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CAISO

Settlements & Billing

Configuration Guide: IFM Net Amount

Pre-calculation

Version 5.67

CAISO, 2013 of 49

Table of Contents

1. Purpose of Document 3

2. Introduction 3

2.1 Background 3 2.2 Description 5

3. Charge Code Requirements 7

3.1 Business Rules 7 3.2 Predecessor Charge Codes 11 3.3 Successor Charge Codes 12 3.4 Inputs – External Systems 12 3.5 Inputs - Predecessor Charge Codes or Pre-calculations 19 3.6 CAISO Formula 22 3.7 Outputs 38

4. Charge Codes Effective Dates 49

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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

2.1 Background

Bid Cost Recovery (BCR) is the process by which the CAISO ensures SCs are able to recover Start Up Costs (SUC), Minimum Load Costs (MLC), Transition Costs (TC) and Energy Bid Costs. In order to recover SUC and MLC, a Generating Unit, Pumped-Storage Unit, or resource-specific System Resource must be committed by the CAISO. Likewise, the CAISO must commit a Multi-Stage Generating Resource in order for it to receive TC compensation. Bid cost recovery for energy and, Ancillary Services (A/S) bids), Regulation Up Mileage and Regulation Down Mileage Bids applies to Bid Cost Recovery Eligible Resources in general (for example, Generating Units, Pumped-Storage Units, Proxy Demand Resources, and resource-specific System Resources without a Circular Schedule) scheduled or dispatched by CAISO, independent of whether they are CAISO-committed or instead are self committed.

For purposes of determining BCR eligibility, CAISO uses a concept called Commitment Period. A Commitment Period consists of the consecutive time periods within a Trading Day when a resource is on-line, synchronized to the grid, and available for dispatch. A Commitment Period is comprised of two distinct sub-types --- Self-Commitment Period and CAISO Commitment Period. The portion of a Commitment Period where a resource submits energy self-schedule or A/S self provision is called a Self-Commitment Period. A Self-Commitment Period may include time periods when a resource is not operating pursuant of an Energy self-schedule or A/S self-provision, but must be on as a result of an Energy Self-Schedule or A/S self-provision due to ramping constraints, minimum up time, or minimum down time. Resources are not eligible for BCR of SUC, MLC, or TC during Self-Commitment Periods, but are eligible for BCR of awarded energy and A/S. The portion of a Commitment Period that is not a Self-Commitment Period is called CAISO Commitment Period. Resources are eligible to receive BCR for SUC, MLC, TC, awarded energy, A/S and A/SRegulation Mileage during a CAISO Commitment Period.

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SUC, MLC, and TC for each market and resource are determined in Pre-Calculation IFM/RUC/RTM Start-up and Minimum Load EligibilityCost and then used as inputs to calculate a resource‟s net difference between costs and revenues in separate pre-calculations by market --- IFM Net Amount, RUC Net Amount, and RTM Net Amount. If the difference between the total costs and the market revenues is positive in the relevant market, then the net amount represents a Shortfall. If the difference is negative in the relevant market, the net amount represents a Surplus. For each resource, the IFM, RUC, and RTM Shortfalls and Surpluses are then netted over all hours of a Trading Day. As a result, surpluses from any of the CAISO markets offset any shortfalls from the other markets over the entire Trading Day. If the net Trading Day amount is positive (a Shortfall), then the resource receives a BCR Uplift Payment equal to the net Trading Day amount under CC 6620 Bid Cost Recovery Settlement.

For MSS entities that have elected gross settlement, the Energy settlement is exactly the same as other Scheduling Coordinators. For MSS entities that have elected net settlement, for both IFM and RTM the Energy MWh quantity is based on the net of Generation and Demand (scheduled quantities in the Day-Ahead Schedule by the IFM and measured quantities for RTM) within the MSS. Therefore, the settlement quantity is proposed to be done on MSS-level basis. Net load from MSS operators that have elected net settlement will be settled at the MSS LAP price and net-Generation from such MSS operators will be settled at the weighted average LMPs over all Pnodes within the MSS with Generation schedules for IFM and measured Generation for RTM as weighting factors.

Consistent with Section 11.8.2.2 of the CAISO Tariff, the portions of the day-ahead schedule and dispatched energy at or below a resource‟s minimum load will be based on delivered energy.

The same tolerance band used to determine whether the resource is entitled to minimum load cost recovery will be used to determine whether a resource‟s market revenue is accounted for in the netting of minimum load cost payments. Applying the Tolerance Band, CAISO determines whether or not the resource is “on” and thereby, its start-up and minimum load costs are recoverable, if ““(a) its metered Energy in a Settlement Interval is equal to or greater than the difference between its Minimum Load Energy and the Tolerance Band.” and (b) if its metered Energy > 0.” Otherwise, the resource is deemed “off” and does not recover its minimum load costs. If the resource is determined to be “on” (as the Tolerance Band requirement is met and the resource‟s metered Energy > 0), CAISO will also calculate the market revenues used to offset the minimum load costs in that given interval.



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As described in the proposed Tariff Amendment presented to FERC through the CAISO‟s Emergency Tariff Filing on March 21, 2011 and amended by an errata filing on March 25, 2011, because a resource‟s DA energy is deemed delivered and settled as such, it is appropriate to reflect the actual DA energy settlement within the BCR methodology. Therefore, as approved by FERC on May 3, 2011 in Docket ER11-3149, irrespective of IFM CAISO Commitment or IFM Self-Commitment, when a resource„s RT Instructed Imbalance Energy (IIE) is equal to or less than zero, the DA Metered Energy Adjustment Factor (MEAF) should not apply to the DA Energy Bid revenue portion of the resource‟s IFM revenue amount. That is, when the sum of a resource‟s Energy components TEE, OA and Regulation is less than or equal to DASE, it is expected that the DA Energy Bid revenue amount = DA Bid Award * DA LMP. Essentially, the DA MEAF should be set to 1. On the other hand, regardless of IFM Self-Commitment or IFM CAISO Commitment, if the resource‟s RT IIE is greater than zero, the DA MEAF should continue to be applied to the DA Energy Bid revenue amount such that DA Energy Bid revenue amount = DA Bid Award * DA LMP * DA MEAF. In the current BCR design, CAISO is applying the DA MEAF to the DA Energy Bid revenue regardless of whether or not RT IIE > 0. The proposed change, in line with the Tariff Amendment filing, becomes effective retroactively on Trading Day March 26, 2011.

After the FERC‟s May 3, 2011 order concerning BCR revenue, on June 22, 2011 CAISO filed a request for a Tariff amendment (modification to BCR rules & exceptional dispatch energy settlement rules in docket no. ER11-3856-000) in order to change the rule for using delivered Energy in the calculation of IFM Bid Costs for BCR. Applying Energy Bid Costs in the negative portions of the Energy Bid Curve essentially allows for the accounting of negative Bid Costs that are used to offset the resources overall Bid Cost Recovery payments. Therefore, the exclusion of Bid Costs in the Bid Cost Recovery process results in an increase of Bid Costs, inflating Bid Cost Recovery payments overall. Instead of accounting for Energy Bid Costs for negative bids on the basis of delivered portions and applying the Day-ahead Metered Energy Adjustment Factor, CAISO proposed to base these costs on the Energy scheduled in the Day-Ahead Market and not apply the Day-ahead Metered Energy Adjustment Factor to negatively-priced Bids when calculating bid costs for Energy. Thus, for negatively-priced Bids CAISO will determine IFM Energy Bid Costs with the formula “DA Energy Bid cost amount = DA Bid Award * DA BID PRICE”. For Bids priced >=0 CAISO will continue, as prior to the June 22 filing, to determine IFM Energy Costs through the formula “DA Energy Bid Cost amount = DA Bid Award * DA BID PRICE * DA MEAF”. The proposed change, in line with the Tariff Amendment filing, was requested to become effective retroactively on Trading Day June 23, 2011.

2.2 Description

For each Settlement Interval, this pre-calculation will generate the IFM Bid Costs, IFM market revenue, and the IFM Net Amount as the net difference between IFM costs and IFM revenue for various Bid Cost Recovery Eligible Resources (for example, Generating Units, Pumped-Storage Units, Proxy Demand Resources and resource specific System Resources without a Circular Schedule). The IFM Net Amount is subsequently used as an input for CC 6620, Bid Cost Recovery Settlement and pre-calculation Bid Cost Recovery Sequential Netting.


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Consistent with the September 21, 2006 FERC Order, until the approval of the CAISO-requested June 22, 2011 Tariff Amendment filing, IFM Bid Cost for any settlement interval is based on whether the resource‟s Day-Ahead Schedule was actually delivered. The portions of the day-ahead schedule and dispatched Energy at or below a resource‟s minimum load are subject to satisfying the Tolerance Band. For other portions of the Day-Ahead Schedule the delivered portions of the Day-Ahead Schedule are evaluated based on the metered energy adjustment factor. Additionally stated in Paragraph #516, Resources that fall short of the Day Ahead and RT Dispatch Instructions shall only be guaranteed the recovery of cost associated with the Energy actually provided, and should not receive payment for deviations from DA Schedule or RT Dispatch Instructions. As mentioned in prior section 2.1 of the current document, in the Tariff amendment request filing with FERC on June 22, 2011, CAISO proposed a simple rule change. Instead of accounting for IFM Energy Bid Costs for Energy having negative Bids on the basis of delivered Energy portions and applying the Day-Ahead Metered Energy Adjustment Factor to the BCR Energy cost calculation, CAISO proposed to base these costs on the Energy scheduled in the Day-Ahead Market and not apply the Day-Ahead Metered Energy Adjustment Factor. For positively-priced Bids, CAISO would continue to account for IFM Energy Bid Costs on the basis of delivered Energy portions and apply the Day-Ahead Metered Energy Adjustment Factor to the BCR Energy calculation.

IFM market revenues are calculated for each Settlement Interval as the sum of 1) The product of Awarded A/S and the relevant ASMP, divided by the number of Settlement Intervals in a Trading Hour, plus 2) The product of Awarded Energy (above Minimum Load or Self-Schedule for Self Commitment Periods, but the entire IFM Schedule for CAISO Commitment Periods) and the IFM LMP, divided by the number of Settlement Intervals in a Trading Hour. , 3) the Revenue associated with Mileage from DA Awarded Regulation Up A/S and paid at the DA Regulation Up Mileage clearing price over the Settlement Interval, and 4) the Revenue associated with Mileage from DA Awarded Regulation Down A/S and paid at the DA Regulation Down Mileage clearing price over the Settlement Interval. Performance factors, based on the Tolerance Band for Minimum Load Energy and on the Day-Ahead Metered Energy Adjustment Factor – as calculated in the Pre-calculation Metered Energy Adjustment Factor, – in the case of non-Minimum Load Energy, are used to determine IFM Energy eligible for Bid Cost Recovery. The Awarded Energy is broken into two (2) categories, Minimum Load Energy and non-Minimum Load Energy, and then the Energy in each category is multiplied by the appropriate performance factor to determine the portion of Energy in each of the 2 categories that receives Bid Cost Recovery. However, in accordance with the preceding document section, in the event a resource‟s RT IIE < 0 the DA MEAF would not be applied to the non-Minimum Load Energy in calculating the DA Energy Bid revenue portion of the resource‟s IFM revenue amount that is applied in the BCR calculation.

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For the MSS entity electing net settlement regardless of other MSS optional elections, the settlement MWh quantity is determined at the MSS level for MSSs within MSS Aggregation or being standalone rather than on individual resource level. For an MSS net-load in the DA Schedule, i.e. MSS internal Demand exceeds internal generation in the Day-Ahead Schedule; the MSS is not eligible for BCR. For the MSS net-generation in Day-Ahead Schedule, i.e. MSS internal Generation exceeds the internal Demand, the Energy of the net Generation in Day-Ahead schedule is paid at the price equal to the weighted average of IFM LMPs for all applicable Pnodes within the relevant MSS; the net Generation energy is eligible for BCR. The weighting factors for computing the weighted average are the MSS Generation quantities corresponding to different Pnodes in Day-Ahead schedule. The settlement MWh quantity is the net Energy of the MSS.

3. Charge Code Requirements

3.1 Business Rules

Bus

Req ID Business Rule

1.0 This Pre-calc is a daily computation generating results on a Settlement Interval basis.

2.0 For any Settlement Interval, the IFM Energy Bid Cost for Bid Cost Recovery Eligible Resources, except Participating Loads, shall be the integral of the relevant Energy Bid (Bid price in $/MWh) submitted to the IFM, if any, from the higher of the registered Bid Cost Recovery Eligible Resource‟s Minimum Load and the Day-Ahead Total Self-Schedule up to the relevant MWh scheduled in the Day-Ahead Schedule, divided by the number of Settlement Intervals (6) in a Trading Hour.

2.1 For a Bid Cost Recovery Eligible Resource that has metered Generation below its Day-Ahead Schedule, the IFM Energy Bid Cost for Bid Cost Recovery Eligible Resources, except Participating Loads, and except for any portion of the Day-Ahead Schedule associated with an Energy Bid less than zero, for any Settlement Interval shall be set to zero for any portion of the Day-Ahead Schedule that is not delivered.

2.1.1 Any portion of the Day-Ahead Schedule that is actually delivered shall remain eligible for IFM Energy Bid Cost Recovery.

2.1.2 The delivered portions of the Day-Ahead Schedule for this calculation shall be determined using the Day-Ahead Metered Energy Adjustment Factor.

2.1.3 The Day-Ahead Metered Energy Adjustment Factor shall not be applied to IFM Energy Bid Costs that associate with Energy Bids that are less than zero.

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2.2 For Multi-Stage Generating (MSG) Resources, Energy Bid Costs (determined under IFM Net Amount Pre-calculation, RUC Net Amount Pre-calculation, and RTM Net Amount Pre-calculation) shall be calculated at the Generating Unit level.

2.3 In the case of positive uninstructed deviation, the BCR Eligible Resource shall be entitled to Bid Cost Recovery based on its scheduled Energy. (induced from requirements 2.0 through 2.1.3 above)

2.4 Mitigated Bid prices are used when calculating IFM Bid Costs.

3.0 Regardless of Resource Type, IFM Net Amount must follow the same sign convention --- positive IFM Net Amount indicates a Shortfall, negative IFM Net Amount indicates a Surplus.

4.0 Resource-specific System Resources are system resources that are eligible to submit a 3-part Bid and are paid or charged at the resource-specific Day Ahead LMP.

5.0 Pass Through Bill Charge Adjustment Logic does not applyapplies to the configuration.

6.0 For the MSS entity electing net settlement, if the DA Demand exceeds the DA Generation schedule, the MSS energy is not eligible for BCR, with the exception of Ancillary Awards and Regulation Mileage, which are eligible for BCR regardless of MSS gross or net election.

7.0 For the MSS entity electing net settlement, if the DA Generation schedule exceeds the DA Demand, only the DA Generation schedule energy that is above the DA Demand is eligible for BCR.

8.0 Non-Dynamic System Resources and Resource-Specific System Resources are considered to be outside the MSS; therefore, will settle on a resource basis at the Intertie LMP or Resource-Specific LMP respectively, regardless of net or gross election.

9.0 For Multi-Stage Generating (MSG) Resources, the comparison of market revenues to bid costs occurs at the resource level.

10.0 The IFM Minimum Load Energy used in the determination of IFM Minimum Load revenue for BCR shall be calculated as the product of delivered MWh in the relevant Day-Ahead Schedule for portions at or below the Minimum Load submitted to the IFM and the relevant LMP divided by the number of Settlement Intervals in a Trading Hour.qualified by whether or not the Resource‟s Energy output has met or surpassed the Tolerance Band limit.

10.1 The delivered portions of the Day Ahead Schedule in this case are determined based on the CAISO‟s determination that the resource was “On” for the applicable Trading Hour as determined by the Pre-calculation Start-Up and Minimum Load Cost configuration.If the Tolerance Band requirement has not been satisfied, the IFM Minimum Load revenue and IFM Minimum Load Cost shall = 0.

10.2 If the Tolerance Band requirement has been satisfied, the IFM Minimum Load revenue shall be computed as the product of the IFM

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Minimum Load Energy and the Resource-specific DA LMP.

10.3 The IFM Minimum Load Cost is input into the currently defined calculation from a predecessor configuration. Fact

11.0

For any Settlement Interval in a CAISO IFM Commitment Period in which the resource‟s Instructed Imbalance Energy is greater than zero (i.e., the resource is dispatched by CAISO in real-time higher than the Day-Ahead Schedule), the IFM Market Revenue for a Bid Cost Recovery Eligible Resource in association with the portion of the relevant DA Energy Schedule that is above the higher of the total day-ahead self-schedules and the Minimum Load submitted to the IFM for the applicable Trading Hour shall be determined as the product of

(a) the delivered MWh, in the relevant Day-Ahead Schedule above the higher of the total day-ahead self-schedules and the Minimum Load submitted to the IFM in that Trading Hour and

(b) the relevant IFM LMP

with said product divided by the number of Settlement Intervals in a Trading Hour.

11.1 The delivered portions of the Day-Ahead Schedule in this case shall be determined based on the Day-Ahead Metered Energy Adjustment Factor.

12.0

For any Settlement Interval in a CAISO IFM Commitment Period in which the resource‟s Instructed Imbalance Energy is equal to or less than zero (i.e., the resource is dispatched by CAISO in real-time at or lower than the Day-Ahead Schedule), the IFM Market Revenue for a Bid Cost Recovery Eligible Resource in association with the portion of the relevant DA Energy Schedule that is above the higher of the total day-ahead self-schedules and the Minimum Load submitted to the IFM for the applicable Trading Hour shall be determined as the product of

(a) the scheduled MWh, in the relevant Day-Ahead Schedule above the higher of the total day-ahead self-schedules and the Minimum Load submitted to the IFM in that Trading Hour and

(b) the relevant IFM LMP,


13.0

For any Settlement Interval in a IFM Self-Commitment Period in which the resource‟s Instructed Imbalance Energy is greater than zero (i.e., the resource is dispatched by CAISO in real-time higher than the Day-Ahead Schedule), the IFM Market Revenue for DA Energy from a Bid Cost Recovery Eligible Resource for a Trading Hour shall be determined as the product of

(a) the delivered MWh, in the relevant Day-Ahead Schedule above the higher of the total day-ahead self-schedules and the Minimum Load submitted to the IFM in that Trading Hour and

(b) the relevant IFM LMP,

with said product divided by the number of Settlement Intervals in a

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Trading Hour.

13.1 The delivered portions of the Day-Ahead Schedule in this case shall be determined based on the Day-Ahead Metered Energy Adjustment Factor.

14.0

For any Settlement Interval in a IFM Self-Commitment Period in which the resource‟s Instructed Imbalance Energy is equal to or less than zero (i.e., the resource is dispatched by CAISO in real-time at or lower than the Day-Ahead Schedule), the IFM Market Revenue for a Bid Cost Recovery Eligible Resource in association with the portion of the relevant DA Energy Schedule that is above the higher of the total day-ahead self-schedules and the Minimum Load submitted to the IFM for the applicable Trading Hour shall be determined as the product of

(c) the scheduled MWh, in the relevant Day-Ahead Schedule above the higher of the total day-ahead self-schedules and the Minimum Load submitted to the IFM in that Trading Hour and

(d) the relevant IFM LMP,


15.0 The resource‟s Instructed Imbalance Energy includes real-time self-schedule Energy as well as CAISO-instructed RTM and exceptional dispatch energy. (Fact)

16.0 For Pumped-Storage Hydro Units and Participating Load operating in the pumping mode or serving Load, the scheduled or delivered DA Energy shall be negative.

17.0 For any Settlement Interval, the IFM AS Bid Cost shall be the product of the IFM AS Award from each accepted IFM AS Bid and the relevant AS Bid Price, divided by the number of Settlement Intervals in a Trading Hour.

17.1 The CAISO will determine and calculate IFM AS Bid Cost for a Multi-Stage Generating Resource at the Generating Unit level.

17.2 The IFM AS Bid Cost shall also include Mileage Bid Costs.

17.2.1

For any Settlement Interval, the IFM Mileage Bid Cost shall be the product of (a) Instructed Mileage associated with a Day Ahead Regulation capacity award, with the AS Mileage Bid adjusted for performance accuracy, and (b) the relevant Mileage Bid price, divided by the number of Settlement Intervals in a Trading Hour.

17.2.2 The CAISO will determine and calculate IFM Mileage Bid Cost for a Multi-Stage Generating Resource at the Generating Unit level.

18.0 Resources supplying Mileage from contracted or self-provided Regulation in the Day-Ahead Market are paid a Mileage clearing price for each MW of Instructed Mileage during the Settlement Period.

18.1 If a resource is awarded incremental Regulation in the Real-Time Market, the Instructed Mileage shall be divided between the Day Ahead Market and Real Time Market, in proportion to the Day-Ahead and Real-Time

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Regulation Capacity awards.

18.2 Instructed Mileage associated with a Day-Ahead Market award will be paid the Day-Ahead Mileage clearing price.

18.3 The CAISO will adjust a resource‟s Mileage payments based on the accuracy of the resource‟s response to CAISO EMS signals.

18.3.1

To determine this accuracy adjustment, the CAISO will sum a resource‟s Automatic Generation Control set points for each four (4) second Regulation interval every fifteen (15) minutes and then sum the total deviations from the Automatic Generation Control set point for each four (4) second regulation interval during that fifteen (15) minute period. (Fact)

18.3.1.1 The CAISO will divide the sum of the resource‟s Automatic Generation Control set points less the sum of the resource‟s total deviations by the sum of the resource‟s Automatic Generation Control set points. (Fact)

18.3.2 The CAISO will apply the resulting percentage to the resource‟s Regulation performance payments as an accuracy adjustment.

190.0 Bid Cost Recovery (BCR) Eligible Resources are those resources eligible to participate in the Bid Cost. They include Generating Units, System Units, System Resources, Participating Loads, and Proxy Demand Resources.

190.1 A System Resource that has a Schedule that results from Bids submitted in violation of Section Tariff 30.5.5 (Scheduling Sourcing/Sinking in Same Balancing Authority Area) shall not be a Bid Cost Recovery Eligible Resource for any Settlement Interval that occurs during the time period covered by the Schedule that results from Bids submitted in violation of Section Tariff 30.5.5. (Fact)

3.2 Predecessor Charge Codes

Charge Code/ Pre-calc Name

Pre-calc – Start-Up and Minimum Load Cost

Pre-calc – Metered Energy Adjustment Factor

Pre-calc – RT Energy Quantity

CC 6011 – Day Ahead Energy, Congestion, Loss Settlement

CC 7251 – Regulation Up Mileage Settlement

CC 7261 – Regulation Down Mileage Settlement



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3.3 Successor Charge Codes

Charge Code/ Pre-calc Name

Pre-calc – RTM Net Amount

Pre-calc – RUC Net Amount

CC 6620 – Bid Cost Recovery Settlement

Pre-calc – Bid Cost Recovery Sequential Netting

3.4 Inputs – External Systems

Row Variable Name Description

1 PTB_BAHourlyResourceCircularScheduleFlag

BrtF‟S‟Jh

Flag input (1/ Blank) that indicates whether or not a system resource has a circular schedule in association with Business Associate ID B, Resource ID r, Resource Type t, Entity Component Type F‟, Entity Component Subtype S‟, PTB ID J and Trading Hour h. The input = 1 to indicate a circular schedule and is blank otherwise (when a resource does not have a circular schedule).

2 DAMinimumLoadQuantity

BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif

Day Ahead Minimum Load Quantity (provided by MQS) for Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

3

DAAwardedSpinBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h

Day Ahead Spinning Reserve Awarded Bid Capacity for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Intertie Constraint a‟, and Trading Hour h.




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4 DASpinBidPrice

BrtuT‟I‟M‟VL‟W‟R‟F‟S‟h

Day Ahead Spinning Reserve Capacity Bid Price for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, and Trading Hour h.

5 DASpinCapacityASMP rth Day Ahead Spinning Reserve Ancillary Service Marginal Price for Resource ID r , Resource Type t, and Trading Hour h.

6

DAAwardedNonSpinBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h

Day Ahead Non-Spinning Reserve Awarded Bid Capacity for Business Associate ID B, Resource ID r , UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Intertie Constraint a‟, and Trading Hour h.

7 DANonSpinBidPrice


Day Ahead Non-Spinning Reserve Capacity Bid Price for Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, and Trading Hour h.

8 DANonSpinCapacityASMP rth

Day Ahead Non-Spinning Reserve Ancillary Service Marginal Price for Resource ID r , Resource Type t, and Trading Hour h.

9 DAAwardedRegUpBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h

Day Ahead Regulation Up Awarded Bid Capacity for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Intertie Constraint a‟, and Trading Hour h.







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10 DARegUpBidPrice


Day Ahead Regulation Up Capacity Bid Price for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, and Trading Hour h.

11 DARegUpCapacityASMP

rth

Day Ahead Regulation Up Ancillary Service Marginal Price for Resource ID r , Resource Type t, and Trading Hour h.

12 DAAwardedRegDownBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h

Day Ahead Regulation Down Awarded Bid Capacity for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Intertie Constraint a‟, and Trading Hour h.

13 DARegDownBidPrice


Day Ahead Regulation Down Capacity Bid Price for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, and Trading Hour h.

14 DARegDownCapacityASMP rth

Day Ahead Regulation Down Ancillary Service Marginal Price for Resource ID r , Resource Type t, and Trading Hour h.

15 DAEnergyBidPrice

BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif

Day Ahead Energy Bid Price (provided by MQS) for Business Associate ID B, Resource ID r, Resource Type t UDC Index u, Entity Type T‟, Bid Segment b, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.







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16 DayAheadLMP rth

Day Ahead Locational Marginal Price for Resource ID r, Resource Type t, and Trading Hour h.

Prices for Resource-Specific System Resource (Tie Generators) shall be mapped to Resource-Specific Day Ahead LMP. Prices for Non-Dynamic System Resource s shall be mapped to Day Ahead Intertie LMP.

17

DAScheduleEnergyAllocationQuantity

BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif

The Day Ahead Expected Energy Allocation Schedule quantity (provided by MQS) inclusive of Minimum Load, Self-schedule, and awarded bid Energy for Business Associate ID B, Resource ID r, Resource Type t UDC Index u, Entity Type T‟, Bid Segment b, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

18 DASelfSchedule


The Self Schedule energy quantity of the Day Ahead Schedule above Minimum Load (provided by MQS) for Business Associate ID B, Resource ID r, Resource Type t UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f

19

DAPumpingEnergy


The Day Ahead Pumping Energy (provided by MQS) from Pumped-Storage Unit and Participating Loads for Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

20 DALoadSchedule

BrtuT‟I‟M‟AA‟R‟pW‟F‟S‟vVL‟h

DA Load Schedule (provided by IFM) for Business Associate ID B, Resource ID r, Resource type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, and MSS Subgroup M‟, APN_ID A, APN Type






CAISO, 2013 of 49


A‟, Penalty Resource ID R‟, Price Node ID p, MSS Emission Pay Flag W‟, Entity Component Type F‟, Entity Component Subtype S‟, TAC Area ID v, RUC Participation Flag V, Load Following Flag L‟, and Trading Hour h. Represents non-participating load resource IDs, and is a negative value.

21 DABidAwardEnergyQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif

The Day Ahead Awarded Expected Energy Bid quantity above Minimum Load and Self Schedule (provided by MQS) for Business Associate ID B, Resource ID r, Resource Type t UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

22 SettlementIntervalIFMCAISOCommitPeriod BrtF‟S‟hi

Provided by MQS, indicates resource was committed ON by CAISO in IFM. 1: for ON, 0: for OFF or Self-Committed for Business Associate ID B, Resource ID r, Resource Type t, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i.

23 IFMPumpingCostFlag

BrtuT‟I‟M‟F‟S‟hi

Indicates IFM Pumping Costs for a settlement interval are qualified for cost compensation (provided by MQS) for Business Associate ID B, Resource ID r, Resource Type t , UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Commitment Period O‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i. Qualified = 1, Not qualified = 0.

24 CAISOHourlyDARegUpMileagePrice mdh

Provides the IFM Regulation Up Mileage marginal price (in $/MWh) in association with Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are implicit).

25 BA15MinuteResourceRegUpPerformanceAccuracyPercentage Brtmdhc

Provides the performance accuracy factor (as a decimal number between 0 and 1) for Regulation Up Mileage in association with Business Associate ID B, Resource ID r, Resource Type t, and 15-minute AS interval c of Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are




CAISO, 2013 of 49


implicit).

26 BA15MinuteResourceAdjustedRegUpMileageQty

Brtmdhc

Adjusted Regulation Up Mileage (in MWh) that has incorporated any necessary under-response adjustment per resource per 15-minute interval. The input is provided in association with Business Associate ID B, Resource ID r, Resource Type t, and 15-minute AS interval c of Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are implicit).

27 DARegUpQSP

BrtuT‟I‟M‟VL‟W‟R‟F‟S‟Nz‟a‟dh

IFM Regulation Up AS qualified self-provided capacity (in MW) in association with Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Contract Reference Number N, Contract Type z‟, and Intertie Constraint ID a‟, Trading Hour h.

28 RegUpCapacitySchedule

BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟hc

Final RTPD Cleared Regulation Up Capacity (in MW). The input includes both any economic award and any qualified self-provision (QSP) Reg Up AS that together represent the amount of Regulation Up capacity that the resource is expected to deliver in real-time. The input is provided in association with Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Intertie Constraint ID a‟ and 15-minute AS interval c of Trading Hour h.

29 BAHourlyResourceDARegUpMileageBidPrice Brtmdh

Day-ahead Regulation Up Mileage Bid Price (in $/MWh) in association with Business Associate ID B, Resource ID r and Resource Type t in Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are implicit).

30 CAISOHourlyDARegDownMileagePrice mdh

Provides the IFM Regulation Up Mileage marginal price (in $/MWh) in association with Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are

CAISO, 2013 of 49


implicit).

31 BA15MinuteResourceRegDownPerformanceAccuracyPercentage Brtmdhc

Provides the performance accuracy factor (as a decimal number between 0 and 1) for Regulation Down Mileage in association with Business Associate ID B, Resource ID r, Resource Type t, and 15-minute AS interval c of Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are implicit).

32 BA15MinuteResourceAdjustedRegDownMileageQty Brtmdhc

Adjusted Regulation Down Mileage (in MWh) that has incorporated any necessary under-response adjustment per resource per 15-minute interval. The input is provided in association with Business Associate ID B, Resource ID r, Resource Type t, and 15-minute AS interval c of Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are implicit).

33 DARegDownQSP

BrtuT‟I‟M‟VL‟W‟R‟F‟S‟Nz‟a‟dh

IFM Regulation Down AS qualified self-provided capacity (in MW) in association with Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Contract Reference Number N, Contract Type z‟, and Intertie Constraint ID a‟, Trading Hour h.

34 RegDownCapacitySchedule BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟hc

Final RTPD Cleared Regulation Down Capacity (in MW). The input includes both any economic award and any qualified self-provision (QSP) Reg Down AS that together represent the amount of Regulation Down capacity that the resource is expected to deliver in real-time. The input is provided in association with Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Penalty Resource ID R‟, Entity Component Type F‟, Entity Component Subtype S‟, Intertie Constraint ID a‟ and 15-minute AS interval c of Trading Hour h.

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35 BAHourlyResourceDARegDownMileageBidPrice

Brtmdh

Day-ahead Regulation Down Mileage Bid Price (in $/MWh) in association with Business Associate ID B, Resource ID r and Resource Type t in Trading Hour h, Trading Day d and Trading Month m (where subscripts d and m are implicit).

3.5 Inputs - Predecessor Charge Codes or Pre-calculations

Row

# Variable Name

Predecessor Charge Code/

Pre-calc Configuration

1 EligibleIFMMLC BrtuT‟I‟M‟F‟S‟hi Pre-calc – Start-Up and Minimum Load Cost

2 EligibleIFMSUC BrtuT‟I‟M‟F‟S‟hi Pre-calc – Start-Up and Minimum Load Cost

3 EligibleIFMPumpingCost BrtuT‟I‟M‟F‟S‟hi Pre-calc – Start-Up and Minimum Load Cost

4 EligibleIFMSDC BrtuT‟I‟M‟F‟S‟hi Pre-calc – Start-Up and Minimum Load Cost

5 EligibleIFMTC BrtuT‟I‟M‟F‟S‟hi Pre-calc – Start-Up and Minimum Load Cost

6 MLC_PMinRealTimeOnFlag BrtF‟S‟hi Pre-calc – Start-Up and Minimum Load Cost

7 MLCRealTimeOnFlag BrtF’S’hi Pre-calc – Start-Up and Minimum Load Cost

8 DA_MSSNetSupplyLMP M‟h CC 6011 – Day Ahead Energy, Congestion, Loss Settlement

9 DAMeteredEnergyAdjustmentFactor

BrtuT‟I‟M‟F‟S‟hif Pre-calc – Metered Energy Adjustment Factor

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10 TotalExpectedEnergyFiltered

BrtuT‟I‟M‟F‟S‟hif Pre-calc – Metered Energy Adjustment Factor

11 DispatchIntervalDAScheduleEnergyFiltered BrtuT‟I‟M‟F‟S‟hif

Pre-calc – Metered Energy Adjustment Factor

12 SettlementIntervalRegulationEnergy

BrtuT‟I‟M‟F‟S‟hi Pre-calc – RT Energy Quantity

13 SettlementIntervalOAEnergy

BrtuT‟I‟M‟F‟S‟hi Pre-calc – RT Energy Quantity

14 DAPumpEnergyFiltered BrtuT‟I‟M‟F‟S‟hif Pre-calc – RT Energy Quantity

15 BA15MinuteResourceHigherDAOrRTRegUpSchedule Brtmdhc


The maximum value (in MW) of the DA and RT Reg Up AS Schedules. The input amounts to the DA Reg Up Schedule plus any additional positive-valued incremental RT Reg Up AS in association with Business Associate B, Resource ID r, and Resource Type t, for 15-minute AS Interval c and Trading Hour h of Trading Day d and Trading Month m.

16 BA15MinuteResourceHigherDAOrRTRegDownSchedule Brtmdhc


The maximum value (in MW) of the DA and RT Reg Down AS Schedules. The input amounts to the DA Reg Down Schedule plus any additional positive-valued incremental RT Reg Down AS in association with Business Associate B, Resource ID r, and Resource Type t for 15-minute AS Interval c and Trading Hour h of Trading Day d and Trading Month m.



CAISO, 2013 of 49

17 BA15MinuteResourceDARegUpMileagePayment Brtmdhc


Day-Ahead Market portion of Regulation Up AS mileage settlement amount (in $) in association with Business Associate B, Resource ID r and Resource Type t for 15-minute AS Interval c and Trading Hour h of Trading Day d and Trading Month m.

18 BA15MinuteResourceDARegDownMileagePayment Brtmdhc


Day-Ahead Market portion of Regulation Down AS mileage settlement amount (in $) in association with Business Associate B, Resource ID r and Resource Type t for 15-minute AS Interval c and Trading Hour h of Trading Day d and Trading Month m.



CAISO, 2013 of 49

3.6 CAISO Formula

3.6.1 For Non-MSS entities and MSS entities with Gross Settlement Election

IFMNetAmount BruT‟I‟M‟F‟hi =

t S'

( ( 1 – BAHourlyResourceCircularScheduleFlag BrtF‟S‟h ) * (

IFMBidCostAmount BrtuT‟I‟M‟F‟S‟hi – IFMRevenueAmount BrtuT‟I‟M‟F‟S‟hi ) )

Note:

In design the hourly quantity BAHourlyResourceCircularScheduleFlag BrtF‟S‟h must be duplicated for each Settlement Interval i.

3.6.1.1 Where BAHourlyResourceCircularScheduleFlag BrtF‟S‟h =

J

PTB_BAHourlyResourceCircularScheduleFlag BrtF‟S‟Jh

3.6.1.2 Where Entity Type T‟ <> MSS or (Entity Type T‟ = MSS and Energy Settlement Type I‟ = Gross)

IFMBidCostAmount BrtuT‟I‟M‟F‟S‟hi =

(EligibleIFMSUC BrtuT‟I‟M‟F‟S‟hi+

EligibleIFMMLC BrtuT‟I‟M‟F‟S‟hi +

EligibleIFMPumpingCost BrtuT‟I‟M‟F‟S‟hi +

EligibleIFMSDC BrtuT‟I‟M‟F‟S‟hi +

EligibleIFMTC BrtuT‟I‟M‟F‟S‟hi +

IFMASBidCostAmount BrtuT‟I‟M‟F‟S‟hi +

IFMEnergyBidCostAmount BrtuT‟I‟M‟F‟S‟hi )+

IFMRegMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi)


Formatted: Body



Formatted: Body Text Indent 2


Formatted: Body Text Indent 2

Formatted: Config 2, Indent: Left: 0.5"

Formatted: Config 2, Indent: Left: 1"

Formatted: English (U.S.)


Formatted: Config 2

CAISO, 2013 of 49

IFMRevenueAmount BrtuT‟I‟M‟F’S’hi =

IFMASRevenueAmount BrtuT‟I‟M‟F‟S‟hi +

f

( IFMDAEnergyRevenueAmount BrtuT‟I‟M‟F‟S‟hif +

IFMPumpingEnergyRevenueAmount BrtuT‟I‟M‟F‟S‟hif +

IFMMinimumLoadRevenueAmount BrtuT‟I‟M‟F‟S‟hif ) +

IFMRegMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi


And (Resource Type t = GEN or ITIE) or (Resource Type t = ITIE and Entity Component Type F‟ = TG)

IFMDAEnergyRevenueAmount BrtuT‟I‟M‟F‟S‟hif =

IF

BADispatchIntervalResourceRT_IIEEnergy BrtuT‟I‟M‟F‟S‟hif > 0

THEN


V L' W' R'

( DABidAwardEnergyQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif *

DayAheadLMP rth *

DAMeteredEnergyAdjustmentFactor BrtuT‟I‟M‟F‟S‟hif )

ELSE


V L' W' R'

( DABidAwardEnergyQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif *

DayAheadLMP rth )

3.6.1.5 BADispatchIntervalResourceRT_IIEEnergy BrtuT‟I‟M‟F‟S‟hif =

TotalExpectedEnergyforBCR BrtuT‟I‟M‟F‟S‟hif –

TotalDayAheadExpectedEnergy BrtuT‟I‟M‟F‟S‟hif

3.6.1.5.1 Where Exists



Field Code Changed



CAISO, 2013 of 49

TotalExpectedEnergyforBCR BrtuT‟I‟M‟F‟S‟hif

3.6.1.5.2 And Where

TotalExpectedEnergyforBCR BrtuT‟I‟M‟F‟S‟hif =

TotalExpectedEnergyFiltered BrtuT‟I‟M‟F‟S‟hif + (1/2) * SettlementIntervalRegulationEnergy BrtuT‟I‟M‟F‟S‟hi + (1/2) * SettlementIntervalOAEnergy BrtuT‟I‟M‟F‟S‟hi

3.6.1.5.2.1 Where Exists

TotalExpectedEnergyFiltered BrtuT‟I‟M‟F‟S‟hif

3.6.1.5.3 And Where

TotalDayAheadExpectedEnergy BrtuT‟I‟M‟F‟S‟hif =

DispatchIntervalDAScheduleEnergyFiltered BrtuT‟I‟M‟F‟S‟hif + DAPumpEnergyFiltered BrtuT‟I‟M‟F‟S‟hif


IFMPumpingEnergyRevenueAmount BrtuT‟I‟M‟F‟S‟hif =

IF


THEN


V L' W' R'

( DAPumpingEnergy BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif *

DayAheadLMP rth *

IFMPumpingCostFlag BrtuT‟I‟M‟F‟S‟hi *

DAMeteredEnergyAdjustmentFactor BrtuT‟I‟M‟F‟S‟hif )

ELSE


V L' W' R'

( DAPumpingEnergy BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif *

DayAheadLMP rth *

IFMPumpingCostFlag BrtuT‟I‟M‟F‟S‟hi )

CAISO, 2013 of 49


And (Resource Type t = GEN or ITIE)

IFMMinimumLoadRevenueAmount BrtuT‟I‟M‟F‟S‟hif =

V L' W' R'

( DAMinimumLoadQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif *

DayAheadLMP rth *

SettlementIntervalIFMCAISOCommitPeriod BrtF‟S‟hi *

MLC_PMinRealTimeOnFlag BrtF‟S‟hi )

3.6.2 For MSS entities with Net Settlement election:

IFMMSSNetBCRAmount BT‟I‟M‟hi =

IFMMSSNetEnergyProRatedBidCostAmount BT‟I‟M‟hi +

IFMMSSNetASBidCostAmount BT‟I‟M‟hi +

IFMMSSNetRegMileageBidCostAmount BT‟I‟M‟hi

3.6.2.1 Where Entity Type T‟ = MSS and Energy Settlement Type I‟ = Net

And Resource Type t = GEN or where Entity Component Type F‟ = PMPP or PMPST

IFMMSSNetASBidCostAmount BT‟I‟M‟hi =

tr u S'F'

( IFMASBidCostAmount BrtuT‟I‟M‟F‟S‟hi –

IFMASRevenueAmount BrtuT‟I‟M‟F‟S‟hi )

3.6.2.2 Where IFMMSSNetEnergyProRatedBidCostAmount BT‟I‟M‟hi =

IFMMSSNetEnergyBidCostAmount BT‟I‟M‟hi *

DANetGenRatio BT‟I‟M‟hi

CAISO, 2013 of 49

3.6.2.2.1 Where IFMMSSNetEnergyBidCostAmount BT‟I‟M‟hi =

IFMMSSEnergyBidCostAmount BT‟I‟M‟hi –

IFMMSSEnergyRevenueAmount BT‟I‟M‟hi

3.6.2.2.2 Where IFMMSSEnergyBidCostAmount BT‟I‟M‟hi =

tr u F' S'

IFMResourceMSSEnergyBidCostAmount BrtuT‟I‟M‟F‟S‟hi

3.6.2.2.3 Where Entity Type T‟ = MSS and Energy Settlement Type I‟ = Net

IFMResourceMSSEnergyBidCostAmount BrtuT‟I‟M‟F‟S‟hi =

IFMMSSGenEnergyBidCost BrtuT‟I‟M‟F‟S‟hi +

EligibleIFMSUC BrtuT‟I‟M‟F‟S‟hi+

EligibleIFMMLC BrtuT‟I‟M‟F‟S‟hi +

EligibleIFMPumpingCost BrtuT‟I‟M‟F‟S‟hi +

EligibleIFMSDC BrtuT‟I‟M‟F‟S‟hi

3.6.2.2.4 And Where Entity Type T‟ = MSS and Energy Settlement Type I‟ = Net

And Resource Type t = GEN

IFMMSSGenEnergyBidCost BrtuT‟I‟M‟F‟S‟hi =

IF DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif >= 0

THEN


fRWLV '''

(b

DAScheduleEnergyAllocationQuantity BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif *

DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif) *


CAISO, 2013 of 49

DAMeteredEnergyAdjustmentFactor BrtuT‟I‟M‟F‟S‟hif

ELSE (IF DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif < 0)


fRWLV '''

(b


DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif)

3.6.2.2.5 And Where Entity Type T‟ = MSS and Energy Settlement Type I‟ = Net


IFMMSSEnergyRevenueAmount BT‟I‟M‟hi =

f'W'LV

( IFMMSSMinLoadEnergyRevenueAmount BT‟I‟M‟VL‟W‟hif +

BAMSSDispatchIntervalMSSNetDAGenEnergyBidRevenueAmount

BT‟I‟M‟VL‟W‟hif +

BAMSSDispatchIntervalMSSNetDAPumpEnergyRevenueAmount

BT‟I‟M‟VL‟W‟hif )

3.6.2.2.5.1 Where

IFMMSSMinLoadEnergyRevenueAmount BT‟I‟M‟VL‟W‟hif =

'S'F'Rutr

( DAMinimumLoadQuantity

BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif *

SettlementIntervalIFMCAISOCommitPeriod BrtF‟S‟hi * MLC_PminRealTimeOnFlag BrtF‟S‟hi * DA_MSSNetSupplyLMP M‟h )

3.6.2.2.5.2 And Where

BAMSSDispatchIntervalMSSNetDAGenEnergyBidRevenueAmount

BT‟I‟M‟VL‟W‟hif =

IF


THEN

CAISO, 2013 of 49

BAMSSDispatchIntervalMSSNetDAGenEnergyBidRevenueAmount BT‟I‟M‟VL‟W‟hif =

'S'F'Rutr

( DABidAwardEnergyQuantity

BrtuT’I’M’VL’W’R’F’S’hif * DAMeteredEnergyAdjustmentFactor

BrtuT’I’M’F’S’hif * DA_MSSNetSupplyLMP M’h )

ELSE

BAMSSDispatchIntervalMSSNetDAGenEnergyBidRevenueAmount BT‟I‟M‟VL‟W‟hif =

'S'F'Rutr

( DABidAwardEnergyQuantity

BrtuT’I’M’VL’W’R’F’S’hif * DA_MSSNetSupplyLMP M’h )

3.6.2.2.5.3 And Where



IF


THEN



'S'F'Rutr

( DAPumpingEnergy

BrtuT’I’M’VL’W’R’F’S’hif *


DAMeteredEnergyAdjustmentFactor BrtuT’I’M’F’S’hif *

DA_MSSNetSupplyLMP M’h )

ELSE



'S'F'Rutr

( DAPumpingEnergy

BrtuT’I’M’VL’W’R’F’S’hif *








CAISO, 2013 of 49


DA_MSSNetSupplyLMP M’h )

3.6.2.2.6 Where DANetGenRatio BT‟I‟M‟hi =

IF DAMSSGrossGenTotal BT‟I‟M‟hi <> 0

THEN

DANetGenRatio BT‟I‟M‟hi =

MAX (0, DAMSSNetSchedule BT‟I‟M‟hi / DAMSSGrossGenTotal BT‟I‟M‟hi )

ELSE

DANetGenRatio BT‟I‟M‟hi = 0



DAMSSNetSchedule BT‟I‟M‟hi =

MAX (0, (tr u F'R'WLV '' S'

f

DABidAwardEnergyQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif +

f

DASelfSchedule BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif +

f

DAMinimumLoadQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif +

f

DAPumpingEnergy BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif +

SettlementIntervalDALoadSchedule BT‟I‟M‟W‟VL‟hi )

CAISO, 2013 of 49


And Resource Type t = LOAD

SettlementIntervalDALoadSchedule BT‟I‟M‟W‟VL‟hi =

vSFpRA'Autr '''

( DALoadSchedule

BrtuT‟I‟M‟AA‟R‟pW‟F‟S‟vVL‟h / N )

Where N = Number of Settlement Intervals in a Trading Hour



DAMSSGrossGenTotal BT‟I‟M‟hi =

tr u V W'L' F'R' fS'

(DABidAwardEnergyQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif +

DASelfSchedule BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif +

DAMinimumLoadQuantity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟hif )

3.6.2.3 Where Entity Type T‟ = MSS and Energy Settlement Type I‟ = Net


IFMMSSNetRegMileageBidCostAmount BT‟I‟M‟hi =

tr u S'F'

(IFMRegMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi –

IFMRegMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi)

CAISO, 2013 of 49

3.6.3 IFMASBidCostAmount BrtuT‟I‟M‟F‟S‟hi =

L'V

'aR'W'

( (DAAwardedSpinBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DASpinBidPrice BrtuT‟I‟M‟VL‟W‟R‟F‟S‟h) +

(DAAwardedNonSpinBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DANonSpinBidPrice BrtuT‟I‟M‟VL‟W‟R‟F‟S‟h) +

(DAAwardedRegUpBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DARegUpBidPrice BrtuT‟I‟M‟VL‟W‟R‟F‟S‟h) +

(DAAwardedRegDownBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DARegDownBidPrice BrtuT‟I‟M‟VL‟W‟R‟F‟S‟h) ) / N


3.6.4 IFMASRevenueAmount BrtuT‟I‟M‟F‟S‟hi =

L'V 'aR'W'

( (DAAwardedSpinBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DASpinCapacityASMP rth ) +

(DAAwardedNonSpinBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DANonSpinCapacityASMP rth ) +

(DAAwardedRegUpBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DARegUpCapacityASMP rth) +

(DAAwardedRegDownBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h *

DARegDownCapacityASMP rth) ) / N



Formatted: Config 1


Formatted: Style Heading 3Heading 3 Char1h3Char CharHeading 3 Char Charh3...

CAISO, 2013 of 49

3.6.5 And Where Entity Type T‟ <> MSS or (Entity Type T‟ = MSS and Energy Settlement Type I‟ = Gross) And (Resource Type t = GEN or ITIE)

IFMEnergyBidCostAmount BrtuT‟I‟M‟F‟S‟hi =

IF DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif >= 0

THEN


L'V R'W' f

(b


DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif) *

DAMeteredEnergyAdjustmentFactor BrtuT‟I‟M‟F‟S‟hif

ELSE (IF DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif < 0)


L'V R'W' f

(b


DAEnergyBidPrice BrtuT‟bI‟M‟VL‟W‟R‟F‟S‟hif)

IFM Regulation Mileage Bid Cost

3.6.6 Where IFMRegMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi =

IFMRegUpMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi + IFMRegDownMileageBidCostAmount


IFM Regulation Up Mileage Bid Cost

3.6.6.1 Where IFMRegUpMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi =

f

BADispatchIntervalResourceIFMRegUpMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hif

3.6.6.2 Where BADispatchIntervalResourceIFMRegUpMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hif =

c

(BA15MinResourceIFMRegUpMileageSelfProvidedBidCostAmount BrtuT‟I‟M‟F‟S‟hc


Formatted: Config 1

Formatted: Configuration Subscript, Font: 11pt

CAISO, 2013 of 49

+ BA15MinResourceIFMRegUpMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc)

IFM Regulation Up Mileage Self-Provided Bid Cost

3.6.6.3 Where BA15MinResourceIFMRegUpMileageSelfProvidedBidCostAmount

BrtuT‟I‟M‟F‟S‟hc =

IF BA15MinResourceRegUpCapacity BrtuT‟I‟M‟F‟S‟hc <> 0 THEN

BA15MinResourceIFMRegUpMileageSelfProvidedBidCostAmount BrtuT‟I‟M‟F‟S‟hc = (CAISOHourlyDARegUpMileagePrice h * BA15MinuteResourceRegUpPerformanceAccuracyPercentage Brthc * BA15MinuteResourceAdjustedRegUpMileageQty Brthc * (BA15MinResourceIFMRegUpQSPCapacity BrtuT‟I‟M‟F‟S‟hc / BA15MinuteResourceHigherDAOrRTRegUpSchedule Brtmdhc ) )

ELSE BA15MinResourceIFMRegUpMileageSelfProvidedBidCostAmount BrtuT‟I‟M‟F‟S‟hc = 0

Where Exists

BA15MinResourceIFMRegUpQSPCapacity BrtuT‟I‟M‟F‟S‟hc Note:

In design the hourly quantity CAISOHourlyDARegUpMileagePrice h must be duplicated for each 15-minute interval.

3.6.6.4 Where BA15MinResourceIFMRegUpQSPCapacity BrtuT‟I‟M‟F‟S‟hc =

''''' azNRWLV

DARegUpQSP BrtuT‟I‟M‟VL‟W‟R‟F‟S‟Nz‟a‟dh

Where

Resource Type t = GEN or ITIE Note:

In design the hourly quantity DARegUpQSP BrtuT‟I‟M‟VL‟W‟R‟F‟S‟Nz‟a‟dh must be duplicated for each 15-minute interval.

3.6.6.5 Where BA15MinResourceRegUpCapacity BrtuT‟I‟M‟F‟S‟hc =

'''' aRWLV

RegUpCapacitySchedule BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟hc

IFM Regulation Up Mileage Awarded Bid Cost

3.6.6.6 Where BA15MinResourceIFMRegUpMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc =

IF BA15MinResourceRegUpCapacity BrtuT‟I‟M‟F‟S‟hc <> 0 THEN

BA15MinResourceIFMRegUpMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc =

CAISO, 2013 of 49

(BAHourlyResourceDARegUpMileageBidPrice Brth * BA15MinuteResourceRegUpPerformanceAccuracyPercentage Brthc * BA15MinuteResourceAdjustedRegUpMileageQty Brthc * (BA15MinResourceIFMRegUpAwardedBidCapacity BrtuT‟I‟M‟F‟S‟hc / BA15MinuteResourceHigherDAOrRTRegUpSchedule Brtmdhc ) )

ELSE BA15MinResourceIFMRegUpMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc = 0

Where Exists BA15MinResourceIFMRegUpAwardedBidCapacity BrtuT‟I‟M‟F‟S‟hc

Note:

In design the hourly quantity BAHourlyResourceDARegUpMileageBidPrice Brth must be duplicated for each 15-minute interval.

3.6.6.7 BA15MinResourceIFMRegUpAwardedBidCapacity BrtuT‟I‟M‟F‟S‟hc =

'''' aRWLV

DAAwardedRegUpBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h

Where

Resource Type t = GEN or ITIE

Note:

In design the hourly quantity DAAwardedRegUpBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h must be duplicated for each 15-minute interval.

IFM Regulation Down Mileage Bid Cost

3.6.6.8 Where IFMRegDownMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi =

f

BADispatchIntervalResourceIFMRegDownMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hif

3.6.6.9 Where BADispatchIntervalResourceIFMRegDownMileageBidCostAmount

BrtuT‟I‟M‟F‟S‟hif =

c

(BA15MinResourceIFMRegDownMileageSelfProvidedBidCostAmount

BrtuT‟I‟M‟F‟S‟hc + BA15MinResourceIFMRegDownMileageAwardedBidCostAmount

BrtuT‟I‟M‟F‟S‟hc)

IFM Regulation Down Mileage Self-Provided Bid Cost

3.6.6.10 Where BA15MinResourceIFMRegDownMileageSelfProvidedBidCostAmount


IF BA15MinResourceRegDownCapacity BrtuT‟I‟M‟F‟S‟hc <> 0

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THEN BA15MinResourceIFMRegDownMileageSelfProvidedBidCostAmount BrtuT‟I‟M‟F‟S‟hc = (CAISOHourlyDARegDownMileagePrice h * BA15MinuteResourceRegDownPerformanceAccuracyPercentage Brthc * BA15MinuteResourceAdjustedRegDownMileageQty Brthc * (BA15MinResourceIFMRegDownQSPCapacity BrtuT‟I‟M‟F‟S‟hc / BA15MinuteResourceHigherDAOrRTRegDownSchedule Brtmdhc ) )

ELSE BA15MinResourceIFMRegDownMileageSelfProvidedBidCostAmount BrtuT‟I‟M‟F‟S‟hc = 0

Where Exists

BA15MinResourceIFMRegDownQSPCapacity BrtuT‟I‟M‟F‟S‟hc Note:

In design the hourly quantity CAISOHourlyDARegDownMileagePrice h must be duplicated for each 15-minute interval.

3.6.6.11 Where BA15MinResourceIFMRegDownQSPCapacity BrtuT‟I‟M‟F‟S‟hc =

''''' azNRWLV

DARegDownQSP BrtuT‟I‟M‟VL‟W‟R‟F‟S‟Nz‟a‟dh

Where

Resource Type t = GEN or ITIE Note:

In design the hourly quantity DARegDownQSP BrtuT‟I‟M‟VL‟W‟R‟F‟S‟Nz‟a‟dh must be duplicated for each 15-minute interval.

3.6.6.12 Where BA15MinResourceRegDownCapacity BrtuT‟I‟M‟F‟S‟hc =

'''' aRWLV

RegDownCapacitySchedule BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟hc

IFM Regulation Down Mileage Awarded Bid Cost

3.6.6.13 Where BA15MinResourceIFMRegDownMileageAwardedBidCostAmount


IF BA15MinResourceRegDownCapacity BrtuT‟I‟M‟F‟S‟hc <> 0 THEN

BA15MinResourceIFMRegDownMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc = (BAHourlyResourceDARegDownMileageBidPrice Brth * BA15MinuteResourceRegDownPerformanceAccuracyPercentage Brthc * BA15MinuteResourceAdjustedRegDownMileageQty Brthc * (BA15MinResourceIFMRegDownAwardedBidCapacity BrtuT‟I‟M‟F‟S‟hc / BA15MinuteResourceHigherDAOrRTRegDownSchedule Brtmdhc ) )

ELSE

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BA15MinResourceIFMRegDownMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc = 0

Where Exists BA15MinResourceIFMRegDownAwardedBidCapacity BrtuT‟I‟M‟F‟S‟hc

Note:

In design the hourly quantity BAHourlyResourceDARegDownMileageBidPrice Brth must be duplicated for each 15-minute interval.

3.6.6.14 BA15MinResourceIFMRegDownAwardedBidCapacity BrtuT‟I‟M‟F‟S‟hc =

'''' aRWLV

DAAwardedRegDownBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h

Where

Resource Type t = GEN or ITIE

Note:

In design the hourly quantity DAAwardedRegDownBidCapacity BrtuT‟I‟M‟VL‟W‟R‟F‟S‟a‟h must be duplicated for each 15-minute interval.

IFM Regulation Mileage Revenue

3.6.7 Where IFMRegMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi =

IFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi + IFMRegDownMileageRevenueAmount


IFM Regulation Up Mileage Revenue

3.6.7.1 Where IFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi =

f

BADispatchIntervalResourceIFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hif

3.6.7.2 Where BADispatchIntervalResourceIFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hif =

c

BA15MinResourceIFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hc

3.6.7.3 Where BA15MinResourceIFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hc =

(-1) * BA15MinuteResourceDARegUpMileagePayment Brtmdhc Where Exists

BA15MinResourceRegUpCapacity BrtuT‟I‟M‟F‟S‟hc

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IFM Regulation Down Mileage Revenue

3.6.7.4 Where IFMRegDownMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi =

f

BADispatchIntervalResourceIFMRegDownMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hif

3.6.7.5 Where BADispatchIntervalResourceIFMRegDownMileageRevenueAmount

BrtuT‟I‟M‟F‟S‟hif =

c

BA15MinResourceIFMRegDownMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hc

3.6.7.6 Where BA15MinResourceIFMRegDownMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hc =

(-1) * BA15MinuteResourceDARegDownMileagePayment Brtmdhc Where Exists

BA15MinResourceRegDownCapacity BrtuT‟I‟M‟F‟S‟hc

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3.7 Outputs

Output

Req ID

Name Description

In addition to any outputs listed below, all inputs shall be included as outputs.

1 IFMNetAmount BruT‟I‟M‟F‟hi

The net difference of IFM Bid Costs and IFM Market Revenue for Business Associate ID B, Resource ID r, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Trading Hour h, and Settlement Interval i.

2 BAHourlyResourceCircularScheduleFlag BrtF‟S‟h

Flag input output that indicates whether or not a system resource has a circular schedule in association with Business Associate ID B, Resource ID r, Resource Type t, Entity Component Type F‟, Entity Component Subtype S‟ and Trading Hour h. The input = 1 to indicate a circular schedule and is blank otherwise (when a resource does not have a circular schedule).

3 IFMBidCostAmount


The Total IFM Bid Costs including eligible SUC, MLC, TC, A/S Bid Costs, and Energy Bid Costs for Business Associate ID B, Resource ID r, resource type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i.

4 IFMRevenueAmount


The Total IFM Revenues as the summation of A/S Revenues and Energy Revenues by Business Associate ID B, Resource ID r, resource type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i.

Formatted Table



Formatted Table


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5

IFMDAEnergyRevenueAmount

BrtuT‟I‟M‟F‟S‟hif

IFM Energy Revenue for awarded Day Ahead Energy above Minimum Load and Day Ahead Self-Scheduled Energy for Business Associate ID B, Resource ID r, resource type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

6 BADispatchIntervalResourceRT_IIEEnergy


Instructed Imbalance Energy (calculated as the sum of Energy components TEE, OA and Regulation from which is subtracted the Day-Ahead Expected Energy) associated with Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

7 TotalExpectedEnergyforBCR BrtuT‟I‟M‟F‟S‟hif

Dispatch Interval Energy that corresponds to the Energy produced or consumed at the DOP, including OA Energy and Regulation Energy, for Business Associate ID B, Resource ID r, Resource type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, and MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f, where the Resource ID r is not associated with WHEEL Energy.

8 TotalDayAheadExpectedEnergy BrtuT‟I‟M‟F‟S‟hif

Day-Ahead Expected associated with Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.





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9 IFMPumpingEnergyRevenueAmount BrtuT‟I‟M‟F‟S‟hif

IFM Pumping Energy Revenue for Business Associate ID B, Resource ID r, resource type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i, and Dispatch Interval f.

10 IFMMinimumLoadRevenueAmount BrtuT‟I‟M‟F‟S‟hif

IFM Minimum Load Revenue for Business Associate ID B, Resource ID r, resource type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i, and Dispatch Interval f.

11 IFMMSSNetBCRAmount

BT‟I‟M‟hi

The net difference of IFM Energy Bid Costs, IFM AS Costs, IFM Market Revenue, and IFM AS Revenue an MSS entity that has elected net Settlement by Business Associate ID B, Resource ID r, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.

12 IFMMSSNetASBidCostAmount BT‟I‟M‟hi

The net difference between IFM AS Bid Costs and IFM AS Market Revenue for an MSS entity that has elected net Settlement by Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.

13 IFMMSSNetEnergyProRatedBidCostAmount

BT‟I‟M‟hi

The net difference between IFM Energy Bid Costs and IFM Energy Market Revenue for an MSS entity that has elected net Settlement pro-rated by the ratio of net positive MSS Generation schedules to the gross MSS Generation schedules by Business Associate ID B, Resource ID r, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.






Formatted: Config 2


CAISO, 2013 of 49

14 IFMMSSNetEnergyBidCostAmount BT’I’M’hi

The net difference between IFM Energy Bid Costs and IFM Market Revenue an MSS entity that has elected net Settlement by Business Associate ID B, Resource ID r, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.

15 IFMMSSEnergyBidCostAmount BT‟I‟M‟hi

Total IFM MSS Bid Cost for an MSS entity that has elected net Settlement for Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, Settlement Interval i.

16 IFMResourceMSSEnergyBidCostAmount


IFM MSS Bid Cost for an MSS entity that has elected net Settlement calculated as the summation of eligible Startup Costs, Minimum Load Costs, Pumping Costs, and DA Energy Bid costs for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

17 IFMMSSGenEnergyBidCost BrtuT’I’M’F’S’hi

IFM Bid Cost for a generator resource associated with an MSS entity that has elected net Settlement for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i.

18 IFMMSSEnergyRevenueAmount BT’I’M’hi

Total IFM Energy Revenue for an MSS entity that has elected net Settlement calculated as the summation of eligible DA Awarded Energy quantities, DA Minimum Load quantities, and Pumping Energy multiplied by the weighted average MSS LMP for Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.



Formatted: Config 2





Formatted: Config 2



Formatted: Config 2

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19 IFMMSSMinLoadEnergyRevenueAmount BT‟I‟M‟VL‟W‟hif

IFM Minimum Load Energy Revenue for an MSS entity that has elected net Settlement calculated as the product of the eligible DA Minimum Load Energy quantity and weighted average MSS LMP for Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f.

20 BAMSSDispatchIntervalMSSNetDAGenEnergyBidRevenueAmount BT‟I‟M‟VL‟W‟hif

IFM DA Bid-awarded Energy Revenue attributable to a Generating Unit for an MSS entity that has elected net Settlement calculated as the eligible DA Awarded Energy multiplied by the weighted average MSS LMP for Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f..

21 BAMSSDispatchIntervalMSSNetDAPumpEnergyRevenueAmount BT‟I‟M‟VL‟W‟hif

IFM DA Bid-awarded Pumping Energy Revenue attributable to a Pumped-Storage Hydro Unit for an MSS entity that has elected net Settlement calculated as the eligible DA Awarded Energy multiplied by the weighted average MSS LMP for Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, RUC Participation Flag V, Load Following Flag L‟, MSS Emission Pay Flag W‟, Trading Hour h, Settlement Interval i, and Dispatch Interval f..

22 DANetGenRatio BT’I’M’hi

DA Net Generation Ratio of net positive MSS Generation schedules to the gross MSS Generation schedules an MSS entity that has elected net Settlement by Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.

23 DAMSSNetSchedule

BT’I’M’hi

Day Ahead MSS Net Schedule for an MSS entity that has elected net Settlement by Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.



Formatted: Config 2



Formatted: Config 2



Formatted: Config 2



Formatted: Config 2



Formatted: Config 2

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24 SettlementIntervalDALoadSchedule BT‟I‟M‟W‟VL‟hi

Settlement Interval Day Ahead Load Schedule for Business Associate ID B, Resource ID r, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, MSS Emission Pay Flag W‟, RUC Participation Flag V, Load Following Flag L‟, Trading Hour h, and Settlement Interval i.

25

DAMSSGrossGenTotal

BT’I’M’hi

DA MSS Gross Generation Total an MSS entity that has elected net Settlement by each Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Trading Hour h, and Settlement Interval i.

26 IFMMSSNetRegMileageBidCostAmount BT‟I‟M‟hi

For a net-settled MSS entity the output reflects the IFM Regulation Mileage Bid Cost amount minus the IFM Regulation Mileage Revenue amount (in $), in association with Business Associate ID B, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟ and Settlement Interval i of Trading Hour h, where Settlement Type I‟ = „Net‟.

27 IFMASBidCostAmount


Summation of A/S Bid Costs divided by the number of Settlement Intervals in a Trading Hour in which Awarded A/S Capacity is multiplied by the relevant A/S Bid Price for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i.

28 IFMASRevenueAmount


Summation of A/S Revenue divided by the number of Settlement Intervals in a Trading Hour in which Awarded A/S Capacity is multiplied by the relevant resource specific ASMP for Business Associate ID B, Resource ID r, Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i.



Formatted: Config 2



Formatted: Config 2


Formatted Table


CAISO, 2013 of 49

29 IFMEnergyBidCostAmount BrtuT‟I‟M‟F‟S‟hi

Energy Bid Costs calculated as the Day Ahead Energy multiplied by the relevant the Energy Bid Price and adjusted for the portion of Day Ahead Schedule that is not delivered based upon meter data for Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, Trading Hour h, and Settlement Interval i.

30 IFMRegMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi

IFM Regulation Mileage Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Settlement Interval i of Trading Hour h.

31 IFMRegUpMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi

IFM Regulation Up Mileage Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Settlement Interval i of Trading Hour h.

32 BADispatchIntervalResourceIFMRegUpMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hif

IFM Regulation Up Mileage Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Dispatch Interval f and Settlement Interval i of Trading Hour h.

33

BA15MinResourceIFMRegUpMileageSelfProvidedBidCostAmount

BrtuT‟I‟M‟F‟S‟hc

IFM Regulation Up Mileage self-provided Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.


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34 BA15MinResourceIFMRegUpQSPCapacity BrtF‟S‟hc

IFM Regulation Up AS qualified self-provided capacity (in MW) in association with Business Associate ID B, Resource ID r , Resource Type t, Entity Component Type F‟, Entity Component Subtype S‟, Intertie, and 15-minute AS interval c of Trading Hour h.

35 BA15MinResourceRegUpCapacity BrtuT‟I‟M‟F‟S‟hc

Regulation Up capacity (in MW) total over the IFM and Real-Time markets in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

36 BA15MinResourceIFMRegUpMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc

IFM Regulation Up Mileage awarded Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

37 BA15MinResourceIFMRegUpAwardedBidCapacity


IFM Regulation Up awarded Bid capacity (in MW) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

38 IFMRegDownMileageBidCostAmount BrtuT‟I‟M‟F‟S‟hi

IFM Regulation Down Mileage Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Settlement Interval i of Trading Hour h.

CAISO, 2013 of 49

39

BADispatchIntervalResourceIFMRegDownMileageBidCostAmount


IFM Regulation Down Mileage Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Dispatch Interval f and Settlement Interval i of Trading Hour h.

40

BA15MinResourceIFMRegDownMileageSelfProvidedBidCostAmount


IFM Regulation Down Mileage self-provided Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

41 BA15MinResourceIFMRegDownQSPCapacity

BrtF‟S‟hc

IFM Regulation Down AS qualified self-provided capacity (in MW) in association with Business Associate ID B, Resource ID r , Resource Type t, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

42 BA15MinResourceRegDownCapacity BrtuT‟I‟M‟F‟S‟hc

Regulation Down capacity (in MW) total over the IFM and Real-Time markets in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

43 BA15MinResourceIFMRegDownMileageAwardedBidCostAmount BrtuT‟I‟M‟F‟S‟hc

Regulation Down mileage awarded Bid Cost amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

CAISO, 2013 of 49

44 BA15MinResourceIFMRegDownAwardedBidCapacity BrtuT‟I‟M‟F‟S‟hc

IFM Regulation Down AS awarded bid capacity (in MW) in association with Business Associate ID B, Resource ID r , Resource Type t, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

45 IFMRegMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi

IFM Regulation Mileage revenue amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Settlement Interval i of Trading Hour h.

46 IFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi

IFM Regulation Up Mileage revenue amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Settlement Interval i of Trading Hour h.

47

BADispatchIntervalResourceIFMRegUpMileageRevenueAmount


IFM Regulation Up Mileage revenue amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Dispatch Interval and Settlement Interval i of Trading Hour h.

49 BA15MinResourceIFMRegUpMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hc

IFM Regulation Up Mileage revenue amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

50 IFMRegDownMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hi

IFM Regulation Down Mileage revenue amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Settlement Interval i of Trading Hour h.

CAISO, 2013 of 49

51

BADispatchIntervalResourceIFMRegDownMileageRevenueAmount


IFM Regulation Down Mileage revenue amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and Dispatch Interval and Settlement Interval i of Trading Hour h.

52 BA15MinResourceIFMRegDownMileageRevenueAmount BrtuT‟I‟M‟F‟S‟hc

IFM Regulation Down Mileage revenue amount (in $) in association with Business Associate ID B, Resource ID r , Resource Type t, UDC Index u, Entity Type T‟, MSS Gross/Net Energy Settlement Type I‟, MSS Subgroup M‟, Entity Component Type F‟, Entity Component Subtype S‟, and 15-minute AS interval c of Trading Hour h.

CAISO, 2013 of 49

4. Charge Codes Effective Dates

Charge Code/

Pre-calc Name

Document

Version

Effective

Start Date

Effective

End Date

Version Update

Type

Pre-Calc IFM Net Amount

5.0 04/01/09 03/31/09 Documentation

Edits Only


5.1 04/01/09 07/31/10 Configuration

Impacted


5.1a 08/01/10 07/31/10 Documentation

Edits Only


5.2 12/08/10 12/07/10 Configuration

Impacted


5.3 08/01/10 03/25/11

Documentation Edits and

Configuration Impacted


5.4 03/26/11 06/22/11




5.5 06/23/11 01/31/13




5.6 02/01/13 04/30/13O

pen




5.7 05/01/13 Open






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