SCD BalMkt TUC Sched (MW) * { SCD RT Loss Price :Sink ($/MW) –

SCD RT Loss Price :Src ($/MW) }= 1.5 MW * { $3/MW - $2/MW } = $1.50

Note: Hr BalMkt TUC Loss Stlmnt ($) = Σ SCD BalMkt TUC Loss Stlmnt ($) B.C. 506Day BalMkt TUC Loss Stlmnt ($) = Σ Hr BalMkt TUC Loss Stlmnt ($) B.C. 755



Example cont.

SCD BalMkt TUC Cong Stlmnt ($) =SCD BalMkt TUC Sched (MW) * { SCD RT Cong Price :Sink ($/MW) –

SCD RT Cong Price :Src ($/MW) } = 1.5 MW * { -$11 – (-$7) } = -$6.00

Note: Hr BalMkt TUC Cong Stlmnt ($) = Σ SCD BalMkt TUC Cong Stlmnt ($) B.C. 507Day BalMkt TUC Cong Stlmnt ($) = Σ Hr BalMkt TUC Cong Stlmnt ($) B.C. 756

SCD Total BalMkt TUC Stlmnt ($) =SCD BalMkt TUC Loss Stlmnt ($) - SCD BalMkt TUC Cong Stlmnt ($)= $1.50 – (-6.00) = $7.50

Note: Hr Total BalMkt TUC Stlmnt ($) = Σ SCD Total BalMkt TUC Stlmnt ($) B.C. 508Day Total BalMkt TUC Stlmnt ($) = Σ Hr Total BalMkt TUC Stlmnt ($) B.C. 757




Note: • Emergency Corrective Actions (ECA’s) and Financial Impact

Charges (FIC’s) are also applicable to the Balancing Market TUC Settlement.

• Outputs:Hr Fin Impact Ch Stlmnt :Trans ($) - Bill Code 530Day Fin Impact Ch Stlmnt :Trans ($) - Bill Code 776

• References: Market Services Tariff Article 4, Section 4.5 & SMD2 Draft B&A Manual, Section 3.2.3



Day-Ahead Market Transaction BPCG




• Intended to guarantee a Transaction Customer, who is importing energy into the NYCA for sale to the NYISO DAM, does not incur a net DAM loss relative to the Transaction Contract’s determined Bid Production Costs

Day-Ahead Market Transaction BPCG - TC



• Market Energy Import Transactions are flows of energy requested by Market Participants (acting as Transaction Customers) and scheduled by the NYISO from NYCA-external suppliers who offer their resources to the NYISO wholesale energy markets.

• These transactions are scheduled with a NYISO external proxy bus (represents an external control area) as the scheduled Point of Injection (POI) and the NYISO reference bus (represents the NYISO energy markets) as the scheduled Point of Withdrawal (POW). – Real-Time Transactions are scheduled in the Security

Constrained Dispatch (SCD) scheduling process, – DAM Transactions are scheduled in the DAM

transaction scheduling process (SCUC).




• The DAM Transaction BPCG ($) settlement is based upon the Transaction Contract’s determined Bid Production Costs (DAM scheduled energy (MW) times the DAM Transaction Bid Decremental Dollar ($/MW)) minus its DAM Energy Revenue ($).

• It is determined at the daily-level for each Market Energy Import Transaction Contract scheduled in the NYISO DAM.



References

• Tariff• Billing & Accounting Manual

– 1.3.3• DSS Corporate Report

– Settlement Detail Report - Transaction Customer - Day Ahead Market Bid Production Cost Guarantee



DSS Elements

TransCnt Transaction CategoryTransaction Category represents the category in which the given transaction belongs

(import, export, wheel-through, internal)TransCnt Transaction TypeTransaction Contract Transaction Type represents the type of the given transaction,

based on whether the transaction is buying/selling energy from/to the NYISO-administered markets (values are LBMP or TUC).

Hr DAM Sched Trans :Trans (MW)Day Ahead Market Scheduled Transaction Energy (MW) is a number representing the

amount of energy scheduled for the given transaction by the NYISO in the Day Ahead Market

Hr DAM Trans Bid Decr Dollar ($/MW)Day Ahead Market Transaction Bid Decremental Bid Cost ($/MW) is a number

representing the price at which the NYISO should schedule the given transaction, based on DAM market prices at the proxy buses



DSS Elements

Hr DAM Total LBMP Stlmnt ($)Total Day Ahead Market LBMP Settlement ($) is a number representing the total BAS-

determined LBMP energy settlement for the given transaction in the NYISO Day Ahead Market; sum of the DAM LBMP energy components (energy, loss, & congestion)

Hr DAM LBMP Energy (MWh)Day Ahead Market Scheduled LBMP Transaction Energy (MWh) is a number representing the

amount of energy scheduled for the given transaction by the NYISO in the Day Ahead Market for LBMP import/export transactions to/from the NYISO Reference Bus

Hr DAM Trans Net Cost ($)Hourly Real-Time Transaction Net Cost ($) is a number representing the BAS-determined

amount of balancing market transaction LBMP revenue net of the calculated production cost of the corresponding balancing market energy (for external generators selling energy in the NYISO balancing market)

Day DAM Trans BPCG ($)Day Ahead Market Transaction Bid Production Cost Guarantee Settlement ($) is a number

representing the BAS-determined payment to ensure cost recovery for the given transaction (external generator) in the NYISO day ahead market



Flow Chart

InvoiceLSE TRANSACTIONS LBMP

Daily Bill Codes768

DAM Bid Cost Guarantee


DAM Bid Cost Guarantee

Settlement Detail Report –Transaction Customer – Day Ahead Market Bid Production Cost Guarantee




Transaction Customers will receive a payment for Day Ahead Market (DAM) Transaction Bid Production Cost Guarantee (BPCG) ($) if all of the following conditions exist:

The Transaction Contract is a DAM Energy Import Transaction

• Source Location is a NYISO external control area proxy bus

• Sink Location is the NYISO market reference proxy bus

• TransCnt Transaction Category = Import

The transaction contract is scheduled in the NYISO DAM (Hr DAM Sched Trans :Trans (MW) > 0).

The sum of all hours for the given day of the given transaction contract’s determined DAM Bid Production Cost ($) exceeds its DAM Energy Revenue ($) (Day DAM Trans BPCG ($) > 0).




Day DAM Trans BPCG ($) is calculated as:

If the given Transaction Contract is a Market Energy Import Transaction:

– TransCnt Transaction Type = “LBMP”

– TransCnt Transaction Category = “Import”

If the sum of all hours for the given day of

Hr DAM Trans Net Cost ($) > 0:

Day DAM Trans BPCG ($) = sum of all hours for the given day of Hr DAM Trans Net Cost ($).



Settlement AlgorithmOtherwise:Day DAM Trans BPCG ($) = 0.Where Hr DAM Trans Net Cost ($) is calculated as:Hr DAM Trans Net Cost ($) = [Hr DAM LBMP Energy (MWh) * Hr DAM Trans Bid Decr

Dollar ($/MW)} - Hr DAM Total LBMP Stlmnt ($)



Example

Data-• 50 MW scheduled in DAM (Ontario to New

York)• HB 7 May 12, 2004• Dec Bid = $100/MW• DAM LBMP $50



Example

• The transaction loses ($50/MW) Hr DAM Trans Net Cost ($) = [Hr DAM LBMP Energy (MWh) * Hr DAM Trans Bid Decr

Dollar ($/MW)} - Hr DAM Total LBMP Stlmnt ($)= (50 MW * $100) - ((50 MW) * $50)= $5,000 – $2,500= $2,500 (Transaction lost money, it was uneconomic)

Sum all the hours for the day• If the sum of the day is a positive the transaction would receive a DAM BPCG payment• If the sum for the day is negative the transaction made money and the payment will be $0.



Notes

• Very similar to Power Suppliers BPCG payment• The calculation remains the same pre and post

SMD



Real-Time Transaction BPCG




• Intended to guarantee a Transaction Customer, who is importing energy into the NYCA for sale to the NYISO Real-Time Market, does not incur a net Balancing Market loss relative to the Transaction Contract’s determined Bid Production Costs

Real-Time Transaction BPCG - TC



• Market Energy Import Transactions are flows of energy requested by Market Participants (acting as Transaction Customers) and scheduled by the NYISO from NYCA-external suppliers who offer their resources to the NYISO wholesale energy markets.

• These transactions are scheduled with a NYISO external proxy bus(represents an external control area) as the scheduled Point of Injection (POI) and the NYISO reference bus (represents the NYISO energy markets) as the scheduled Point of Withdrawal (POW). – Real-Time Transactions are scheduled in the Security

Constrained Dispatch (SCD) scheduling process, – DAM Transactions are scheduled in the DAM transaction

scheduling process (SCUC).



• The RT Transaction BPCG ($) settlement is based upon the Transaction Contract’s determined Bid Production Costs (net RT scheduled energy (MW) times the HAM Transaction Bid Decremental Dollar ($/MW)) minus its Balancing Market Energy Revenue ($).

• It is determined at the daily-level for each Market Energy Import Transaction Contract scheduled in the NYISO RT market.


References

• Tariff• Billing & Accounting Manual

– 1.3.4• DSS Corporate Report

– Settlement Detail Report - Transaction Customer – Real-Time Bid Production Cost Guarantee



DSS Elements

• TransCnt Transaction Category– Transaction Category represents the category in which the given transaction

belongs (import, export, wheel-through, internal)• TransCnt Transaction Type

– Transaction Contract Transaction Type represents the type of the given transaction, based on whether the transaction is buying/selling energy from/to the NYISO-administered markets (values are LBMP or TUC).

• SCD RT Sched Trans :Trans (MW)– Real Time Scheduled Transaction Energy (MW) is a number representing the

total amount of transaction energy scheduled in real time for a given transaction, injected at a given generator, for an SCD interval.

• Hr DAM Sched Trans :Trans (MW)– Day Ahead Market Scheduled Transaction Energy (MW) is a number representing

the amount of energy scheduled for the given transaction by the NYISO in the Day Ahead Market


DSS Elements

• Hr HAM Trans Bid Decr Dollar ($/MW)– Hour Ahead Market Transaction Bid Decremental Bid Price ($/MW) is a

number representing the price at which the NYISO should schedule the given transaction, based on HAM market prices at the proxy buses

• SCD BalMkt Total LBMP Stlmnt ($)– Balancing Market Total LBMP Energy Settlement is a number representing the

BAS-determined LBMP energy total settlement for the given transaction in the NYISO balancing market; is the sum of the balancing market LBMP energy, loss, and congestion components

• SCD Interval Seconds– SCD Interval Seconds is a number representing the number of seconds in the

SCD interval• SCD BalMkt LBMP Energy (MWh)

– Balancing Market LBMP Energy (MWh) is a number representing the BAS-determined amount of balancing market LBMP energy for the given transaction "


DSS Elements

• SCD RT Trans Net Cost ($)– SCD-level Real-Time Transaction Net Cost ($) is a number representing the

BAS-determined amount of balancing market transaction LBMP revenue net of the calculated production cost of the corresponding balancing market energy (for external generators selling energy in the NYISO balancing market)

• Hr RT Trans Net Cost ($)– Hourly Real-Time Transaction Net Cost ($) is a number representing the BAS-

determined amount of balancing market transaction LBMP revenue net of the calculated production cost of the corresponding balancing market energy (for external generators selling energy in the NYISO balancing market)

• Day RT Trans BPCG ($)– Real-Time Transaction Bid Production Cost Guarantee Settlement ($) is a

number representing the BAS-determined payment to ensure cost recovery for the given transaction (external generator) in the NYISO balancing market


Flow Chart

InvoiceLSE TRANSACTIONS LBMP

Daily Bill Codes769

R/T Bid Cost Guarantee


R/T Bid Cost Guarantee

Settlement Detail Report –Transaction Customer – Real-Time Bid Production Cost Guarantee




Transaction Customers will receive a payment for Real-Time Transaction Bid Production Cost Guarantee (BPCG) ($) if all of the following conditions exist:

The Transaction Contract is an Energy Import Transaction

– Source Location is a NYISO external control area proxy bus

– Sink Location is the NYISO market reference proxy bus

– TransCnt Transaction Category = Import

The Transaction Contract’s RT Schedule exceeds its DAM Schedule (SCD RT Sched Trans :Trans (MW) > Hr DAM Sched Trans :Trans (MW)).




• Where Hr RT Trans Net Cost ($) is calculated as:• Hr RT Trans Net Cost ($) = sum of all SCD-intervals for the given hour

of SCD RT Trans Net Cost ($).

• Where SCD RT Trans Net Cost ($) is calculated as:– SCD RT Trans Net Cost ($) = {SCD BalMkt LBMP Energy (MWh) * Hr HAM Trans Bid Decr Dollar

($/MW)} - SCD BalMkt Total LBMP Stlmnt ($)

• And SCD BalMkt LBMP Energy (MWh) =

{SCD RT Sched Trans :Trans (MW) - Hr DAM Sched Trans :Trans (MW)} * {SCD Interval Seconds ÷ 3,600}



Settlement AlgorithmDay RT Trans BPCG ($) is calculated as:

If the given Transaction Contract is a Market Energy Import Transaction: • TransCnt Transaction Type = “LBMP” • TransCnt Transaction Category = “Import”

If the sum of all hours for the given day of Hr RT Trans Net Cost ($)>0:Day RT Trans BPCG ($) = sum of all hours for the given day of Hr RT Trans Net Cost($)

Otherwise:Day RT Trans BPCG ($) = 0.

Where Hr RT Trans Net Cost ($) is calculated as:Hr RT Trans Net Cost ($) = sum of all SCD-intervals for the given hour of SCD RT Trans Net Cost ($)

Where SCD RT Trans Net Cost ($) is calculated as: SCD RT Trans Net Cost ($) =

{SCD BalMkt LBMP Energy (MWh) * Hr HAM Trans Bid Decr Dollar ($/MW)} -SCD BalMkt Total LBMP Stlmnt ($)

And SCD BalMkt LBMP Energy (MWh) ={SCD RT Sched Trans :Trans (MW) - Hr DAM Sched Trans :Trans (MW)} * {SCD Interval Seconds ÷ 3,600}



Example

Data-• 50 MW scheduled in real-time (Ontario to New

York)• The interval length is 300 seconds (11:00:00 –

11:05:00)• Dec Bid = $100/MW• RT LBMP $50 • No MW’s scheduled Day Ahead



Example

• The transaction loses ($50/MW) SCD RT Trans Net Cost ($) =

[SCD BalMkt LBMP Energy (MWh) * Hr HAM Trans Bid Decr Dollar ($/MW)] -SCD BalMkt Total LBMP Stlmnt ($)

= (50 MW * $100) - ((50 MW – 0 MW) * $50)= $5,000 – $2,500= $2,500 * 300 / 3600= $208.33 (Transaction lost money, it was uneconomic)

Sum all the SCD/RTD intervals for the day• If the sum of the day is a positive the transaction would receive a RT BPCG payment• If the sum for the day is negative the transaction made money and the payment will be $0.



Transmission Congestion Contract




• Intended to credit or charge holders of Transmission Congestion Contract Capacity in the NYISO Day Ahead Market

Transmission Congestion Contract - TC



• The Transmission Congestion Contract Settlement (TCC Rent) ($) is intended to credit or charge holders of Transmission Congestion Contract Capacity in the NYISO Day Ahead Market.




• Transmission Congestion Contract Customers are Market Participants who obtain transmission congestion contract capacity (through either regular auctions or via the conversion of grandfathered transmission rights)

• Used to hedge against Day Ahead Market transmission congestion costs.

• TCCs can also be used purely as an investment for transmission congestion over a specified contract path.




• Transmission Congestion Contract (TCC) holders are paid a settlement (TCC Rent) which is based on the difference between DAM congestion prices at the contract’s point of withdrawal (POW) and point of injection (POI), multiplied times the amount of TCC capacity (MW) held.

• The settlement is determined at the hourly-level for each Transmission Congestion Contract.



References

• Tariff – OATT– Attachment M Sale of TCC– Attachment N Congestion Settlements related to

the Day-Ahead Market and TCC Auction Settlements

• Billing & Accounting Manual Section 1.5 Transmission Congestion Contract Holders

• DSS Corporate Report -Settlement Detail Report - Transmission Congestion Contract Customer - TCC Rent



Flow Chart

InvoicePower Supplier

Daily Bill Codes903 TCC credit

Hourly Bill Codes901 TCC credit

Corporate ReportTCC Rent



Eligibility Rules / RequirementsTransmission Congestion Contract Customers will be credited or

charged for TCC Rent ($) if:

• The Transmission Congestion Contract Customer is the holder of Transmission Congestion Contract Capacity (MW) in the NYISO DAM (Hr TCC Capacity (MW) > 0).

• The Transmission Congestion Contract is one of the following types:

» Primary (Original Owner)» Recon-Purchase (Sale from Original Owner)» Recon-Release (Corresponding Purchase)» These contract types reflect a TCC’s ability to be

reconfigured in the monthly auction. Owner can have a 6 month TCC and then sell a portion or all the MW rights to a 3rd party via the monthly reconfiguration auction.



Data ElementsHr DAM Cong Price :Sink ($/MW)Hourly Day Ahead Market Congestion Price - Sink ($/MW) is a number

representing the day ahead market price of congestion component at a transmission congestion contract's point of withdrawal.

Hr DAM Cong Price :Src ($/MW)Hourly Day Ahead Market Congestion Price - Source ($/MW) is a number

representing the day ahead market price of congestion component at a transmission congestion contract's point of injection.

Capability PeriodCapability Period represents the capability period that the day falls in (either

Winter or Summer)Hr TCC Capacity :Winter (MW)Hourly Transmission Congestion Contract Capacity -Winter (MW) is a

number representing the amount of capacity during the winter capability period for the given transmission congestion contract for the given hour.



Data Elements

Hr TCC Capacity :Summer (MW)Hourly Transmission Congestion Contract Capacity -Summer (MW) is a

number representing the amount of capacity during the summer capability period for the given transmission congestion contract for the given hour.

TCC GTR IndTransmission Congestion Contract (TCC) Grand-Fathered Transmission

Rights (GTR) Indicator is a character representing whether or not the given TCC has been converted to Grand-Fathered Transmission Rights.

TCC Contract TypeTransmission Congestion Contract (TCC) Contract Type represents the

type of TCC modeled, either the primary TCC, or the sale/purchase TCCs made via 3rd party transactions.



Data Elements

Hr TCC Capacity (MW)Hourly Transmission Congestion Contract Capacity (MW) is a number

representing the amount of capacity for the given transmission congestion contract for the given hour.

Hr TCC Rent Stlmnt ($)Hourly Transmission Congestion Contract Rent Settlement ($) is a number

representing the amount of transmission congestion contract (TCC) rent being paid to the TCC holder for the given hour.



Tariff




The DAM Congestion Prices ($/MW) for the Source and Sink locations of the TCC are:– The TCC Rent settlement is determined using the

difference in DAM Congestion Prices ($/MW) at the TCC’s Point Of Withdrawal (POW/sink) and Point Of Injection (POI/source).

• The actual prices used in this settlement will vary based on the definition of the TCC’s POW and POI




• POW/Sink DAM Congestion Prices (Hr DAM Cong Price :Sink ($/MW))

If the TCC POW is the NYISO Reference Bus, the settlement will be made using the NYISO Reference Bus’ DAM Congestion Price ($/MW).

– Else the settlement will be made using the Zonal DAM Congestion Price ($/MW) corresponding to the TCC’s POW.




POI/Source DAM Congestion Prices (Hr DAM Cong Price :Src ($/MW))

– The settlement will be made using either the POI (generator) DAM Congestion Price ($/MW), or

– Zonal DAM Congestion Price ($/MW), depending on the definition of the TCC’sPOI.



Settlement AlgorithmHr TCC Rent Settlement ($) is calculated as:

Hr TCC Rent Stlmnt ($) = Hr TCC Capacity (MW) * {Hr DAM Cong Price :Sink

($/MW) - Hr DAM Cong Price :Src ($/MW)}

Where Hr TCC Capacity (MW) is: If Capability Period = “SUMMER” Hr TCC Capacity (MW) = Hr TCC Capacity :Summer (MW)

Else (Capability Period = “WINTER”) Hr TCC Capacity (MW) = Hr TCC Capacity :Winter (MW)



Example

• The TCC holders has a 100 MW TCC from Sink (Load, POW) A to Source (Generator, POI) B.

• Hour Beginning 7• Sink Congestion = $15 /MW• Source Congestion = $5 /MW• 100 MW * ($15 - $5)• $1,000 payment to TCC holder



Day-Ahead Market Congestion Residual




• Any identified amounts where NYISO is not revenue neutral are called residuals.

• Residuals are the net difference between related total credits and charges, and are created from settlements where NYISO has customer settlements both to pay suppliers and to charge load/transaction customers.

Day-Ahead Market Congestion Residual - TC



• The TO DAM Congestion Residual settlement is based upon the NYISO Total DAM Congestion Residual ($) times the Transmission Owner’s MW-Mile Coefficient.

• It is determined at the daily-level for each TO that is responsible for transmission capacity of transmission line within the New York Control Area (NYCA).



References

• Tariff Attachment N • Billing & Accounting Manual 1.7.1• DSS Corporate Report

– Settlement Details - DAM Excess Cong Residual for Transmission Owners

• LINK– http://www.nyiso.com/markets/billing.html



Flow Chart

InvoiceTRANSMISSION PROVIDERS DATE –

NTAC and Cong Credit

Daily Bill Codes1013 IMWM Coefficient

1014 Excess Cong Credit $

Hourly Bill CodesOnly appears on Daily

Statement

Settlement Details –DAM Excess Cong Residual for Transmission Owners




Transmission Owners will receive a charge or payment for DAM Congestion Residuals ($) if all of the following conditions exist:

– The Transmission Owner is responsible for transmission capacity of transmission line within the NYCA (Interface MW/Mile Coefficient > 0).

– There is a NYISO DAM Congestion Residual ($) for the given day (Day Total NYISO DAM ResidCong ($) <> 0).



Example of Co-efficients



Tariff Formula

• See OATT Attachment N– Very detailed and complex rules– Only relates to owners of transmission

assets– Nothing changes in SMD 2.0



Inputs


Day Ttl NYISO DAMTUC CngCh :TC ($)Day Ttl NYISO DAMLBMP CngCh:TC ($)

Day Ttl NYISO DAM Cng Ch to LSE ($)

Day Ttl NYISO DAM TCC Cong Cr ($)

Day Ttl NYISO DAM Cng Cr to PS ($)Day Total NYISO DAM Resid Cong ($)Interface MW/Mile Coefficient



Day DAM Residual Congestion Settlement :TO ($) is calculated as:

Day DAM Residual Congestion Settlement :TO ($) = Interface MW/Mile Coefficient * DAM Residual Congestion ($)

Where: DAM Residual Congestion ($) =

DAM Congestion Credit to Power Suppliers ($) plusDAM TCC Congestion Credits ($) lessDAM Congestion Charge to LSE ($) plusLBMP Congestion Charge: TC ($) plusDAM TUC Congestion Charge: TC ($)




• Example –– Power Suppliers where paid $750 in

congestion credits– TCC holders where paid $250 in congestion

credits– LSE paid $400 in congestion charges– TO’s paid $650 in congestion charges– Bilaterals where assessed $50 in TUC

charges– TO X has 40% has a MW-Mile Coefficient




• ($750 + $250) – ($400 + $650 + $50)• $1,000 - $1,100• ($100)• 40% * ($100) = ($40)

– TO X needs to pay $40 so NYISO remains revenue neutral



ANCILLARY SERVICES


Ancillary Services Description

• NYISO operates the New York Control Area (NYCA) and its markets using two key tariffs: the Market Administration and Control Services Tariff (MST) and the Open Access Transmission Tariff (OATT). The MST defines the market requirements, rules, and procedures for Market Participants participating in the NYISO administered energy and ancillary service markets (i.e. DAM, HAM, RT, etc.). The OATT defines the regulations, requirements, and procedures for Market Participants in order to obtain access to the NYISO controlled NYCA transmission network.


Who Pays for Services?


MST Schedule 1 (S, SC, & D)

Ancillary Services

Ancillary Services



MST Schedule 1 (S, SC, & D) - AS

• All of NYISO operating costs for scheduling, system control, and dispatch (S, SC &D) are allocated to Load Serving Entities (LSE) and Transaction Customers (TC) (exports and wheel-throughs only) through charges under Schedule 1. The estimated annual NYISO operating costs are determined, then a MST Schedule 1 Rate ($/MW) is determined using estimated load. This rate is then used over the year to recover the estimated annual NYISO operating costs.


References

• Tariff: Market Services Tariff Schedule 1

• Billing & Accounting Manual: Version 1.24, Section 1.2.3.1.1 & 1.3.10.1.1

• DSS Corporate Reports: • Settlement Details – Ancillary Services for Load Serving

Entities• Settlement Details – Ancillary Services for Transaction

Customers

NYISO Proprietary InformationMST Schedule 1 (S, SC, & D) - AS


Flow Chart

InvoiceAncillary Services



Corporate Reports:Ancillary Services for Load Serving Entities

Ancillary Services for Transaction Customers



Eligibility Rules / Requirements• The Load Serving Entity purchased energy to

meet their load requirements from the NYISO energy markets(Hr RT LSE Load (MW) > 0).

• The Transaction Customer scheduled real-time export or wheel-through energy within the NYCA (Hr RT Export Trans :TC (MW) > 0) or (Hr RT Wheel-Thru Trans :TC (MW) > 0).

• NOTE: Hr RT LSE Load (MW) is the sum of market energy purchased from NYISO plus import and internal bilateral transaction energy purchased from 3rd Parties.



Inputs

• Hr MST Sched 1 Rate ($/MW) - Bill Code 607• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602



Outputs

• Hr MST Sched 1 Stlmnt :LSE ($) - Bill Code 608• Hr MST Sched 1 Stlmnt :TC ($) - Bill Code 608

Note:Day MST Sched 1 Stlmnt :LSE ($) - Bill Code 805= Σ Hr MST Sched 1 Stlmnt :LSE ($)

Day MST Sched 1 Stlmnt :TC ($) - Bill Code 805= Σ Hr MST Sched 1 Stlmnt :TC ($)




Hr MST Sched 1 Stlmnt :LSE ($) = Hr MST Sched 1 Rate ($/MW) *Hr RT LSE Load (MWh)

Hr MST Sched 1 Stlmnt :TC ($) = Hr MST Sched 1 Rate ($/MW) * {Hr RT Export Trans :TC (MWh) +

Hr RT Wheel-Thru Trans :TC (MWh)}



OATT Schedule 1 (S, SC, & D)

Ancillary Services

Ancillary Services



OATT Schedule 1 (S, SC, & D) - AS

• All of NYISO operating costs for scheduling, system control, and dispatch (S, SC &D) are allocated to Load Serving Entities (LSE) and Transaction Customers (TC) (exports and wheel-throughs only) through charges under Schedule 1. The estimated annual NYISO operating costs are determined, then an OATT Schedule 1 Rate ($/MW) is determined using estimated load. This rate is then used over the year to recover the estimated annual NYISO operating costs.


References

• Tariff: Open Access Transmission TariffSchedule 1


• DSS Corporate Report:• Settlement Details – Ancillary Services for Load Serving


Customers

NYISO Proprietary InformationOATT Schedule 1 (S, SC, & D) - AS


Flow Chart








Eligibility Rules / Requirements• The Load Serving Entity purchased energy to meet

their load requirements from the NYISO energy markets(Hr RT LSE Load (MW) > 0).





Inputs

• Hr OATT Sched 1 Rate ($/MW) - Bill Code 614• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602



Outputs

• Hr OATT Sched 1 Stlmnt :LSE ($) - Bill Code 615• Hr OATT Sched 1 Stlmnt :TC ($) - Bill Code 615

Note:Day OATT Sched 1 Stlmnt :LSE ($) - Bill Code 809= Σ Hr OATT Sched 1 Stlmnt :LSE ($)

Day OATT Sched 1 Stlmnt :TC ($) - Bill Code 809= Σ Hr OATT Sched 1 Stlmnt :TC ($)




Hr OATT Sched 1 Stlmnt :LSE ($) = Hr OATT Sched 1 Rate ($/MW) *Hr RT LSE Load (MWh)

Hr OATT Sched 1 Stlmnt :TC ($) = Hr OATT Sched 1 Rate ($/MW) * {Hr RT Export Trans :TC (MWh) +




OATT Schedule 2 –Voltage Support Service

Ancillary Services

Ancillary Services



OATT Schedule 2 – Voltage Support Service - AS

• The NYISO procures Voltage Support Services (VSS) from Power Suppliers in the New York Control Area (NYCA) in order to ensure that appropriate voltage levels are maintained on the NYCA transmission network. Voltage is a critical component of providing quality and reliable electric service (also helps to minimize losses; higher voltage levels on the transmission network allow for longer transmission distances), and therefore is required. Poor voltage levels will lead to poor electric service.

• All of NYISO’s costs for procuring VSS are allocated to Load Serving Entities (LSE) and Transaction Customers (TC) (exports and wheel-throughs only) through charges under OATT Schedule 2. The estimated annual NYISO VSS costs are determined, then a VSS rate ($/MW) is determined using estimated load. This rate is used over the year to recover the estimated annual NYISO VSS costs.


References



• DSS Corporate Report: • Settlement Details – Ancillary Services for Load Serving


CustomersOATT Schedule 2 – Voltage Support Service - AS


Flow Chart









• The Load Serving Entity purchased energy to meet their load requirements from the NYISO energy markets (Hr RT LSE Load (MW) > 0).





Inputs

• Hr VSS Rate ($/MW) - Bill Code 605• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602



Outputs

• Hr VSS Stlmnt :LSE ($) - Bill Code 606• Hr VSS Stlmnt :TC ($) - Bill Code 606

Note:Day VSS Stlmnt :LSE ($) - Bill Code 804= Σ Hr VSS Stlmnt :LSE ($)

Day VSS Stlmnt :TC ($) - Bill Code 804= Σ Hr VSS Stlmnt :TC ($)




Hr VSS Stlmnt :LSE ($) = Hr VSS Rate ($/MW) *Hr RT LSE Load (MWh)

Hr VSS Stlmnt :TC ($) = Hr VSS Rate ($/MW) * {Hr RT Export Trans :TC (MWh) +




OATT Schedule 3 –Regulation & Frequency Control Service

Ancillary Services

Ancillary Services



• Regulation is part of the electrical capacity reserves procured by NYISO to be confident they will have enough resources to meet most all demand-level contingencies in real-time. It is designed to allow NYISO to balance supply and demand in real-time using small increments of increases / decreases in supply (generation) to meet small increases / decreases in measured demand (load).

• All of NYISO’s costs for procuring Regulation are allocated to Load Serving Entities (LSE) through charges under OATT Schedule 3. Transaction customers (TC) are not charged any allocations for Regulation Service given their contracts are by conceptual nature a fixed amount of scheduled energy (not variable in real-time as with load).

OATT Schedule 3 – Regulation & Frequency Control Service - AS


References

• Tariff: Open Access Transmission Tariff Schedule 3

• Billing & Accounting Manual: Version 1.24, Section 1.2.3.1.4


Entities



Flow Chart








• The Load Serving Entity purchased energy to meet their load requirements from the NYISO energy markets(Hr RT LSE Load (MW) > 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO Reg Cr to PS ($)• Hr Total NYISO Reg Chg to PS ($)



Outputs

• Hr Regulation Stlmnt :LSE ($) - Bill Code 612

Note:Day Regulation Stlmnt :LSE ($) - Bill Code 807= Σ Hr Regulation Stlmnt :LSE ($)



Settlement AlgorithmHr Regulation Stlmnt :LSE ($) =

Hr Total NYISO Net Reg Cr to PS ($) *Hr RT LSE Ld Ratio Sh :LSE

Hr Total NYISO Net Reg Cr to PS ($) = Hr Total NYISO Reg Cr to PS ($) -Hr Total NYISO Reg Chg to PS ($)

Hr RT LSE Ld Ratio Sh :LSE =Hr RT LSE Load (MWh) /Hr Total NYISO RT LSE Load (MWh)



OATT Schedule 5 –Operating Reserve Service

Ancillary Services

Ancillary Services



• The NYISO procures Operating Reserve Services from Power Suppliers in the New York Control Area (NYCA) in order to ensure that enough electric supply is available in real-time to meet demand requirements (if actual demand significantly exceeds forecasted demand, or in cases of the loss of other expected supply resources).

• All of NYISO’s costs for procuring Operating Reserve Services are allocated to Load Serving Entities (LSE) and Transaction Customers (TC) (exports only) through charges under OATT Schedule 5.

OATT Schedule 5 – Operating Reserve Service - AS


References





Customers



Flow Chart










• The Transaction Customer scheduled real-time export energy within the NYCA (Hr RT Export Trans :TC (MW) > 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO Op Res Cr to PS ($)• Hr Total NYISO Op Res ShtChg to PS ($)



Outputs

• Hr Op Res Stlmnt :LSE ($) - Bill Code 610• Hr Op Res Stlmnt :TC ($) - Bill Code 610

Note:Day Op Res Stlmnt :LSE ($) - Bill Code 806= Σ Hr Op Res Stlmnt :LSE ($)

Day Op Res Stlmnt :TC ($) - Bill Code 806= Σ Hr Op Res Stlmnt :TC ($)



Settlement AlgorithmHr Op Res Stlmnt :LSE ($) =

Hr Total NYISO Net Op Res Cr to PS ($) *Hr RT LSE Ld Ratio Sh :LSE & Exp

Hr Total NYISO Net Op Res Cr to PS ($) = Hr Total NYISO Op Res Cr to PS ($) -Hr Total NYISO Op Res ShtChg to PS ($)

Hr RT LSE Ld Ratio Sh :LSE & Exp =Hr RT LSE Load (MWh) /{Hr Total NYISO RT LSE Load (MWh) +Hr Total NYISO RT Export Trans (MWh)}



Settlement AlgorithmHr Op Res Stlmnt :TC ($) =

Hr Total NYISO Net Op Res Cr to PS ($) *Hr RT TC Ld Ratio Sh :LSE & Exp

Hr Total NYISO Net Op Res Cr to PS ($) = Hr Total NYISO Op Res Cr to PS ($) -Hr Total NYISO Op Res ShtChg to PS ($)

Hr RT TC Ld Ratio Sh :LSE & Exp =Hr RT Export Trans :TC (MWh) /{Hr Total NYISO RT LSE Load (MWh) +Hr Total NYISO RT Export Trans (MWh)}



OATT Schedule 6 –Black Start Service

Ancillary Services

Ancillary Services



• The NYISO procures Black Start Services from Power Suppliers in the New York Control Area (NYCA) in order to ensure that in the worst case scenario of a complete power blackout, specifically configured power supply resources (generators) are capable of ramping-up without station service power form the NYCA grid.

• All of NYISO’s costs for procuring Black Start Service are allocated to Load Serving Entities (LSE) through charges under OATT Schedule 6.

OATT Schedule 6 – Black Start Service - AS


References




Entities



Flow Chart







Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO Black Start Cost ($)



Outputs

• Hr Black Start Stlmnt :LSE ($) - Bill Code 613

Note:Day Black Start Stlmnt :LSE ($) - Bill Code 808= Σ Hr Black Start Stlmnt :LSE ($)



Settlement AlgorithmHr Black Start Stlmnt :LSE ($) =

Hr Total NYISO Black Start Cost ($) *Hr RT LSE Ld Ratio Sh :LSE

Hr RT LSE Ld Ratio Sh :LSE =Hr RT LSE Load (MWh) /Hr Total NYISO RT LSE Load (MWh)



RESIDUALS


Residuals Description

• The NYISO was created as a non-profit organization; therefore it should be revenue neutral (income from charges should equal payments for credits). So, the NYISO customer settlements rules need to identify and address any scenarios where they are not revenue neutral.

• Any identified amounts where NYISO is not revenue neutral are called residuals. Residuals are the net difference between related total credits and charges, and are created from settlements where NYISO has customer settlements both to pay suppliers and to charge load/transaction customers. Residuals are typically allocated to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given period.

• Residuals identified from the DAM Energy, DAM Loss, Balancing Market Energy, Balancing Market Loss, or Balancing Market Congestion settlements are typically addressed under customer settlement allocations. Other identified residual amounts are addressed differently (notably DAM Congestion).


DAM Energy Residual

Ancillary Services

Residuals



DAM Energy Residual - AS

• The Load Serving Entity (LSE) Day Ahead Market (DAM) Energy Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s DAM Energy settlements to the Market Participants purchasing energy as LSEs.

• The Transaction Customer (TC) Day Ahead Market (DAM) Energy Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s DAM Energy settlements to the Market Participants transacting energy via exports and/or wheel-throughs.


References



• DSS Corporate Report:• Settlement Details – Residuals for Load Serving Entities• Settlement Details – Residuals for Transaction

CustomersDAM Energy Residual - AS


Flow Chart




Corporate Report:Residuals for Load Serving Entities

Residuals for Transaction Customers





• The Transaction Customer transacted energy via exports and/or wheel-throughs(Hr RT Export Trans :TC (MW) > 0) or (Hr RT Wheel-Thru Trans :TC (MW) > 0).

• There is a NYISO DAM Energy Residual ($) for the given hour (Hr Total NYISO DAM Resid Energy ($) <> 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr Total NYISO DAM Engy Cr to PS ($)• Hr Total NYISO DAM Engy Ch to LSE ($)• Hr Total NYISO DAM LBMP Engy Ch :TC ($)



Outputs

• Hr DAM Resid Enrgy Stlmnt :LSE ($)• Hr DAM Resid Enrgy Stlmnt :TC ($)

Note:Day DAM Resid Enrgy Stlmnt :LSE ($)= Σ Hr DAM Resid Enrgy Stlmnt :LSE ($)

Day DAM Resid Enrgy Stlmnt :TC ($)= Σ Hr DAM Resid Enrgy Stlmnt :TC ($)



Settlement AlgorithmHr DAM Resid Enrgy Stlmnt :LSE ($) =

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO DAM Resid Energy ($)

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT =Hr RT LSE Load (MWh) /{Hr Total NYISO RT LSE Load (MWh) +Hr Total NYISO RT Export Trans (MWh) +Hr Total NYISO RT WT Trans (MWh)}

Hr Total NYISO DAM Resid Energy ($) =Hr Total NYISO DAM Engy Cr to PS ($) -{Hr Total NYISO DAM Engy Ch to LSE ($) +Hr Total NYISO DAM LBMP Engy Ch :TC ($)}



Settlement AlgorithmHr DAM Resid Enrgy Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO DAM Resid Energy ($)

Hr RT TC Ld Ratio Sh :LSE, Exp, WT ={Hr RT Export Trans :TC (MWh) + Hr RT Wheel-Thru Trans :TC (MWh)} /{Hr Total NYISO RT LSE Load (MWh) +Hr Total NYISO RT Export Trans (MWh) +Hr Total NYISO RT WT Trans (MWh)}

Hr Total NYISO DAM Resid Energy ($) =Hr Total NYISO DAM Engy Cr to PS ($) -{Hr Total NYISO DAM Engy Ch to LSE ($) +Hr Total NYISO DAM LBMP Engy Ch :TC ($)}



DAM Loss Residual

Ancillary Services

Residuals



• The Load Serving Entity (LSE) Day Ahead Market (DAM) Loss Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s DAM Loss settlements to the Market Participants purchasing energy as LSEs.

• The Transaction Customer (TC) Day Ahead Market (DAM) Loss Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s DAM Loss settlements to the Market Participants transacting energy via exports and/or wheel-throughs.

DAM Loss Residual - AS


References




CustomersDAM Loss Residual - AS


Flow Chart











• There is a NYISO DAM Loss Residual ($) for the given hour (Hr Total NYISO DAM Resid Loss ($) <> 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr Total NYISO DAM Loss Cr to PS ($)• Hr Total NYISO DAM Loss Ch to LSE ($)• Hr Total NYISO DAM LBMP Loss Ch :TC ($)• Hr Total NYISO DAM TUC Loss Ch :TC ($)



Outputs

• Hr DAM Resid Loss Stlmnt :LSE ($)• Hr DAM Resid Loss Stlmnt :TC ($)

Note:Day DAM Resid Loss Stlmnt :LSE ($)= Σ Hr DAM Resid Loss Stlmnt :LSE ($)

Day DAM Resid Loss Stlmnt :TC ($)= Σ Hr DAM Resid Loss Stlmnt :TC ($)



Settlement AlgorithmHr DAM Resid Loss Stlmnt :LSE ($) =

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO DAM Resid Loss ($)


Hr Total NYISO DAM Resid Loss ($) =Hr Total NYISO DAM Loss Cr to PS ($) -{Hr Total NYISO DAM Loss Ch to LSE ($) +Hr Total NYISO DAM LBMP Loss Ch :TC ($) +Hr Total NYISO DAM TUC Loss Ch :TC ($)}



Settlement AlgorithmHr DAM Resid Loss Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO DAM Resid Loss ($)


Hr Total NYISO DAM Resid Loss ($) =Hr Total NYISO DAM Loss Cr to PS ($) -{Hr Total NYISO DAM Loss Ch to LSE ($) +Hr Total NYISO DAM LBMP Loss Ch :TC ($) +Hr Total NYISO DAM TUC Loss Ch :TC ($)}



Balancing Market Energy Residual

Ancillary Services

Residuals



Balancing Market Energy Residual - AS

• The Load Serving Entity (LSE) Balancing Market Energy Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s Balancing Market Energy settlements to the Market Participants purchasing energy as LSEs.

• The Transaction Customer (TC) Balancing Market Energy Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s Balancing Market Energy settlements to the Market Participants transacting energy via exports and/or wheel-throughs.


References



• DSS Corporate Report: • Settlement Details – Residuals for Load Serving Entities• Settlement Details – Residuals for Transaction

CustomersBalancing Market Energy Residual - AS


Flow Chart











• There is a NYISO Balancing Market Energy Residual ($) for the given hour (Hr Total NYISO Bal Resid Energy ($) <> 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr Total NYISO Bal Engy Cr to PS ($)• Hr Total NYISO Bal Engy Ch to LSE ($)• Hr Total NYISO Bal LBMP Engy Ch :TC ($)



Outputs

• Hr Bal Resid Enrgy Stlmnt :LSE ($)• Hr Bal Resid Enrgy Stlmnt :TC ($)

Note:Day Bal Resid Enrgy Stlmnt :LSE ($)= Σ Hr Bal Resid Enrgy Stlmnt :LSE ($)

Day Bal Resid Enrgy Stlmnt :TC ($)= Σ Hr Bal Resid Enrgy Stlmnt :TC ($)



Settlement AlgorithmHr Bal Resid Enrgy Stlmnt :LSE ($) =

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Bal Resid Energy ($)


Hr Total NYISO Bal Resid Energy ($) =Hr Total NYISO Bal Engy Cr to PS ($) -{Hr Total NYISO Bal Engy Ch to LSE ($) +Hr Total NYISO Bal LBMP Engy Ch :TC ($)}



Settlement AlgorithmHr Bal Resid Enrgy Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Bal Resid Energy ($)


Hr Total NYISO Bal Resid Energy ($) =Hr Total NYISO Bal Engy Cr to PS ($) -{Hr Total NYISO Bal Engy Ch to LSE ($) +Hr Total NYISO Bal LBMP Engy Ch :TC ($)}



Balancing Market Loss Residual

Ancillary Services

Residuals



Balancing Market Loss Residual - AS

• The Load Serving Entity (LSE) Balancing Market Loss Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s Balancing Market Loss settlements to the Market Participants purchasing energy as LSEs.

• The Transaction Customer (TC) Balancing Market Loss Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s Balancing Market Loss settlements to the Market Participants transacting energy via exports and/or wheel-throughs.


References



• DSS Corporate Report: • Settlement Details – Residuals for Load Serving Entities• Settlement Details – Residuals for Transaction

CustomersBalancing Market Loss Residual - AS


Flow Chart











• There is a NYISO Balancing Market Loss Residual ($) for the given hour (Hr Total NYISO Bal Resid Loss ($) <> 0).

• NOTE: Hr RT LSE Load (MW) is the sum of market energy purchased from NYISO plus import and internal bilateral transaction energypurchased from 3rd Parties.



Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr Total NYISO Bal Loss Cr to PS ($)• Hr Total NYISO Bal Loss Ch to LSE ($)• Hr Total NYISO Bal LBMP Loss Ch :TC ($)• Hr Total NYISO Bal TUC Loss Ch :TC ($)



Outputs

• Hr Bal Resid Loss Stlmnt :LSE ($)• Hr Bal Resid Loss Stlmnt :TC ($)

Note:Day Bal Resid Loss Stlmnt :LSE ($)= Σ Hr Bal Resid Loss Stlmnt :LSE ($)

Day Bal Resid Loss Stlmnt :TC ($)= Σ Hr Bal Resid Loss Stlmnt :TC ($)



Settlement AlgorithmHr Bal Resid Loss Stlmnt :LSE ($) =

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Bal Resid Loss ($)


Hr Total NYISO Bal Resid Loss ($) =Hr Total NYISO Bal Loss Cr to PS ($) -{Hr Total NYISO Bal Loss Ch to LSE ($) +Hr Total NYISO Bal LBMP Loss Ch :TC ($) +Hr Total NYISO Bal TUC Loss Ch :TC ($)}



Settlement AlgorithmHr Bal Resid Loss Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Bal Resid Loss ($)


Hr Total NYISO Bal Resid Loss ($) =Hr Total NYISO Bal Loss Cr to PS ($) -{Hr Total NYISO Bal Loss Ch to LSE ($) +Hr Total NYISO Bal LBMP Loss Ch :TC ($) +Hr Total NYISO Bal TUC Loss Ch :TC ($)}



Balancing Market Congestion Residual

Ancillary Services

Residuals



Balancing Market Congestion Residual - AS

• The Load Serving Entity (LSE) Balancing Market Congestion Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s Balancing Market Congestion settlements to the Market Participants purchasing energy as LSEs.

• The Transaction Customer (TC) Balancing Market Congestion Residual settlement ($) is designed to allocate (charge or payment) any cash imbalance in NYISO’s Balancing Market Congestion settlements to the Market Participants transacting energy via exports and/or wheel-throughs.


References




CustomersBalancing Market Congestion Residual - AS


Flow Chart











• There is a NYISO Balancing Market Congestion Residual ($) for the given hour (Hr Total NYISO Bal Resid Cong ($) <> 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr Total NYISO Bal Cong Cr to PS ($)• Hr Total NYISO Bal Cong Ch to LSE ($)• Hr Total NYISO Bal LBMP Cong Ch :TC ($)• Hr Total NYISO Bal TUC Cong Ch :TC ($)



Outputs

• Hr Bal Resid Cong Stlmnt :LSE ($)• Hr Bal Resid Cong Stlmnt :TC ($)

Note:Day Bal Resid Cong Stlmnt :LSE ($)= Σ Hr Bal Resid Cong Stlmnt :LSE ($)

Day Bal Resid Cong Stlmnt :TC ($)= Σ Hr Bal Resid Cong Stlmnt :TC ($)



Settlement AlgorithmHr Bal Resid Cong Stlmnt :LSE ($) =

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Bal Resid Cong ($)


Hr Total NYISO Bal Resid Cong ($) =Hr Total NYISO Bal Cong Cr to PS ($) -{Hr Total NYISO Bal Cong Ch to LSE ($) +Hr Total NYISO Bal LBMP Cong Ch :TC ($) +Hr Total NYISO Bal TUC Cong Ch :TC ($)}



Settlement AlgorithmHr Bal Resid Cong Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Bal Resid Cong ($)


Hr Total NYISO Bal Resid Cong ($) =Hr Total NYISO Bal Cong Cr to PS ($) -{Hr Total NYISO Bal Cong Ch to LSE ($) +Hr Total NYISO Bal LBMP Cong Ch :TC ($) +Hr Total NYISO Bal TUC Cong Ch :TC ($)}



Tying out to the Hourly Bill Code: Residual Adjustment ($)

• BC 611= Hr DAM Resid Enrgy Stlmnt :LSE ($) + Hr DAM Resid Loss Stlmnt :LSE ($) + Hr Bal Resid Enrgy Stlmnt :LSE ($) + Hr Bal Resid Loss Stlmnt :LSE ($)+ Hr Bal Resid Cong Stlmnt :LSE ($) + Hr Emergency Purch Stlmnt :LSE ($)+ Hr Emergency Sales Stlmnt :LSE ($)+ Hr DAM Mrgn Assrnc Stlmnt :LSE ($)+ Hr DAM Mrgn Assrnc LRR Stlmnt :LSE ($)

*** Detailed later in Uplift and Other Settlement Sections



• BC 611= Hr DAM Resid Enrgy Stlmnt :TC ($) + Hr DAM Resid Loss Stlmnt :TC ($) + Hr Bal Resid Enrgy Stlmnt :TC ($) + Hr Bal Resid Loss Stlmnt :TC ($)+ Hr Bal Resid Cong Stlmnt :TC ($)+ Hr Emergency Purch Stlmnt :TC ($)+ Hr Emergency Sales Stlmnt :TC ($)+ Hr DAM Mrgn Assrnc Stlmnt :TC ($)


Tying out to the Hourly Bill Code: Residual Adjustment ($)



• BC 813 = Day DAM Resid Enrgy Stlmnt :LSE ($) + Day DAM Resid Loss Stlmnt :LSE ($) + Day Bal Resid Enrgy Stlmnt :LSE ($) + Day Bal Resid Loss Stlmnt :LSE ($)+ Day Bal Resid Cong Stlmnt :LSE ($) + Day Emergency Purch Stlmnt :LSE ($)+ Day Emergency Sales Stlmnt :LSE ($)+ Day DAM Mrgn Assrnc Stlmnt :LSE ($)+ Day DAM Mrgn Assrnc LRR Stlmnt :LSE ($)+ Day ELR DAM Marg Asrc Stlmnt :LSE ($)+ Day ELR DAM Marg Asrc LRR Stlmnt :LSE ($)



Tying out to the Daily Bill Code: Residual Adjustment ($)


• BC 813 = Day DAM Resid Enrgy Stlmnt :TC ($) + Day DAM Resid Loss Stlmnt :TC ($) + Day Bal Resid Enrgy Stlmnt :TC ($) + Day Bal Resid Loss Stlmnt :TC ($)+ Day Bal Resid Cong Stlmnt :TC ($) + Day Emergency Purch Stlmnt :TC ($)+ Day Emergency Sales Stlmnt :TC ($)+ Day DAM Mrgn Assrnc Stlmnt :TC ($)+ Day ELR DAM Marg Asrc Stlmnt :TC ($)



Tying out to the Daily Bill Code: Residual Adjustment ($)


UPLIFT ALLOCATIONS


Power Supplier DAM BPCG Allocation

Ancillary Services

Uplift Allocations


Description of Settlement• NYISO offers a DAM BPCG uplift payment to Power

Suppliers selling energy into the NYISO DAM when their DAM energy schedule is flagged as Out of Merit for NYISO reliability reasons. This uplift payment is designed to ensure that generators recover at least their bid production costs, net of costs to serve Transaction Contracts, defined by their DAM Generation Bid (minimum generation, start-up, and incremental costs from energy curve/blocks), when they are dispatched off of their economic schedule by NYISO for reliability reasons.

• All payments made to Power Suppliers through the DAM BPCG settlement are totaled, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given day.

Power Supplier DAM BPCG Allocation - AS


References





Flow Chart







• The Load Serving Entity purchased energy to meet their load requirements from the NYISO energy markets(Day RT LSE Load (MW) > 0).

• The Transaction Customer transacted energy via exports and/or wheel-throughs(Day RT Export Trans :TC (MW) > 0) or (Day RT Wheel-Thru Trans :TC (MW) > 0).

• There were DAM BPCG payments made to Power Suppliers due to NYISO Out of Merit DAM scheduling, or un-allocated DAM BPCG Under-Forecasting payments, during the day (Day Total NYISO DAM BPCG ($) <> 0) or (Day Ttl NYISO DAM BPCG Fcst Rdr ($) > 0).



Inputs

• Day RT LSE Load (MWh) - Bill Code 800• Day RT Export Trans :TC (MWh) - Bill Code 801• Day RT Wheel-Thru Trans :TC (MWh) - Bill Code 802• Day Total NYISO RT LSE Load (MWh)• Day Total NYISO RT Export Trans (MWh)• Day Total NYISO RT WT Trans (MWh)• Day Total NYISO DAM BPCG ($)• Day Total NYISO DAM BPCG Fcst Rdr ($)



Outputs

• Day DAM BPCG Stlmnt :LSE ($)• Day DAM BPCG Stlmnt :TC ($)




Day DAM BPCG Stlmnt :LSE ($) = {Day Total NYISO DAM BPCG ($) +Day Total NYISO DAM BPCG Fcst Rdr ($)} *Day RT LSE Ld Ratio Sh :LSE, Exp, WT

Day RT LSE Ld Ratio Sh :LSE, Exp, WT =Day RT LSE Load (MWh) /{Day Total NYISO RT LSE Load (MWh) +Day Total NYISO RT Export Trans (MWh) +Day Total NYISO RT WT Trans (MWh)}




Day DAM BPCG Stlmnt :TC ($) = {Day Total NYISO DAM BPCG ($) +Day Total NYISO DAM BPCG Fcst Rdr ($)} *Day RT TC Ld Ratio Sh :LSE, Exp, WT

Day RT TC Ld Ratio Sh :LSE, Exp, WT ={Day RT Export Trans :TC (MWh) +Day RT Wheel-Thru Trans :TC (MWh)} /{Day Total NYISO RT LSE Load (MWh) +Day Total NYISO RT Export Trans (MWh) +Day Total NYISO RT WT Trans (MWh)}



Power Supplier RT BPCG Allocation

Ancillary Services

Uplift Allocations


Description of Settlement• NYISO offers a RT BPCG uplift payment to Power

Suppliers selling energy into the NYISO RT market when their RT energy basepoint is flagged as Out of Merit for NYISO reliability reasons. This uplift payment is designed to ensure that generators recover at least their bid production costs, net of costs to serve Transaction Contracts or DAM Energy, defined by their HAM Generation Bid (minimum generation, start-up, and incremental costs from energy curve/blocks), when they are dispatched off of their economic basepoint by NYISO for reliability reasons.

• All payments made to Power Suppliers through the RT BPCG settlement are totaled, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given day.

Power Supplier RT BPCG Allocation - AS


References





Flow Chart









• There were RT BPCG payments made to Power Suppliers due to NYISO Out of Merit real-time dispatches during the day (Day Total NYISO RT BPCG ($) > 0).



Inputs

• Day RT LSE Load (MWh) - Bill Code 800• Day RT Export Trans :TC (MWh) - Bill Code 801• Day RT Wheel-Thru Trans :TC (MWh) - Bill Code 802• Day Total NYISO RT LSE Load (MWh)• Day Total NYISO RT Export Trans (MWh)• Day Total NYISO RT WT Trans (MWh)• Day Total NYISO RT BPCG ($)



Outputs

• Day RT BPCG Stlmnt :LSE ($)• Day RT BPCG Stlmnt :TC ($)




Day RT BPCG Stlmnt :LSE ($) = Day Total NYISO RT BPCG ($) *Day RT LSE Ld Ratio Sh :LSE, Exp, WT





Day RT BPCG Stlmnt :TC ($) = Day Total NYISO RT BPCG ($) *Day RT TC Ld Ratio Sh :LSE, Exp, WT




Transaction DAM BPCG Allocation

Ancillary Services

Uplift Allocations



Transaction DAM BPCG Allocation - AS

• NYISO offers a DAM BPCG uplift payment to Transaction Customers (external generators) selling energy into the NYISO DAM via Market Energy Import Transactions when their DAM schedule is below their DAM Transaction Bid (MW) due to constraints at the external control area transmission ties. This uplift payment is designed to ensure that external generators recover at least their bid production costs defined by their DAM Transaction Bid (decremental bid price), when they are scheduled below their DAM Bid (MW).

• All payments made to Transaction Customers through the Transaction DAM BPCG settlement are totaled, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given day.


References





Flow Chart









• There were Transaction DAM BPCG payments made to Transaction Customers during the day (Day Total NYISO Trans DAM BPCG ($) > 0).



Inputs

• Day RT LSE Load (MWh) - Bill Code 800• Day RT Export Trans :TC (MWh) - Bill Code 801• Day RT Wheel-Thru Trans :TC (MWh) - Bill Code 802• Day Total NYISO RT LSE Load (MWh)• Day Total NYISO RT Export Trans (MWh)• Day Total NYISO RT WT Trans (MWh)• Day Total NYISO Trans DAM BPCG ($)



Outputs

• Day DAM Trans BPCG Stlmnt :LSE ($)• Day DAM Trans BPCG Stlmnt :TC ($)




Day DAM Trans BPCG Stlmnt :LSE ($) = Day Total NYISO Trans DAM BPCG ($) *Day RT LSE Ld Ratio Sh :LSE, Exp, WT





Day DAM Trans BPCG Stlmnt :TC ($) = Day Total NYISO Trans DAM BPCG ($) *Day RT TC Ld Ratio Sh :LSE, Exp, WT




Transaction RT BPCG Allocation

Ancillary Services

Uplift Allocations



• NYISO offers a RT BPCG uplift payment to Transaction Customers (external generators) selling energy into the NYISO RT market via Market Energy Import Transactions when their RT schedule is below their HAM Transaction Bid (MW) due to constraints at the external control area transmission ties. This uplift payment is designed to ensure that external generators recover at least their bid production costs, net of DAM Transaction scheduled energy, defined by their HAM Transaction Bid (decremental bid price), when they are scheduled below their HAM Bid (MW).

• All payments made to Transaction Customers through the Transaction RT BPCG settlement are totaled, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given day.

Transaction RT BPCG Allocation - AS


References



NYISO Proprietary InformationTransaction RT BPCG Allocation - AS


Flow Chart









• There were Transaction RT BPCG payments made to Transaction Customers during the day (Day Total NYISO Trans RT BPCG ($) > 0).



Inputs

• Day RT LSE Load (MWh) - Bill Code 800• Day RT Export Trans :TC (MWh) - Bill Code 801• Day RT Wheel-Thru Trans :TC (MWh) - Bill Code 802• Day Total NYISO RT LSE Load (MWh)• Day Total NYISO RT Export Trans (MWh)• Day Total NYISO RT WT Trans (MWh)• Day Total NYISO Trans RT BPCG ($)



Outputs

• Day RT Trans BPCG Stlmnt :LSE ($)• Day RT Trans BPCG Stlmnt :TC ($)




Day RT Trans BPCG Stlmnt :LSE ($) = Day Total NYISO Trans RT BPCG ($) *Day RT LSE Ld Ratio Sh :LSE, Exp, WT





Day RT Trans BPCG Stlmnt :TC ($) = Day Total NYISO Trans RT BPCG ($) *Day RT TC Ld Ratio Sh :LSE, Exp, WT




Transaction Import ECA Supplier Guarantee Allocation

Ancillary Services

Uplift Allocations



• NYISO offers an Import Extraordinary Corrective Action (ECA) Supplier Guarantee uplift payment to Transaction Customers importing energy from external control areas into the New Your Control Area (NYCA) when their real-time transaction schedule is curtailed by NYISO (not for Market Participant reasons). This uplift payment is designed to ensure the Transaction Customers importing power into the NYCA are not financially harmed by NYISO transaction curtailments, when necessary.

• The Transaction Contracts are either Market Energy Import Transactions (sales to the NYISO markets) or Bilateral Import Transactions (direct sales to load buses within the NYCA). Uplift payments made to Transaction Customers are totaled and allocated to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given hour.

Transaction Import ECA Supplier Guarantee Allocation - AS


References





Flow Chart









• There were Import ECA Supplier Guarantee payments made to Transaction Customers during the hour (Hr Total NYISO Imp ECA Sup Gnt ($) > 0).

• NOTE: Hr RT LSE Load (MW) is the sum of market energy purchasedfrom NYISO plus import and internal bilateral transaction energypurchased from 3rd Parties.



Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr Total NYISO ImECASupGnt :LBMP ($)• Hr Total NYISO ImECASupGnt :PTP ($)



Outputs

• Hr Imp ECA Sup Gnt Stlmnt :LSE ($)• Hr Imp ECA Sup Gnt Stlmnt :TC ($)

Note:Day Imp ECA Sup Gnt Stlmnt :LSE ($)= Σ Hr Imp ECA Sup Gnt Stlmnt :LSE ($)

Day Imp ECA Sup Gnt Stlmnt :TC ($)= Σ Hr Imp ECA Sup Gnt Stlmnt :TC ($)




Hr Imp ECA Sup Gnt Stlmnt :LSE ($) = Hr Total NYISO Imp ECA Sup Gnt ($) *Hr RT LSE Ld Ratio Sh :LSE, Exp, WT

Hr Total NYISO Imp ECA Sup Gnt ($) =Hr Total NYISO ImECASupGnt :LBMP ($) +Hr Total NYISO ImECASupGnt :PTP ($)




Settlement AlgorithmHr Imp ECA Sup Gnt Stlmnt :TC ($) =

Hr Total NYISO Imp ECA Sup Gnt ($) *Hr RT TC Ld Ratio Sh :LSE, Exp, WT

Hr Total NYISO Imp ECA Sup Gnt ($) =Hr Total NYISO ImECASupGnt :LBMP ($) +Hr Total NYISO ImECASupGnt :PTP ($)

Hr RT TC Ld Ratio Sh :LSE, Exp, WT ={Hr RT Export Trans :TC (MWh) +Hr RT Wheel-Thru Trans :TC (MWh)} /{Hr Total NYISO RT LSE Load (MWh) +Hr Total NYISO RT Export Trans (MWh) +Hr Total NYISO RT WT Trans (MWh)}



Tying out to the Daily Bill Code:NYISO-Wide Uplift Charge ($)

• BC 812 = Day DAM BPCG Stlmnt :LSE ($) + Day RT BPCG Stlmnt :LSE ($) + Day DAM Trans BPCG Stlmnt :LSE ($) + Day RT Trans BPCG Stlmnt :LSE ($)+ Day Imp ECA Sup Gnt Stlmnt :LSE ($)



Tying out to the Daily Bill Code:NYISO-Wide Uplift Charge ($)

• BC 812 = Day DAM BPCG Stlmnt :TC ($) + Day RT BPCG Stlmnt : TC ($) + Day DAM Trans BPCG Stlmnt : TC ($) + Day RT Trans BPCG Stlmnt : TC ($)+ Day Imp ECA Sup Gnt Stlmnt : TC ($)



Power Supplier DAM BPCG –LRR Allocation

Ancillary Services

Uplift Allocations



• NYISO offers a DAM BPCG LRR uplift payment to Power Suppliers selling energy into the NYISO DAM when their DAM energy schedule is flagged as Out of Merit by Transmission Owners for local reliability reasons. This uplift payment is designed to ensure that generators recover at least their bid production costs, net of costs to serve Transaction Contracts, defined by their DAM Generation Bid (minimum generation, start-up, and incremental costs from energy curve/blocks), when they are dispatched off of their economic schedule by a Transmission Owner for local reliability reasons.

• All payments made to Power Suppliers through the DAM BPCG settlement due to LRR are totaled by NYISO Sub-Zone, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) based on their load ratio share in the given Sub-Zone during the given day.

Power Supplier DAM BPCG – LRR Allocation - AS


References





Flow Chart


Daily Bill Codes810

Hourly Bill Codes




• The Load Serving Entity purchased energy to meet their load requirements in a given NYISO sub-zone from the NYISO energy markets (Day LSE Subzone Load (MW) > 0).

• There were DAM BPCG LRR payments made to Power Suppliers in a given NYISO sub-zone due to NYISO Out of Merit DAM scheduling during the day (Day Total NYISO SZ DAM BPCG LRR ($) > 0).



Inputs

• Day LSE Subzone Load (MW)• Day Total Subzone Load (MW)• Day Total NYISO SZ DAM BPCG LRR ($)



Outputs

• Day SZ DAM BPCG LRR Stlmnt :LSE ($)

NOTE: The LSE’s Total DAM BPCG LRR Settlement is currently contained in the DSS, which is the sum of Day SZ DAM BPCG LRR Stlmnt :LSE ($) across all NYISO sub-zones.




Day SZ DAM BPCG LRR Stlmnt :LSE ($) = Day Total NYISO SZ DAM BPCG LRR ($) *Day RT LSE SZ Ld Ratio Sh :LSE

Day RT LSE SZ Ld Ratio Sh :LSE =Day LSE Subzone Load (MW) /Day Total Subzone Load (MW)



Power Supplier RT BPCG – LRR Allocation

Ancillary Services

Uplift Allocations


Description of Settlement• NYISO offers a RT BPCG LRR uplift payment to

Power Suppliers selling energy into the NYISO DAM when their RT basepoint is flagged as Out of Merit by Transmission Owners for local reliability reasons. This uplift payment is designed to ensure that generators recover at least their bid production costs, net of costs to serve Transaction Contracts and DAM Energy, defined by their HAM Generation Bid (minimum generation, start-up, and incremental costs from energy curve/blocks), when they are dispatched off of their economic schedule by a Transmission Owner for local reliability reasons.

• All payments made to Power Suppliers through the RT BPCG settlement due to LRR are totaled by NYISO Sub-Zone, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) based on their load ratio share in the given Sub-Zone during the given day.

Power Supplier RT BPCG – LRR Allocation - AS


References





Flow Chart


Daily Bill Codes810

Hourly Bill Codes




• The Load Serving Entity purchased energy to meet their load requirements in a given NYISO sub-zone from the NYISO energy markets (Day LSE Subzone Load (MW) > 0).

• There were RT BPCG LRR payments made to Power Suppliers in a given NYISO sub-zone due to NYISO Out of Merit DAM scheduling during the day (Day Total NYISO SZ RT BPCG LRR ($) > 0).



Inputs

• Day LSE Subzone Load (MW)• Day Total Subzone Load (MW)• Day Total NYISO SZ RT BPCG LRR ($)



Outputs

• Day SZ RT BPCG LRR Stlmnt :LSE ($)

NOTE: The LSE’s Total RT BPCG LRR Settlement is currently contained in the DSS, which is the sum of Day SZ RT BPCG LRR Stlmnt :LSE ($) across all NYISO sub-zones.




Day SZ RT BPCG LRR Stlmnt :LSE ($) = Day Total NYISO SZ RT BPCG LRR ($) *Day RT LSE SZ Ld Ratio Sh :LSE

Day RT LSE SZ Ld Ratio Sh :LSE =Day LSE Subzone Load (MW) /Day Total Subzone Load (MW)



Tying out to the Daily Bill Code:LRR Mingen Charge ($)

• BC 810 = Day DAM BPCG LRR Stlmnt :LSE ($) + Day RT BPCG LRR Stlmnt :LSE ($)



Power Supplier DAM MarginAssurance Allocation

Ancillary Services

Uplift Allocations



Power Supplier DAM Margin Assurance Allocation - AS

• NYISO offers a DAM Margin Assurance uplift payment to Power Suppliers that are required to purchase energy in the NYISO Balancing Energy Market as a result of being dispatched below their DAM schedule by NYISO for reliability reasons. Therefore, the DAM Margin Assurance settlement for Power Suppliers guarantees a generator’s DAM margin (profit) is not reduced by balancing market energy settlements in Real-Time due to NYISO scheduling.

• The DAM Margin Assurance payments made to Power Suppliers are totaled, and allocated to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given hour.


References



• DSS Corporate Report: • Settlement Details – PS Uplift Allocations for Load

Serving Entities• Settlement Details – PS Uplift Allocations for Transaction

Customers

NYISO Proprietary InformationPower Supplier DAM Margin Assurance Allocation - AS


Flow Chart




Corporate Report:PS Uplift Allocations for Load Serving Entities

PS Uplift Allocations for Transaction Customers



Eligibility Rules / Requirements• The Load Serving Entity purchased energy to meet their

load requirements from the NYISO energy markets(Hr RT LSE Load (MW) > 0).


• There were DAM Margin Assurance payments made to Power Suppliers during the hour (Hr Total NYISO DAM Mrgn Assrnc ($) > 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr Total NYISO DAM Mrgn Assrnc ($)



Outputs

• Hr DAM Mrgn Assrnc Stlmnt :LSE ($) *** Included in BC 611

• Hr DAM Mrgn Assrnc Stlmnt :TC ($) *** Included in BC 611

Note:Day DAM Mrgn Assrnc Stlmnt :LSE ($) *** Included in BC 813= Σ Hr DAM Mrgn Assrnc Stlmnt :LSE ($)

Day DAM Mrgn Assrnc Stlmnt :TC ($) *** Included in BC 813= Σ Hr DAM Mrgn Assrnc Stlmnt :TC ($)




Hr DAM Mrgn Assrnc Stlmnt :LSE ($) = Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO DAM Mrgn Assrnc ($)




Settlement AlgorithmHr DAM Mrgn Assrnc Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO DAM Mrgn Assrnc ($)




Power Supplier DAM MarginAssurance - LRR Allocation

Ancillary Services

Uplift Allocations


Description of Settlement• NYISO offers a DAM Margin Assurance LRR uplift

payment to Power Suppliers that are required to purchase energy in the NYISO Balancing Energy Market as a result of being dispatched below their DAM schedule by Transmission Owners for local reliability reasons. Therefore, the DAM Margin Assurance LRR settlement for Power Suppliers guarantees a generator’s DAM margin (profit) is not reduced by balancing market energy settlements in Real-Time due to Transmission Owner scheduling.

• All payments made to Power Suppliers through the DAM Margin Assurance settlement due to LRR are totaled by NYISO Sub-Zone, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) based on their load ratio share in the given Sub-Zone during the given day.

Power Supplier DAM Margin Assurance - LRR Allocation - AS


References





Flow Chart


Daily Bill Codes813





• The Load Serving Entity purchased energy to meet their load requirements in a given NYISO sub-zone from the NYISO energy markets (Hr LSE Subzone Load (MWh) > 0).

• There were DAM Margin Assurance LRR payments made to Power Suppliers in a given NYISO sub-zone due to Transmission Owner Out of Merit DAM scheduling during the day (Hr Ttl NYISO DAM Mgn Assrnc LRR ($) > 0).



Inputs

• Hr LSE Subzone Load (MW)• Hr Total Subzone Load (MW)• Hr Total NYISO DAM Mgn Assrnc LRR ($)



Outputs

• Hr SZ DAM Mgn Assrnc LRR Stlmnt :LSE ($)

*** Included in BC 611

Note:Day SZ DAM Mgn Assrnc LRR Stlmnt :LSE ($) *** Included in BC 813= Σ Hr SZ DAM Mgn Assrnc LRR Stlmnt :LSE ($)

Note: The LSE’s Total DAM Margin Assurance LRR Settlement is currently contained in the DSS, which is the sum of Hr SZ DAM MgnAssrnc LRR Stlmt :LSE ($) for all hours in a given day.




Hr SZ DAM Mgn Assrnc LRR Stlmnt :LSE ($) = Hr Total NYISO DAM Mgn Assrnc LRR ($) *Hr RT LSE SZ Ld Ratio Sh :LSE

Hr RT LSE SZ Ld Ratio Sh :LSE =Hr LSE Subzone Load (MW) /Hr Total Subzone Load (MW)



Power Supplier ELR DAM MarginAssurance Allocation

Ancillary Services

Uplift Allocations



Power Supplier ELR DAM Margin Assurance Allocation - AS

• NYISO offers an ELR DAM Margin Assurance uplift payment to PowerSuppliers, with generators classified as ELR generators that arerequired to purchase energy in the NYISO Balancing Energy Market as a result of being dispatched below their DAM schedule by NYISO for reliability reasons. Therefore, the ELR DAM Margin Assurance settlement for Power Suppliers guarantees an ELR generator’s DAMmargin (profit) is not reduced by balancing market energy settlements in Real-Time due to NYISO scheduling.

• The ELR DAM Margin Assurance payments made to Power Suppliers are totaled and allocated to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given day.


References





Flow Chart







• The Load Serving Entity purchased energy to meet their load requirements from the NYISO energy markets (Day RT LSE Load (MWh) > 0).

• The Transaction Customer transacted energy via exports and/or wheel-throughs(Day RT Export Trans :TC (MWh) > 0) or (Day RT Wheel-Thru Trans :TC (MWh) > 0).

• There were ELR DAM Margin Assurance payments made to Power Suppliers during the day (Day Total NYISO ELR DAM Mrgn Assrnc ($) > 0).



Inputs• Day RT LSE Load (MWh) - Bill Code 800• Day RT Export Trans :TC (MWh) - Bill Code 801• Day RT Wheel-Thru Trans :TC (MWh) - Bill Code 802• Day Total NYISO RT LSE Load (MWh)• Day Total NYISO RT Export Trans (MWh)• Day Total NYISO RT WT Trans (MWh)• Day Total NYISO ELR DAM Mrgn Assrnc ($)



Outputs

• Day ELR DAM MargAsrc Stlmnt :LSE ($)*** Included in BC 813

• Day ELR DAM MargAsrc Stlmnt :TC ($) *** Included in BC 813



Settlement AlgorithmDay ELR DAM MargAsrc Stlmnt :LSE ($) =

Day RT LSE Ld Ratio Sh :LSE, Exp, WT *Day Total NYISO ELR DAM Mrgn Assrnc ($)




Settlement AlgorithmDay ELR DAM MargAsrc Stlmnt :TC ($) =

Day RT TC Ld Ratio Sh :LSE, Exp, WT *Day Total NYISO ELR DAM Mrgn Assrnc ($)

Day RT TC Ld Ratio Sh :LSE, Exp, WT ={Day RT Export Trans :TC (MWh) + Day RT Wheel-Thru Trans :TC (MWh)} /{Day Total NYISO RT LSE Load (MWh) +Day Total NYISO RT Export Trans (MWh) +Day Total NYISO RT WT Trans (MWh)}



Power Supplier DAM BPCG Under-Forecasted Load Allocation

Ancillary Services

Uplift Allocations



Power Supplier DAM BPCG Under-Forecasted Load Allocation - AS

• NYISO offers a DAM BPCG uplift payment to Power Suppliers selling energy into the NYISO DAM when their DAM energy schedule is flagged as Out of Merit by NYISO to meet additional forecasted load requirements. This uplift payment is designed to ensure that generators recover at least their bid production costs, net of costs to serve Transaction Contracts, defined by their DAM Generation Bid (minimum generation, start-up, and incremental costs from energy curve/blocks), when they are dispatched off of their economic schedule by NYISO to meet additional forecasted load requirements (additional load requirements due to under-forecasting).

• All payments made to Power Suppliers through the DAM BPCG settlement (to meet additional forecasted load requirements only) are totaled, and the costs of these payments are recovered through allocations to Load Serving Entities (LSE) based on their load ratio share for the given super zone for the given day.


References





Flow Chart


Daily Bill Codes815

Hourly Bill Codes




• DAM Bid Production Cost Guarantee (BPCG) payments were allocated to power suppliers as a result of DAM load underforecasting(Day DAM Forecasted BPCG ($) > 0).



Inputs• Day RT LSE Load :LSE/SprZn (MW)• Day DAM Sched Load :LSE/SprZn (MW)• Day DAM VSupply Energy :VBE/SprZn (MW)• Day DAM VLoad Energy :VBE/SprZn (MW)• Day RT LSE Load :SprZn (MW)• Day DAM Sched Load :SprZn (MW)• Day DAM VSupply Energy :SprZn (MW)• Day DAM VLoad Energy :SprZn (MW)• Day DAM NYISO Frcst Load :SprZn (MW)• Day Total NYISO DAM UndrFrcst BPCG ($)



Outputs

• Day DAM BPCG UnderFrcst :LSE/SprZn ($) - Bill Code 815

Note: The below algorithm section calculates the Load Serving Entity (LSE) Power Supplier Day Ahead Market (DAM) Bid Production Cost Guarantee (BPCG) Under-Forecasted Load Allocation settlement ($) for a single SuperZone. For a complete Under-Forecasted Load Allocation, this calculation must be performed for each SuperZone in which a Load Serving Entity (LSE) serves load.




Day DAM BPCG UnderFrcst :LSE/SprZn ($) = Day Total NYISO DAM UndrFrcst BPCG ($) *Day DAM BPCG UndrFrcst Rat :LSE/SprZn

Day DAM BPCG UndrFrcst Rat :LSE/SprZn =Day DAM Frcst Accuracy Ratio :SprZn *Day SprZn Adj RT Ld Ratio Sh *Day Adj2 RT Ld Ratio Sh :LSE/SprZn



Settlement AlgorithmDay DAM Frcst Accuracy Ratio :SprZn =

Day Adj RT Actual Load :SprZn (MW) /Day Adj Frcast Load :SprZn (MW)

NOTE: Day DAM Frcst Accuracy Ratio :SprZn is bound by 0 and 1 (If Day DAM Frcst Accuracy Ratio :SprZn > 1, then Day DAM Frcst Accuracy Ratio :SprZn = 1, or If Day DAM FrcstAccuracy Ratio :SprZn < 0, then Day DAM Frcst Accuracy Ratio :SprZn = 0).

Day Adj RT Actual Load :SprZn (MW) =Max {Day RT LSE Load :SprZn (MW) +

Day DAM VSupply Energy :SprZn (MW) -Day DAM VLoad Energy :SprZn (MW) -Day DAM Sched Load :SprZn (MW), 0}

Day Adj Frcast Load :SprZn (MW) =Max {Day DAM NYISO Frcst Load :SprZn (MW) +

Day DAM VSupply Energy :SprZn (MW) -Day DAM VLoad Energy :SprZn (MW) -Day DAM Sched Load :SprZn (MW), 0}

NOTE: Day Adj Frcst Load :SprZn (MW) cannot be equal to zero (to avoid dividing by zero). In this case, the denominator = 1 (If Day Adj Frcst Load :SprZn (MW) = 0, then Day Adj FrcstLoad :SprZn (MW) = 1).




Day SprZn Adj RT Ld Ratio Sh =Day Adj RT Actual Load :SprZn (MW) /Day Total Adj RT Actual Load (MW)

Day Total Adj RT Actual Load (MW) =∑ Day Adj RT Actual Load :SprZn (MW) for all Super Zones



Settlement AlgorithmDay Adj2 RT Ld Ratio Sh :LSE/SprZn =

Day Adj2 RT Actual Load :LSE/SprZn (MW) /Day Adj2 RT Actual Load :SprZn (MW)

Day Adj2 RT Actual Load :LSE/SprZn (MW) =Max {Day RT LSE Load :LSE/SprZn (MW) -

Day DAM VLoad Energy :VBE/SprZn (MW) -Day DAM Sched Load :LSE/SprZn (MW), 0} +

Day DAM VSupply Energy :VBE/SprZn (MW)

Day Adj2 RT Actual Load :SprZn (MW) =∑ Day Adj2 RT Actual Load :LSE/SprZn (MW) for all Load Serving Entities

NOTE: Day Adj2 RT Actual Load :SprZn (MW) cannot be equal to zero (to avoid dividing by zero). In this case, the denominator = 1 (Day Adj2 RT Actual Load :SprZn (MW) = 0, then Day Adj2 RT Actual Load :SprZn (MW) = 1).



OTHER SETTLEMENT ALLOCATIONS


Emergency Purchases

Ancillary Services

Other Settlement Allocations



Emergency Purchases - AS

• In cases where NYISO demand (load) exceeds available supply resources, the NYISO will purchase emergency supply from external control area resources on behalf of the NYCA under existing emergency energy contracts. In general, the NYISO willattempt to obtain enough supply to meet its demand through its common markets/channels. If demand still exceeds supply, emergency purchases will be made. These emergency purchases can be made from NYISO’s 4 external control areas: Hydro Quebec, ISO-New England, PJM, and Ontario Hydro.

• The costs of the emergency energy purchases typically are recovered through allocations to Load Serving Entities (LSE) andTransaction Customers (TC) based on their load ratio shares during the given period.


References



• DSS Corporate Report:• Settlement Details – Emergency Purchases for Load

Serving Entities• Settlement Details – Emergency Purchases for

Transaction Customers



Flow Chart




Corporate Report:Emergency Purchases for Load Serving Entities

Emergency Purchases for Transaction Customers




• The Load Serving Entity purchased energy to meet their load requirements from the NYISO energy markets (Hr RT LSE Load (MWh) > 0).

• The Transaction Customer transacted energy via exports and/or wheel-throughs(Hr RT Export Trans :TC (MWh) > 0) or (Hr RT Wheel-Thru Trans :TC (MWh) > 0).

• There was an Emergency Purchase(s) made from one of the external control areas (PJM, Ontario Hydro, ISO-NE, Hydro Quebec) during the hour (Hr Total NYISO Emergency Purch ($) > 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr NYISO Emergency Purch :ISO-NE ($)• Hr NYISO Emergency Purch :PJM ($)• Hr NYISO Emergency Purch :OH ($)• Hr NYISO Emergency Purch :HQ ($)



Outputs

• Hr Emergency Purch Stlmnt :LSE ($) *** Included in BC 611

• Hr Emergency Purch Stlmnt :TC ($) *** Included in BC 611

Note:Day Emergency Purch Stlmnt :LSE ($) *** Included in BC 813= Σ Hr Emergency Purch Stlmnt :LSE ($)

Day Emergency Purch Stlmnt :TC ($) *** Included in BC 813= Σ Hr Emergency Purch Stlmnt :TC ($)



Settlement AlgorithmHr Emergency Purch Stlmnt :LSE ($) =

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Emergency Purch ($)


Hr Total NYISO Emergency Purch ($) =Hr NYISO Emergency Purch :ISO-NE ($) +Hr NYISO Emergency Purch :PJM ($) +Hr NYISO Emergency Purch :OH ($) +Hr NYISO Emergency Purch :HQ ($)



Settlement AlgorithmHr Emergency Purch Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Emergency Purch ($)


Hr Total NYISO Emergency Purch ($) =Hr NYISO Emergency Purch :ISO-NE ($) +Hr NYISO Emergency Purch :PJM ($) +Hr NYISO Emergency Purch :OH ($) +Hr NYISO Emergency Purch :HQ ($)



Emergency Sales

Ancillary Services




Emergency Sales - AS

• In cases where an external control area’s demand (load) exceeds its available supply resources, the external control area will purchase emergency supply from NYISO under existing emergency energy contracts. These emergency sales can be made to NYISO’s 4 external control areas: Hydro Quebec, ISO-New England, PJM, and Ontario Hydro.

• The revenue from the emergency energy sales typically are allocated to Load Serving Entities (LSE) and Transaction Customers (TC) based on their load ratio shares during the given period


References



• DSS Corporate Report:• Settlement Details – Emergency Sales for Load Serving

Entities• Settlement Details – Emergency Sales for Transaction

Customers



Flow Chart




Corporate Report:Emergency Sales for Load Serving Entities

Emergency Sales for Transaction Customers






• There was an Emergency Sale(s) made to one of the external control areas (PJM, Ontario Hydro, ISO-NE, Hydro Quebec) during the hour (Hr Total NYISO Emergency Sales ($) > 0).




Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr Total NYISO RT LSE Load (MWh)• Hr Total NYISO RT Export Trans (MWh)• Hr Total NYISO RT WT Trans (MWh)• Hr NYISO Emergency Sales :ISO-NE ($)• Hr NYISO Emergency Sales :PJM ($)• Hr NYISO Emergency Sales :OH ($)• Hr NYISO Emergency Sales :HQ ($)



Outputs

• Hr Emergency Sales Stlmnt :LSE ($) *** Included in BC 611• Hr Emergency Sales Stlmnt :TC ($) *** Included in BC 611

Note:Day Emergency Sales Stlmnt :LSE ($) *** Included in BC 813= Σ Hr Emergency Sales Stlmnt :LSE ($)

Day Emergency Sales Stlmnt :TC ($) *** Included in BC 813= Σ Hr Emergency Sales Stlmnt :TC ($)



Settlement AlgorithmHr Emergency Sales Stlmnt :LSE ($) =

Hr RT LSE Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Emergency Sales ($)


Hr Total NYISO Emergency Sales ($) =Hr NYISO Emergency Sales :ISO-NE ($) +Hr NYISO Emergency Sales :PJM ($) +Hr NYISO Emergency Sales :OH ($) +Hr NYISO Emergency Sales :HQ ($)



Settlement AlgorithmHr Emergency Sales Stlmnt :TC ($) =

Hr RT TC Ld Ratio Sh :LSE, Exp, WT *Hr Total NYISO Emergency Sales ($)


Hr Total NYISO Emergency Sales ($) =Hr NYISO Emergency Sales :ISO-NE ($) +Hr NYISO Emergency Sales :PJM ($) +Hr NYISO Emergency Sales :OH ($) +Hr NYISO Emergency Sales :HQ ($)



NTAC

Ancillary Services




NTAC - AS

• All NTAC charges made by NYISO are collected and paid to NYPA. Load Serving Entities and Transaction Customers (exports and wheel-throughs) receive this charge based on their real-time actual load or transaction schedule.


References



• DSS Corporate Report:• Settlement Details – NYPA NTAC for Load

Serving Entities• Settlement Details – NYPA NTAC for

Transaction Customers

NTAC - AS


Flow Chart




Corporate Reports:NYPA NTAC for Load Serving Entities

NYPA NTAC for Transaction Customers

NTAC - AS






NTAC - AS


Inputs

• Hr RT LSE Load (MWh) - Bill Code 600• Hr RT Export Trans :TC (MWh) - Bill Code 601• Hr RT Wheel-Thru Trans :TC (MWh) - Bill Code 602• Hr NTAC Rate ($/MW) - Bill Code 603

NTAC - AS


Outputs

• Hr NTAC Stlmnt :LSE ($) - Bill Code 604• Hr NTAC Stlmnt :TC ($) - Bill Code 604

Note:Day NTAC Stlmnt :LSE ($) - Bill Code 803= Σ Hr NTAC Stlmnt :LSE ($)

Day NTAC Stlmnt :TC ($) - Bill Code 803= Σ Hr NTAC Stlmnt :TC ($)

NTAC - AS



Hr NTAC Stlmnt :LSE ($) = Hr RT LSE Load (MWh) *Hr NTAC Rate ($/MW)

Hr NTAC Stlmnt :TC ($) = {Hr RT Export Trans :TC (MWh) +Hr RT Wheel-Thru Trans :TC (MWh)} *Hr NTAC Rate ($/MW)

NTAC - AS


New SMD2 Ancillary Services Bill Codes

• Bill Codes 618 & 817: Regulation Revenue Adjustment ($)

• Bill Codes 619 & 818: Supplemental Event Charge ($)

• Bill Codes 620 & 819: Financial Impact Credit ($)

NTAC - AS


Settlements Reporting


SMD2 Settlement Reporting

• DSS CSV files• Daily Reconciliations - Cash and MW• Consolidated Invoice - Invoice Details



Hourly CSV Files

• Modified Codes– Power Suppliers

• Bill Code 227 Hrly 30 Min Res Avail $– Includes Balancing Market payment

• Bill Code 232 Hrly Synch Res Avail $– Includes Balancing Market payment

• Bill Code 237 Hrly 10 Min Non Synch Res Avail $– Includes Balancing Market payment

– Transmission Customers (Ancillary Service Charges)• Bill Code 610 Hrly Reserve Charge $

– Includes Balancing Market Operating Reserves charge• Bill Code 612 Hrly Regulation & Frequency Response Charge $

– Includes Balancing Market Regulation charge



Hourly CSV Files• New Columns

– Power Suppliers• Bill Code 250 Hrly Bal Mkt Reg Avail MWhr• Bill Code 251 Hrly Bal Mkt Reg Avail $• Bill Code 252 Hrly Reg Rev Adj $• Bill Code 253 Hrly Sup Event Credit $

– Transmission Customers • Transaction TUC and TSC Charges - Bill Code 530 Hrly FIC $• Transaction LBMP Energy Charges - Bill Code 531 Hrly FIC $• Ancillary Service Charges - Bill Code 618 Hrly RRA $• Ancillary Service Charges - Bill Code 619 Hrly Sup Event Chrg $• Ancillary Service Charges - Bill Code 620 Hrly FIC $



Daily CSV Files

• Modified Codes– Power Suppliers

• Bill Code 308 Regulation Payment $– Includes Balancing Market Regulation payment

• Bill Code 310 Operating Reserve Payment $– Includes Balancing Market Operating Reserves payment

– Transmission Customers (Ancillary Service Charges)• Bill Code 806 Reserve Charge $

– Includes Balancing Market Operating Reserves charge• Bill Code 807 Regulation & Frequency Response Charge $

– Includes Balancing Market Regulation charge



Daily CSV Files• New Columns

– Power Suppliers• Bill Code 316 Regulation Revenue Adjustment $• Bill Code 317 Supplemental Event Credit $

– Transmission Customers • LBMP Energy Charges - Bill Code 776 FIC (Charge) $• TUC and TSC Charges - Bill Code 777 FIC (Charge) $• Ancillary Service Charges - Bill Code 817 RRA $• Ancillary Service Charges - Bill Code 818 Sup Event Charge $• Ancillary Service Charges - Bill Code 819 FIC (Credit) $



Daily Reconciliations


Org_Name Start_Billing_Day End_Billing_Day Version_NumberNYISO Wide 8/5/2004 8/5/2004 0Billing_code Description Item_Value Total_Value Billing_code Description Item_Value

70001 DAM LSE Internal LBMP Energy Sales 163469 30001 DAM Internal PS LBMP Energy Purchases 17978775801 DAM External TC LBMP Energy Sales 2030 75803 DAM External PS LBMP Energy Purchases 669575802 DAM Replacement LBMP Energy Sales Due to Curtailed Imports 0 77201 DAM Virtual Supply 383677001 DAM Virtual Load 5920 20100 DAM Price Responsive Load Reduction 0

34 DAM LBMP Energy Market MWh 171419 41 DAM LBMP Energy Market MWh

70401 Balancing LSE Internal LBMP Energy Sales 142608 30301 Balancing Internal PS LBMP Energy Purchases 12537376301 Balancing External TC LBMP Energy Sales 200 76303 Balancing External PS LBMP Energy Purchases 271676302 Balancing Replacement LBMP Energy Sales Due to Curtailed Imports 0 77202 Balancing Virtual Supply -383677002 Balancing Virtual Load -5920

35 Balancing LBMP Energy Market MWh 136888 42 Balancing LBMP Energy Market MWh

75001 DAM Bilateral - Internal Bilaterals 165805 30002 DAM Regulation MW 520075002 DAM Bilateral - Importl/Non-LBMP Market Bilaterals 120 30003 DAM Synchronous Reserve MW 1622775003 DAM Bilateral - Export/Non-LBMP Market Bilaterals 168 30004 DAM 10 Minute Non-Synchonous Reserve MW 1298775004 DAM Bilateral - Wheel Through Bilaterals 0 30005 DAM 30 Minute Reserve MW 13991

39 DAM Bilateral Transmission Service MWh 166093 30302 Balancing Regulation MW -214630303 Balancing Synchronous Reserve MW -3189

75401 Balancing Bilateral - Internal Bilaterals 839 30304 Balancing 10 Minute Non-Synchonous Reserve MW -877075402 Balancing Bilateral - Importl/Non-LBMP Market Bilaterals 175 30305 Balancing 30 Minute Reserve MW -104975403 Balancing Bilateral - Export/Non-LBMP Market Bilaterals 075404 Balancing Bilateral - Wheel Through Bilaterals 0

40 Balancing Bilateral Transmission Service MWh 1014

Changes in MW Reconciliation

30002 – 30005 DAM Reserves and Regulation MW30302 – 30305 Balancing Reserves and Regulation MW


Daily Reconciliations


Changes in $ Reconciliation

Org_Name Start_Billing_DayNYISO Wide 8/5/2004Billing_code Description Billing_code Description

76502 Balancing Replacement LBMP Losses Sales Revenue Due to Curtailed Imports 30502 Supplemental Event Credit76602 Balancing Replacement LBMP Congestion Sales Revenue Due to Curtailed Imports 30503 Regulation Revenue Adjustment Credit70502 Failed Transaction Financial Impact Charge 31401 Energy Limited Resource Balancing per Local Reliability

31402 Energy Limited Resource Balancing per ISO2 Balancing LBMP Revenue 14 Balancing LBMP Expenditure

81214 Supplemental Event Payment80903 Failed Transaction Financial Impact Credit

5 OAT Schedule 1: NYCA Customer Revenue

81215 Supplemental Event Payment80904 Failed Transaction Financial Impact Credit

6 OATT Schedule 1: Non-NYCA Customer Revenue

30802 DAM Regulation Service Availability Payment Expenditure80701 OATT Schedule 3: Regulation Service Revenue 31 MST Schedule 3: Regulation Service Expenditure

31007 DAM Synchronous Operating Reserve Availability Payment Expenditure31008 DAM 10 Minute Non-Sync. Operating Reserve Availability Payment Expenditure31009 DAM 30 Minute Operating Reserve Availability Payment Expenditure

8 OATT Schedule 5: Operating Reserve Service Revenue 32 MST Schedule 4: Operating Reserve Service Expenditure

FIC Charge in Balancing LBMP Revenue

Supp. Event Credit and RRA Credit(Charge) in

Balancing LBMP Expenditure

Supp.Event Payment and FIC Credit in Schedule 1

DAM Regulation and Reserves


Con Invoice – Invoice Details

• No additional invoice line items• Modified invoice line items


Code Description SMD2 Modification305 supplier_rt_cost_guarantee includes supplemental_event_credit305 supplier_rt_cost_guarantee includes regulation_revenue_adjustment_credit308 regulation_payment includes dam_regulation_availability_credit and balnacing_regulation_availability_credit310 operating_reserves_payment includes dam_synch_reserve_credit and balancing_synch_reserve_credit310 operating_reserves_payment includes dam_min10_nonsynch_reserve_credit and balancing_min10_nonsynch_reserve_credit310 operating_reserves_payment includes dam_min30_reserve_credit and balancing_min30_reserve_credit705 trans_cust_balancing_energy includes charge for FIC

805,809 mst_and_oat_uplift_charge includes credit for FIC812 nyiso_wide_uplift includes supplemental event payment


Conclusion

Questions?

Conclusion

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