Configuration Guide for: Forecasting Service Fee / Date: 04/01/09
Settlements & Billing
BPM Configuration Guide:Forecasting Service Fee
CC 701
Version 5.0
CAISO, 2018 / Page 1 of 7Settlements & Billing / Version: 5.0
Configuration Guide for: Forecasting Service Fee / Date: 04/01/09
Table of Contents
1.Purpose of Document
2.Introduction
2.1Background
2.2Description
3.Charge Code Requirements
3.1Business Rules
3.2Predecessor Charge Codes
3.3Successor Charge Codes
3.4Inputs – External Systems
3.5Inputs – Predecessor Charge Codes or Pre-calculations
3.6CAISO Formula
3.7Outputs
4.Charge Code Effective Dates
1.Purpose of Document
The purpose of this document is to capture the requirements and design specification for a SaMC Charge Code in one document.
2.Introduction
2.1Background
The Participating Intermittent Resources Program (PIRP) was implemented on Trading Day 6/2/2004 enabling intermittent resources (wind and other resources with an uncontrollable primary fuel source) to participate in CAISO Markets. PIRP scheduling methodology allows participating intermittent power producers to schedule Energy in the CAISO HASP/RTM while reducing their exposure to hourly imbalance charges whenever the delivered Energy differs from the scheduled Energy.
The CAISOshall provide each Participating Intermittent Resource (PIR) with independent third party Hour-Ahead Energy forecasts. Currently, the independent third party is AWS True Wind Company. The Scheduling Coordinator representing the PIR, must submitting HASP/RT Self Schedules tht are identical, in aggregate, to the Hour-Ahead Forecast. In addition to the Hour-Ahead forecasts, AWS will provide Day-Ahead forecast for each PIR for each Trading Hour for the following Trading Day. The SC can use these Day-Ahead forecasts as an advisory or the SC can schedule in the Day-Ahead Market. However, if the PIR schedules in the DAM, they are exposed to daily imbalance energy charges.
Forecasting Service Fee Charge Code 701 charges Business Associates for each PIR for the daily Energy generation forecasts provided by an external Forecast Service Provider. The forecasting service company provides a Day Ahead forecast for each PIR for a Trading Hour for the following Trading Day, as well as updated hourly forecasts as needed. All BAs for PIRs are charged a FERC approved forecasted service rate per MWh based on actual metered Energy.
2.2Description
The Forecasting Service Fee is automatically calculated by the Settlements system on a monthly basis at the resource specific level and summed by Business Associate for the Settlement Statement and Invoicing. The forecasted service rate is approved by FERC and per MWh based on actual metered Energy
This Charge Code will be implemented pursuant to a configuration enhancement procedure that allows for gains in performance, thereby reducing the volume of calculations executed during the monthly Settlement Run. The outcome of this feature is not published on the monthly Settlements Statements issued to participants. However, this enhancement procedure has no impact on the actual calculation of the settlement amounts determined by this Charge code. The performance enhancement is achieved through the availability of a feature that makes the results of (previously calculated) daily Settlement Runs available during to the CAISO operator for the monthly run in lieu of the operator having to re-execute daily calculations within the monthly Settlement Run. Additionally, this feature will provide the CAISO operator monthly totals of (previously calculated) daily outputs as well as monthly totals of primary bill determinants as needed. The CAISO will notify participants of which Charge Code uses this feature by including this statement in the description of the affected Charge Codes. In addition, the CAISO will indicate in the applicable CAISO Formula sections which of the individual calculations within the monthly run utilize this feature.Participants can verify the Settlement Amounts resulting from this Charge Code in their monthly calculations by utilizing the daily input data as defined in the input sections of each Charge Code, the amounts and/or quantities of which are published on the relevant, daily Settlement Statements
.
3.Charge Code Requirements
3.1Business Rules
Bus Req ID / Business Rule1.0 / Forecasting Service Fee is a charge to Business Associates for daily energy generation forecasts for PIR resources.
2.0 / Business Associates are charged a FERC approved forecasted service rate per MWh based on actual metered Energy for resources defined as PIRs.
3.0 / Forecasting Service Fee charges are calculated monthly and appear on the market Invoice.
4.0 / All Forecasting Service Fees collected are accrued in a trustee account for distribution to the Forecast Service Provider.
5.0 / For adjustments to the Charge Code that cannot be accomplished by correction of upstream data inputs/recalculation or operator override Pass Through Bill Charge logic will be applied.
3.2Predecessor Charge Codes
Charge Code/ Pre-calc NameMSS Netting Pre-calculation
3.3Successor Charge Codes
Charge Code/ Pre-calc NameCC 751 – Monthly Intermittent Resource Export Energy Settlement
3.4Inputs – External Systems
Row # / Variable Name / Description1 / CAISOForecastingServiceFeeRate / FERC approved forecasted service rate. This is standing data. (Currently $0.10/MWh)
2 / PTBChargeAdjustmentForecastingServiceFeeSettlementAmount BJm / PTB Charge Adjustment Forecasting Service Fee Settlement Amount by BA B PTB ID J and Trading Month m.
3 / PIRCertFlag Brtd / PIR Certification Flag for PIR Business Associate B per Resource r for Trade Day d. ‘Y’ identifies certified PIR resource, ‘N’ identifies non-certified PIR resource, and Null is a non-PIR resource.
3.5Inputs – Predecessor Charge Codes or Pre-calculations
Row # / Variable Name / Predecessor Charge Code/Pre-calc Configuration
1 / BAResIntervalMeteredGenerationQuantity BrtT’Q’uI’M’AA’R’pW’Qd’n’Nz’HvPVL’mdhi / MSS Netting Pre-calculation
3.6CAISO Formula
3.6.1BAMonthlyResourceForecastingServiceFeeSettlementAmountBrtm= BAMonthlyResourcePIRMeteredGenerationQuantityBrtm * CAISOForecastingServiceFeeRate
3.6.2Where,
BAMonthlyResourcePIRMeteredGenerationQuantity Brtm = BAHourlyResourcePIRMeteredGenerationQuantity Brtmdh
Note: BAHourlyResourcePIRMeteredGenerationQuantity Brtmdh
is provided by the configuration enhancement procedure that returns a monthlyquantity as a summation of dailyquantities generated previously under CC 701from daily settlement calculation results forthe applicable Trading Month.
3.6.3Where,
IF
PIRCertFlagBrtd= 1
THEN
BAHourlyResourcePIRMeteredGenerationQuantityBrtmdh=HourlyMeteredGenerationBrtmdh
ELSE
BAHourlyResourcePIRMeteredGenerationQuantityBrtmdh= 0
END IF
3.6.4WhereHourlyMeteredGenerationBrtmdh=
BAResIntervalMeteredGenerationQuantityBrtT’Q’uI’M’AA’R’pW’Qd’n’Nz’HvPVL’mdhi
Note: BAMonthlyForecastingServiceFeeSettlementAmount Bm is calculated as part of the reporting structure and will not be configured as individual charge type.
3.7Outputs
OutputID / Name / Description
1 / In addition to any outputs listed below, all inputs shall be included as outputs. / All inputs.
2 / BAMonthlyResourceForecastingServiceFeeSettlementAmountBrtm / The Forecasting Service Fee charge amount attributed to Business AssociateB for Resource ID r for Trading Month m.
3 / BAMonthlyResourcePIRMeteredGenerationQuantityBrtm / Total metered generation quantity for PIR resource r and Business Associate B for Trading Month m.
4 / BAHourlyResourcePIRMeteredGenerationQuantityBrtmdh / The total metered quantity for Generation resource r and Business Associate B in Trading Month m , Trade day d, Trade Hour h (MWh)
5 / HourlyMeteredGenerationBrtmdh / The Total Hourly Metered Generation quantity of Business Associate B,
resource r, of Trading Hour h, Trading Day d, and Trading Month m.
4.Charge Code Effective Dates
Charge Code/Pre-calc Name / Document Version / Effective Start Date / Effective End Date / Version Update Type
CC 701 – Forecasting Service Fee / 5.0 / 04/01/09 / Open / Documentation Edits Only
CAISO, 2018 / Page 1 of 7