Business Requirements Specification Template

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Business Requirements Specification

Energy Storage Enhancements Track 2

Document Version: 1.5

Current Version Date: 10/13/2023

Revision History

Date

Version

Description

5/25/2023

1.0

Document Created

6/27/2023

1.1

Updates in red reflect State of Charge scope:

1.1 Purpose Statement

2.1 Description

3.1 BPMs

3.2 Other

Added the following BRQs:

102, 103, 104, 113, MSIM-001, MSIM-002

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Date

Version

Description

8/8/2023

1.2

Updates in red:

 Added requirements BRQ250, BRQ251,

BRQ252, BRQ253, and BRQ254.

 Updated BRQ030 with Tariff Section.

 Updated Section 3.1 for BPM changes

from additional requirements.

8/17/2023

1.3

Updates in red:

 Updated BRQ103

 Added Section 4.10 with the following

BRQs: BRQ076 – BRQ087, BRQ093,

BRQ094, and BRQ203.

 Added MSIM–003.

9/12/2023

1.4

Updates in red:

 Removed BRQ094

10/11/2023

1.5

Updates in red:

Updated BRQ093, BRQ077, BRQ078.

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All information contained in this draft Business Requirements Specification (BRS) as provided by the

California Independent System Operator Corporation (ISO) is prepared for discussion and

information purposes only. The draft BRS is provided “as is” without representation or warranty of

any kind, including, without limitation, a representation or warranty as to accuracy, completeness, or

appropriateness for any particular purpose. The draft BRS shall be revised as the development and

review of the business requirements progresses. The ISO assumes no responsibility for the

consequences of any errors or omissions. The ISO may revise or withdraw all or part of this

information at any time at its discretion without notice.

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Table of Contents

1 Introduction

1.1 Purpose

The purpose of this document is to capture and record a description of what the Users and Business

Stakeholders of the project wish to obtain, by providing high level business requirements. This document

establishes the basis for the agreement between the initiators and implementers of the project. The

information in this document serves as input to determine the scope of projects and all Business Process

Modeling and System Requirements Specifications (SRS) efforts.

Business requirements are what must be delivered to provide value for the Users and Business

Stakeholders. Systems, software, and processes are the ways (how) to deliver, satisfy, or meet the

business requirements (what).

Project Background

Storage developers are rapidly deploying new utility-scale resources onto the California grid to provide

replacement capacity for retiring resources and to meet procurement mandates authorized by the

California Public Utilities Commission.

The purpose of this initiative is to enhance reliability tools and the co-located model with regards to storage

resources. The reliability enhancements includes updates to bidding rules, exceptional dispatch of storage

resources, storage resource opportunity costs, and local area minimum online constraints. The co-located

model enhancements include preventing co-located resources from charging when beyond generation

levels for on-site resources and allowing pseudo-tied resources to use the co-located model.

Project Scope

Reliability Enhancements

 Allow for Exceptional Dispatches (EDs) to be issued for storage resources to hold SOC

o Develop functionality within ED User Interface; automate existing excel tool functionality

o Storage may receive a traditional ED or an SOC ED, but not both

 Moved from Track 1 to Track 2: Include lost opportunity cost from not generating in storage

resource compensation due to Exceptional Dispatch (ED) to hold SOC (i.e. 0 MW ED)

o Calculate counterfactual energy revenues with and without the SOC Hold ED

o If prices are below bids counterfactuals will not include discharges

o Use actual LMPs (the ISO will not generate counterfactual LMPs)

o Include SOC Hold ED period through the end of the day in time horizon

o Different Settlement process than traditional ED

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Co-Located Model Enhancements

 Develop an electable co-located model available to all storage resources

o Storage schedules to never exceed renewable schedules (i.e. no grid charging)

o Storage may deviate down to match solar, when solar is producing less than schedules in

real-time

o Deviations to be subject to imbalance energy charges

o Require storage resources to submit outages when depleted and unable to charge

o Require all resources to respond to operator and ED instructions within physical bounds of

operation

 Allow for co-located pseudo-tie resources to apply Aggregate Capability Constraint (ACC)

o Resources under an ACC must be pseudo-tied from the same BAA

2 Details of Business Need/Problem

2.1 Description

Business Opportunity/Problem Statement:

What:

This initiative includes enhancements to the ED UI to allow

Operators to better manage energy storage resource state of

charge. In addition, this initiative includes a new counter-factual

opportunity cost methodology to settle EDs to hold SOC. The

initiative also includes enhancements and to the co-located model

to support storage resource VER grid charging only (i.e. no grid

charging.

Why do we have this

opportunity/problem:

The number of storage resources interconnecting to the ISO grid is

rapidly growing. Storage resources can charge and discharge;

therefore they function inherently differently from one-way

generation and load. Current operator tools, bidding rules, market

optimization, and settlement rules require enhancements to

accommodate the influx of storage resources to the grid.

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3 Project Impact Assessment (IA)

3.1 Business Practice Manuals (BPM)

BPM

Description of Impact(s)

Market

Instruments

 Updates for external reporting of ED SOC changes

Market

Operations

 Reflect new SOC Hold and SOC Charge ED reason codes for storage

resources

 Reflect Storage resource ED SOC opportunity cost

 Reflect co-located model update to support “no grid charging”

 Impacts to regulation for co-located resources when hourly withdrawal limit =

0MW

3.2 Other

Impact

Description (optional)

Market Simulation

Yes

Market Participant Impact

ISO BA, WEIM BA

External Bid Publication

 Reflect new EDs on OASIS Operator

Initiated Commitment OASIS Report

 Impacts to CMRI for reporting of ACC

for pseudo-tied resources.

Customer Readiness Impact

Yes, see below.

 External Communication Needed

Yes

 External Onboarding and Maintenance

 External Training

Yes

 External Computer Based Training

Potential Impacts (Storage CBT)

Policy Initiative

Yes

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4 Business Requirements

The sections below describe the business processes and the associated business requirements involved

in the project. These may represent high-level functional, non-functional, reporting, and/or infrastructure

requirements. These business requirements directly relate to the high-level scope items determined for

the project.

4.1 Policy and Tariff Requirements

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

This proposal includes new functionality that will

allow dispatch to storage resources to hold a certain

state of charge (MWh), in addition to the traditional

(MW) exceptional dispatch. A tool will allow for

dispatch of storage resources to charge to and hold

a specific level of state of charge for a specific

duration of time in the real-time market.

Policy

RTM

The proposal includes an electable functionality to

limit dispatch instructions for co-located storage

resources to charge to be no greater than the

dispatch operating target of their co-located

renewable resources in both the day-ahead and

real-time markets. 9 This functionality will be

electable on an hour by hour basis and offered to

any co-located storage resource and will prevent

‘grid charging.’

Policy

SIBR

IFM/RTM

The proposal includes implementing this change,

but only for co-located resources that can be

modeled by an aggregate capability constraint and

where all resources are pseudo-tied from the same

balancing authority area to the ISO.

Policy

CMRI

This proposal includes new functionality that will

allow dispatch to storage resources to hold a certain

state of charge (MWh), in addition to the traditional

(MW) exceptional dispatch. A tool will allow for

dispatch of storage resources to charge to and hold

a specific level of state of charge for a specific

duration of time in the real-time market.

Policy

RTM

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Business Feature

Requirement

Type

Potential

Application(s)

Impacted

Actual signals for exceptional dispatch o resources

will continue to be transmitted to storage SCs via

dispatch instruction in terms of MW.

Storage resources receiving exceptional dispatch

instructions to hold state of charge will be

compensated using a different methodology than

traditional exceptional dispatch.

This compensation will be based on an opportunity

cost methodology and will capture the revenues that

the resource would have received had it been

optimally participating in the market, during the

exceptional dispatch and for a period of time after

the exceptional dispatch.

Policy

Settlements

OASIS

CMRI

The CAISO will settle storage resources that

receive an Exceptional Dispatch to hold a State of

Charge pursuant to Sections 11.5.6 and 11.5.6.1 for

any FMM Instructed Imbalance Energy or RTD

Instructed Imbalance Energy to move to the

targeted State of Charge plus the resource’s

opportunity cost for holding the State of Charge.

The CAISO will calculate this opportunity cost

starting from the first Operating Interval when the

resource met and followed the Exceptional Dispatch

through the end of the Operating Day. The CAISO

will calculate the difference between the resource’s

maximum potential RTM Energy revenues without

the Exceptional Dispatch to hold the State of

Charge and the resource’s maximum potential RTM

Energy revenues with the Exceptional Dispatch to

hold State of Charge. If the resource’s maximum

potential RTM Energy revenues without the

Exceptional Dispatch to hold State of Charge are

higher than the resource’s maximum potential RTM

Energy revenues with the Exceptional Dispatch to

hold State of Charge, then the resource will receive

the positive difference between these two values,

which is its opportunity cost. The CAISO will

calculate the resource’s opportunity costs based on

its Master File characteristics, Bids, State of

Tariff

Settlements

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Business Feature

Requirement

Type

Potential

Application(s)

Impacted

Charge, Day-Ahead Schedules, and the applicable

Locational Marginal Prices.

Section 11.5.6.1.2

For storage resources that receive an Exceptional

Dispatch to hold a State of Charge, the RTM Market

Revenue will include revenues from the opportunity

cost to hold the State of Charge but not the

Exceptional Dispatch Energy to reach the State of

Charge.

Section 11.8.4.2

Tariff

RTM

Settlements

At the request of the Interconnection Customer or

Pseudo-Tie Generating Facility, the CAISO may

enforce an Aggregate Capability Constraint for

Generating Facilities with Co-located Resources

that reflects a Generating Facility’s maximum and

minimum capability or a portion of that capability for

purposes of Day-Ahead Market Awards, Real-Time

Market Awards, and Real-Time Dispatch as

described in the CAISO’s Business Practice

Manuals.

The following resources are not eligible to use the

Aggregate Capability Constraint: Multi-Stage

Generators, Proxy Demand Response, Pumped

Storage Hydro Units, Metered Subsystems, and

Use-Limited Resources.

Section 27.13

Tariff

CMRI

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Business Feature

Requirement

Type

Potential

Application(s)

Impacted

At the request of the Scheduling Coordinator of a

Co-Located Resource that is a storage resource,

the CAISO will enforce a Charging Constraint that

reflects the storage resource’s election not to

charge beyond the output of its co-located Variable

Energy Resource(s). Where a storage resource

has a Charging Constraint registered in the Master

File, the CAISO will not issue (a) Day-Ahead

Schedules for Energy less than the negative value

of the co-located Variable Energy Resource’s Day-

Ahead Schedules; or (b) FMM Schedules or RTD

Schedules for Energy that are less than the

negative value of the co-located Variable Energy

Resource’s Dispatch Operating Target, in the same

Operating Intervals. The CAISO will not observe

Charging Constraints in Operating Intervals where

the storage resource receives an Ancillary Service

Award to provide Regulation or where the storage

resource elects to use Regulation Energy

Management.

Section 27.13

Tariff

SIBR

IFM/RTM

The CAISO may issue a manual Exceptional

Dispatch for all types of Generating Unit.

Section 34.11.1

Tariff

RTM

Co-located Resources that are Non-Generator

Resources may deviate from Dispatch Instructions

to observe their registered Charging Constraints

pursuant to Section 27.14.

Section 34.13.3

Tariff

SIBR

IFM/RTM

Charging Constraint

A constraint that reflects a storage resource’s

election not to charge beyond the output of its co-

located Variable Energy Resource.

Appendix A

Tariff

SIBR

IFM/RTM

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4.2 Business Process: Manage RIMS

4.2.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ001B

INT/EXT

BRS

App & Study  Equipment

Configuration  Generation Type

and Fuel Type shall have a new

field (column) for all resources

called MWh.

Implementation note: This new field

will be to the right of Net MW. This

is only a numeric field. This new

field must be available for entry for

existing and new RIMS A&S

projects.

Core

RIMS

ESE2-

BRQ004A

INT/EXT

BRS

System (RIMS) must have two new

fields of “MWh” and “PMin” within

the General Project information

under the Fuel Type and Megawatt

grid for each fuel type 1-4.

Core

RIMS (NRI)

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4.3 Business Process: Manage SIBR

4.3.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ020

INT/EXT

BRS

The system shall have a new bid attribute

to identify hours of the day that the sub or

standalone ACC withdrawal limit is to be

set to 0 MW

--B to B: Y/N flag (to ensure market

participants are not able to enter a value)

--Attribute=Y

--Withdrawal limit shall be defined by

market type (DAM, RTM)

Core

SIBR

ESE2-

BRQ021

INT/EXT

BRS

The system shall broadcast to downstream

systems the sub or standalone ACC

withdrawal limit=0 MW when bid attribute

(as described in BRQ020)=Y

--A to A: Flag=Ybroadcast sub or

standalone ACC withdrawal limit=0 MW

--System shall broadcast the withdrawal

limit per market type (DAM vs. RTM)

Implementation note: If Flag = Y in SIBR,

limit of 0 is sent to downstream system. If

Flag = N in SIBR, then no limit will be sent

to downstream system.

Core

SIBR

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4.4 Business Process: Manage IFM and RTM

4.4.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ030

INT/EXT

BRS

The system shall consume sub or standalone ACC

withdrawal limit=0 MW in an hourly fashion (Broadcast:

BRQ021)

--Updated hourly withdrawal limits shall be higher

priority than Internal System value, and lower priority

than UI override value

Core

Compliance:

§30.5.6.3

IFM/RTM

ESE2-

BRQ250

INT/EXT

BRS

During the hours where a standalone or sub ACC

constraint has an hourly withdrawal limit = 0 MW, all the

LES unit type resources behind the standalone or sub

ACC constraint shall not receive regulation up or

regulation down awards.

Core

Compliance:

§30.5.6.3

IFM

ESE2-

BRQ251

INT/EXT

BRS

During the hours where a standalone or sub ACC

constraint has an hourly withdrawal limit = 0 MW, and

there is no regulation up or regulation down award from

the day ahead market for any of the LES unit type

resources behind the standalone or sub ACC constraint,

all the LES unit type resources behind such constraint

shall not receive regulation up or regulation down

awards.

Core

Compliance:

§30.5.6.3

RTM

ESE2-

BRQ252

INT/EXT

BRS

The hourly withdrawal limit = 0 MW for the standalone

or sub ACC constraint shall not be enforced when there

is an LES unit type resource that has an REM flag = Y.

Core

Compliance:

§30.5.6.3

IFM/RTM

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

Master file / override values shall still apply for the

injection/withdrawal limit of the standalone or sub ACC

constraint.

ESE2-

BRQ253

INT/EXT

BRS

The hourly withdrawal limit = 0 MW for the standalone

or sub ACC constraint shall not be enforced when there

is an exceptional dispatch on any of the LES unit type

resource behind the standalone or sub ACC constraint

for the applicable interval.

Master file / override values shall still apply for the

injection/withdrawal limit of the standalone or sub ACC

constraint.

Core

Compliance:

§30.5.6.3

RTM

ESE2-

BRQ254

INT/EXT

BRS

The hourly withdrawal limit = 0 MW for the standalone

or sub ACC constraint shall not be enforced when there

is a regulation up or regulation down award from the

day ahead market, or from RTPD, on any of the LES

unit type resource behind the standalone or sub ACC

constraint

Master file / override values shall still apply for the

injection/withdrawal limit of the standalone or sub ACC

constraint

Core

Compliance:

§30.5.6.3

RTM

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4.5 Business Process: Manage WEBOMS

4.5.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ056

INT/EXT

BRS

System shall require storage resources to

submit outage cards if the co-located VER

cannot provide the charging energy as

forecasted per Tariff requirements

Existing

WebOMS

ESE2-

BRQ057

INT/EXT

BRS

System shall require storage resources to

submit outage cards if the resource has

depleted its SOC and there is no ability to

charge the resource per Tariff

requirements

Existing

WebOMS

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4.6 Business Process: Manage ITS

4.6.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ060

INT/EXT

BRS

System shall model pseudo-tied and

dynamic co-located storage resources

following the standard NRI pseudo-tie and

dynamic rules and practices

Note: pseudo-tied and dynamic storage

resources must be registered as TNGR

resources

Existing

ITS

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4.7 Business Process: Manage CMRI

4.7.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ110

INT/EXT

BRS

System shall map pseudo-tied

resource to the existing ACC

Definition Report

Existing

CMRI

ESE2-

BRQ111

INT/EXT

BRS

System shall add pseudo-tied co-

located resource’s ACC MW value to

the existing ACC Limits Report

Existing

CMRI

4.8 Business Process: Settlements

4.8.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ102

INT/EXT

BRS

System shall compensate the SC for

the storage resource that received

the ED SOC uplift.

Core

Compliance:

§11.5.6.1.2

BPM:

Settlements

& Billing

Settlements

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ103

INT/EXT

BRS

System shall allocate the total uplift

cost associated with storage resource

ED SOCs in two tiers based on:

Tier 1: Net Negative Uninstructed

Deviations

Tier 2: Measured Demand

Core

Compliance:

§11.5.2.5.2

BPM:

Settlements

& Billing

Settlements

ESE2-

BRQ104

INT/EXT

BRS

Modify real-time bid cost recovery

(BCR) charge code to account for

revenue from storage resources ED

SOC uplift.

Core

Compliance:

§11.8.4.2.1

BPM:

Settlements

& Billing

Settlements

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4.9 Business Process: OASIS

4.9.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ113

INT/EXT

BRS

Moved from Track 1:

System shall perform regression

testing to confirm that new internal

ED reason codes (“SOC Hold” and

“SOC Charge”) are included under

System Emergency Instruction Type,

as “Reason,” on the Operator Initiated

Commitment OASIS Report.

Existing

Compliance:

N/A

BPM: Market

Instruments

OASIS

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4.10 Business Process: Manage Internal System

4.10.1 Business Requirements

ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BR076

The evaluation period (AKA SOC Evaluation

Period) during which the counterfactual

calculation shall be applied for a specific

resource and starts from when a SOC Hold ED

for that resource is first applied until the end of

the trading day (11:59:59 pm).

-Calculation only needs to be performed for

resources that have an active SOC Hold ED

during the trade day.

-If only SOC Charge ED is issued, NO evaluation

is necessary.

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

ESE2-

BRQ077

The system shall determine where a resource

should have been dispatched for each 5-minute

interval in the evaluation period, assuming no

SOC Hold ED was applied (AKA Counterfactual

Effective Dispatch without SOC Hold). This

theoretical Effective Dispatch is based on the

expected dispatch point using the resource bids,

real-time prices, RT SOC, upper and lower

market energy capacity limits, and minimum and

maximum SOC levels.

The Effective Dispatch shall observe the

following (in this order):

 Physical Limitations on the resource:

Pmin/Pmax, outage cards

 EDs related to SOC Hold or SOC Charge

that limit upper operating range of the

resource (SOC Hold is NOT observed for

counterfactual without hold)

 Any other EDs

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

 Limitations due to awarded AS (all

products)

 Limitations due to SOC: operating range

limited by insufficient SOC due to

exceeding MinSOC or MaxSOC

 Economic signals from the market:

Compare LMPs and bid curves

 Given the remaining operating range of the

resource, and bid curves for energy in that

range, system shall determine Effective

Dispatch based on a comparison of the

locational marginal price and the resource

bid.

The counterfactual dispatches shall be further

constrained to account for upward and downward

AS awards. Internal System shall calculate the

limits of the MEC (Market Energy Capacity

calculated by the Internal System Commodity

Allocation process, as detailed in Market

Operations BPM Appendices) for purposes of the

ESE formula. The counterfactual dispatches shall

not exceed these MEC Limits.

Dispatch direction shall be based on a

comparison of LMP vs bid price; the existing RT

Lower/Upper Economic Dispatch (RTL/UED)

calculations can be used.

Theoretical dispatch MW shall be based on any

EDs (other than SOC Hold EDs) and the

RTL/UED value. These values are limited above

by:

(SOC - Min SOC) * 12),

And limited below by: (Max SOC-SOC) * -

12)/RTE

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

If RT Lower Economic Dispatch <> RT Upper

Economic Dispatch, indicating the resource is on

the margin, use an RTL/UED at the average

output of the bid segment.

Five-minute interval final dispatch MW = ED MW

if there is an active ED in place, other than SOC

Hold ED instructions.

Effective Dispatch shall also respect any max

GOTO or min GOTO ED instructions.

Note: if resource does not provide a bid for a

trade hour, the resource is assumed to be

dispatched to zero for intervals during that hour

in which an ED is not active.

Note: Use RTD LMP

Note: See BRQ203 for calculation of upper and

lower market energy capacity limits

ESE2-

BRQ078

The system shall determine where a resource

should have been dispatched for each 5-minute

interval in the evaluation period, assuming SOC

Hold EDs were applied (AKA Counterfactual

Effective Dispatch with SOC Hold). This

theoretical Effective Dispatch is based on the

expected dispatch point using the resource bids,

real-time prices, RT SOC, SOC Hold ED, SOC

Charge ED, upper and lower market energy

capacity limits, and minimum and maximum SOC

levels.

The Effective Dispatch shall observe the

following (in this order):

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

 Physical Limitations on the resource:

Pmin/Pmax, outage cards

 EDs related to SOC Hold or SOC Charge

that limit upper operating range of the

resource (SOC Hold IS observed for

counterfactual with hold)

 Any other EDs

 Limitations due to awarded AS (all

products)

 Limitations due to SOC: operating range

limited by insufficient SOC due to

exceeding MinSOC or MaxSOC

 Economic signals from the market:

Compare LMPs and bid curves

 Given the remaining operating range of the

resource, and bid curves for energy in that

range, system shall determine Effective

Dispatch based on a comparison of the

locational marginal price and the resource

bid.

Dispatch direction shall be based on a

comparison of LMP vs bid price; the existing RT

Lower/Upper Economic Dispatch (RTL/UED)

calculation value can be used.

The counterfactual dispatches shall be further

constrained to account for upward and downward

AS awards. Internal System shall calculate the

limits of the MEC (Market Energy Capacity

calculated by the Internal System Commodity

Allocation process, as detailed in Market

Operations BPM Appendices) for purposes of the

ESE formula. The counterfactual dispatches shall

not exceed these MEC Limits.

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

Theoretical dispatch MW shall be based on any

EDs (other than SOC Hold EDs) and the

RTL/UED value. These values are limited above

by:

(SOC - Min SOC) * 12),

And limited below by:

(MAX SOC –SOC) *-12)/RTE

If RT Lower Economic Dispatch <> RT Upper

Economic Dispatch, indicating the resource is on

the margin, use RTL/UED at the average output

of the bid segment.

Five-minute interval final dispatch MW = ED MW

if there is an active ED in place, other than SOC

Hold ED instructions.

Effective Dispatch shall also respect any max

GOTO or min GOTO ED instructions.

Note: if resource does not provide a bid for a

trade hour, the resource is assumed to be

dispatched to zero for intervals during that hour

in which an ED is not active.

Note: Use RTD LMP

Note: See BRQ203 for calculation of upper and

lower market energy capacity limits

ESE2-

BRQ079

Counterfactual Dispatch calculations shall use

the following SOC limits. SOC limits shall be

calculated for every 5-minute period during the

SOC Evaluation Period.

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

Min SOC=max (Minimum SOC, Lower Charge

Limit)

Max SOC= min(Maximum SOC, Upper Charge

Limit)

ESE2-

BRQ080

For the Counterfactual Dispatch calculations,

system shall separately track storage resource

SOC based on Effective Dispatch MW values.

Initial SOC shall be the actual SOC (received via

payload) corresponding to the beginning of the

SOC Evaluation Period. After each dispatch,

SOC shall be reduced by the following formula:

If Effective Dispatch < 0

SOC_t = SOC_t-1 – (EffDispatch * RTE / 12)

Else:

SOC_t = SOC_t-1 – (EffDispatch / 12)

Note: RTE=resource specific round trip-efficiency

 For discharging instructions, efficiency

factor = 1.

 For charging instructions, efficiency factor

= value received from master file.

Note: discharging instructions (positive MW) shall

reduce the SOC, charging instructions (negative

MW) shall increase the SOC.

Note: The tracked SOC shall be used as an input

into determining the expected dispatch point for

all intervals in the SOC Evaluation period after

the first interval.

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

ESE2-

BRQ081

IF ED crosses over into the next day, then a new

SOC Evaluation Period shall be initiated for the

following day starting at 00:00

Existing

Internal

System

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

Compliance:

§11.5.6.1.2

BPM: Market

Operations

ESE2-

BRQ082

Based on the Counterfactual Dispatches without

SOC Hold (BRQ077 above), the system shall

calculate the storage resource revenue without

SOC Hold ED, which is equal to:

[(Effective Dispatch MW)*(LMP)]/12

Note: Use the RTD LMP

Note: The value will be calculated on a 5-minute

basis for settlement purposes, thus the product

above must be divided by 12.

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

ESE2-

BRQ083

Based on the Counterfactual dispatches with

SOC Hold (BRQ078 above), the system shall

calculate the storage resource revenue with SOC

Hold ED over the same time period, which is

equal to:

[(Effective Dispatch MW)*(LMP)]/12

Note: Use the RTD LMP

Note: The value will be calculated on a 5-minute

basis, thus the product above must be divided by

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

ESE2-

BRQ084

System shall calculate the total revenue without

SOC Hold ED from the interval specific

calculations within the SOC Evaluation Period.

Core

Compliance:

§11.5.6.1.2

Internal

System

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

BPM: Market

Operations

ESE2-

BRQ085

System shall calculate the total revenue with

SOC Hold ED from the interval specific

calculations within the SOC Evaluation Period.

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

ESE2-

BRQ086

If, for a particular resource, the total revenue

without SOC Hold > total revenue with SOC

Hold, then the difference shall be stored as an

uplift. Otherwise, the uplift shall be zero.

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

ESE2-

BRQ087

System shall distribute the total uplift equally

across all settlement intervals in the SOC

Evaluation Period.

-If there is no uplift, the system shall use a value

of 0.

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

ESE2-

BRQ093

System shall broadcast the following information

to downstream systems:

 ED start time

 ED end time

 Resource ID

 SOC Hold instruction Reason Code

 Instruction Type of the first SOC Hold ED

of the day, listed for all intervals of the

evaluation period.

 Counterfactual dispatch MW with hold

 Counterfactual dispatch MW without hold

Core

Compliance:

N/A

BPM: N/A

Internal

System

(CMRI)

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ID#

Business Feature

Requirement

Type

Potential

Application(s)

Impacted

ESE2-

BRQ203

The system shall calculate the limits (upper and

lower) of the Market Energy Capacity (MEC) for

storage resource counterfactual calculations.

These limits shall mark the operational MW

values bracketing the MEC currently calculated

by the Internal System Commodity Allocation

Process.

Note: MEC limits are utilized in BRQ077 and

BRQ078

Core

Compliance:

§11.5.6.1.2

BPM: Market

Operations

Internal

System

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4.11 Business Process: Market/Business Simulation

This section shall provide a basis for the development of the Market/Business Simulation Scenarios.

These requirements will provide guidance on the market participant impacts, inputs into the

Scenarios, endpoints to the Scenarios and reasons for potential Scenarios. The guidance on market

participant impacts shall be gathered from the requirements that impact rules, interfaces,

applications/reports, new system processes, new/modified data models, and new user roles. The

source and sink systems shall be determined through the development of the system context

diagram and the web service requirements. The Reason for the Potential Scenario column will be to

offer guidance regarding what potential scenarios, and their context, may be needed for this project.

This section applies to all policy development projects, market enhancements, technology

enhancements, operation enhancements, Energy Imbalance Market (EIM) implementations, and

Reliability Coordination (RC) service implementations. If the project team has deemed that no

structured testing is needed, an end-to-end test case must be specified.

In the Reason for Potential Scenario column, select one or more of the following reasons:

1. Rule Impacts: Generalized changes in market rules, bidding rules, settlements rules, market

design changes, or other business rules.

2. Interface changes: Changes that impact templates (e.g., the Resource Adequacy (RA) supply

plan), user interface (UI), and application programming interface (API) (e.g., retrievals of new

shadow settlement data).

3. New application/report: Changes that cause addition/modification of market software or reports,

especially when market data input is required by the market participant.

4. New system process: Modification of data flow in systems, especially if the new process

requires the market participant to demonstrate proficiency prior to production.

5. New/Modified model data: Addition or substantial modification of model data as a market

solution or export provided by the ISO.

6. New user role: The addition or modification of access permissions for a user role applied to

specific business units within an EIM entity or market participant organization (e.g., Load Serving

Entity (LSE) as a Local Regulatory Authority (LRA) role). Scenarios are beneficial for market

participants taking on a new function or process within their organization.

4.11.1 Business Requirements

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ID#

Guidance on Market Participant Impacts

Source

System

Sink

System

Reason for

Potential

Scenario

ESE2-

MSIM-

001

INT/EXT

BRS

Moved from Track 1:

Operator shall issue ED for storage

resource to hold SOC, thus triggering the

requirements to calculate counterfactual

for storage resource settlement

RTM (ED

Instructions)

Settlements

CMRI

Confirm proper

settlement for

EDs to hold

storage

resource SOC

ESE2-

MSIM-

002

INT/EXT

BRS

Moved from Track 1:

Operator shall issue ED for storage

resource to hold SOC, followed by an ED

to move SOC to confirm different ED types

for storage resource are being settled

properly

RTM (ED

Instructions)

Settlements

CMRI

Confirm proper

settlement for

EDs to hold

storage

resource SOC,

and for EDs to

charge storage

resource SOC

ESE2-

MSIM-

003

INT/EXT

BRS

Unstructured Market Sim, End-to-End:

Market Participants to confirm on their end

that the interaction between the hourly

withdrawal limit = 0 MW and regulation up

and down awards for the standalone or

sub ACC constraint is behaving as outlined

in BRQ250, BRQ251, BRQ253, and

BRQ254.

Note: Market Participants should expect

this item to be implemented after formal

market sim for this initiative due to timeline

constraints.

SIBR

IFM/RTM

Rule Impacts

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5 Acronyms and Definitions

Acronym

Definition

A2A

Application-to-Application

ABC

Available Balancing Capacity

ACL

Access Control List

ADS

Automatic Dispatch System

AGC

Automatic Generation Control

AIM

Access and Identity Management

ALFS

Automated Load Forecast System

Anode

Aggregate Node

API

Application Program Interface

Apnode

Aggregate Pricing Node

Ancillary Services

AUX

Auxiliary

B2B

Business-to-Business

Business Analyst

BAA

Balancing Authority Area

BAAOP

Balancing Authority Area Operations Portal

BCR

Bid Cost Recovery

BPM

Business Process Manual

BRS

Business Requirement Specifications

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Acronym

Definition

BSAP

Base Schedule Aggregation Portal

BSC

Base Schedule Coordinator

BSSD

(WEIM) Base Schedule Submission Deadline

CAISO

California Independent System Operator

Convergence Bidding

Commitment Cost

CCDEBE

Commitment Costs and Default Energy Bid Enhancements

CDN

Conformed Dispatch Notice

CIM

Common Information Model

CIP

Critical Infrastructure Protection

CIRA

Customer Interface for Resource Adequacy

CISO

California Independent System Operator

CLAP

Custom Load Aggregation Point

CMRI

Customer Market Results Interface

Cnode

Connectivity Node

COG

Constrained-Output Generator

CPM

Capacity Procurement Mechanism

CRN

Contract Reference Number

CRR

Congestion Revenue Rights

CRRS

Congestion Revenue Rights Settlements (aka CRR Clawback system)

CSS

Critical Systems Support

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Acronym

Definition

Day-Ahead

DACA

Day-Ahead Contingency Analysis

DAM

Day-Ahead Market

DART

Day-Ahead Reliability Tool

DCPA

Dynamic Competitive Path Assessment

DEB

Default Energy Bid

DER

Distributed Energy Resource

DCC

Default Commitment Cost

DGAP

Default Generation Aggregation Point

DMLC

Default Minimum Load Cost

DMM

Department of Market Monitoring

DOP

Dispatch Operating Point

DOT

Dispatch Operating Target

Demand Response

DRP

Demand Response Program

DSA

Dynamic Stability Analysis

DSTC

Default State Transition Cost

DSUC

Default Start Up Cost

ECIC

Energy Costs and Index Calculator

Exceptional Dispatch

EDAM

Extended Day-Ahead Market

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Acronym

Definition

EDR

Enterprise Data Repository

Expected Energy

EEA

Expected Energy Allocation

EESC

Energy Imbalance Market Entity Scheduling Coordinator

EFC

Effective Flexible Capacity

EMM

Enterprise Model Management

EMMS

Enterprise Model Management System

EMNA

Energy Management Network Application

EMS

Energy Management System

EPI

Electricity Price Index

ESP

Electronic Security Perimeter

ETC

Existing Transmission Contract

ETSR

Energy Transfer System Resources

FERC

Federal Energy Regulatory Commission

FMCA

Fifteen-Minute Contingency Analysis

FMM

Fifteen-Minute Market

FMU

Frequently Mitigated Unit

FNM

Full Network Model

FODD

FERC Outgoing Data Depository

FRCT

Forbidden Region Crossing Time

FRD

Flexible Ramp Down

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Acronym

Definition

FRU

Flexible Ramp Up

GDF

Generation Distribution Factor

GHG

Green House Gas

GIP

Generator Interconnection Procedure

GMC

Grid Management Charge

GPI

Gas Price Index

GRDT

Generator Resource Data Template

GUI

Graphical User Interface

HASP

Hour-Ahead Scheduling Process

HAVGC

Heat Average Cost (for non-gas resources)

Heat Rate

ICE

InterContinental Exchange

ICM

Infrastructure Contracts and Management

Identifier

IFM

Integrated Forward Market

ISL

Intertie Scheduling Limit

ISO

California Independent System Operator

IOOC

Integrated Optimal Outage Coordination

Information Technology

ITC

Inter-Tie Constraint

ITPD

Information Technology Product Development

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Acronym

Definition

ITS

Interchange Transaction Scheduler

ITSM

Information Technology Service Management

JOU

Joint Owned Unit

LACA

Look-Ahead Contingency Analysis

LAP

Load Aggregation Point

LDF

Load Distribution Factor

LEL

Lower Economic Limit

LFR

Lower Forbidden Region

Load Forecast

LMP

Locational Marginal Price

LMPM

Locational Market Power Mitigation

LOL

Lower Operating Limit

LRA

Local Regulatory Authority

LRL

Lower Regulation Limit

LSE

Load Serving Entity

LTCA

Long-Term Contingency Analysis

MCI

Model and Contract Implementation

Manual Dispatch

MDT

Minimum Down Time

MDS

Maximum Daily Startups

MIBP

Maximum Import Bid Price

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Acronym

Definition

MLAC

Minimum Load Average Cost

MLC

Minimum Load Cost

MLHAVGC

Minimum Load Heat Average Cost (for non-gas resources)

MLHR

Minimum Load Heat Rate

MMA

Major Maintenance Adder

MMAMLC

Major Maintenance Adder for Minimum Load Cost

MMASUC

Major Maintenance Adder for Start Up Cost

MMASTC

Major Maintenance Adder for MSG State Transition Cost

MMG

Manage Markets & Grid

MMR

Manage Market & Reliability

MOS

Manage Operations Support & Settlements

MPM

market Power Mitigation

MRID

Master Resource IDentifier

MRI-S

Market Results Interface – Settlements

MSSA

Metered Sub System Agreement

MSG

Multi-Stage Generator

MUT

Minimum Up Time

MV&A

Market Validation & Analysis

MVT

Market Validation Tool

N/A

Not Applicable

Network Application

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Acronym

Definition

NDEB

Negotiated Default Energy Bid

NGR

Non-Generating Resource

Network Model

NQC

Net Qualifying Capacity

OASIS

Open Access Same-time information System

OATI

Open Access Technology International

Opportunity Cost

OCC

Opportunity Cost Calculator

ODCP

On Demand Capacity Procurement

OES

Operations Engineering Services

OMS

Outage Management System

OOM

Out Of Market

OTS

Operations Training Simulator

PAM

Program and Application Management

PBC

Power Balance Constraint

Pre-Calculation

PCA

Price Correction Admin

PCT

Price Correction Tools

PDR

Proxy Demand Resource

Plant Information

Participating Load

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Acronym

Definition

Pmax

Maximum Generation Capacity

Pmin

Minimum Generation Capacity

PMO

Program Management Office

PNM

Public New Mexico

Pnode

Pricing Node

POC

Point Of Contact

PRSC

Participating Resource Scheduling Coordinator

PSH

Pump Storage Hydro

PSTD

Power Systems Technology Development

PSTO

Power Systems Technology Operations

PTO

Participating Transmission Owner

QRB

Quality Review Board

Resource Adequacy

Reliability Coordinator

RC-BSAP

Reliability Coordinator - Base Schedule Aggregation Portal

RCD

Reliability Capacity Down

RCSA

Reliability Coordinator Service Agreement

RCU

Reliability Capacity Up

RDOT

Ramping Dispatch Operating Target (a continuous piecewise linear curve

connecting consecutive DOTs using their mid-interval points, from RTD, RTCD,

or RTDD runs, as applicable)

RDRR

Reliability Demand Response Resource

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Acronym

Definition

RDT

Resource Data Template

RIG

Remote Intelligent Gateway

RIMS

Resource Interconnection Management System

RMR

Reliability Must Run

ROPR

Operating Reserve Ramp Rate

Ramp Rate

RREG

Regulation Ramp Rate

RSE

Resource Sufficiency Evaluation

RSEE

Resource Sufficiency Evaluation Enhancements

Real-Time

RTBS

Real-Time Base Scheduler

RTCA

Real-Time Contingency Analysis

RTCD

Real-Time Contingency Dispatch

RTD

Real-Time Dispatch

RTDD

Real-Time Disturbance Dispatch

RTPD

Real-Time Pre-Dispatch

RTM

Real-Time Market

RTUC

Real-Time Unit Commitment

RUC

Residual Unit Commitment

SADS

System And Design Specifications

Scheduling Coordinator

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Acronym

Definition

SCME

Scheduling Coordinator Meter Entity

State Estimator

SIBR

Scheduling Infrastructure and Business Rules

SME

Subject Matter Expert

SOA

Service-Oriented Architecture

SQMD

Settlements Quality Meter Data

SRS

System Requirement Specifications

STC

State Transition Cost

STF

Short-Term Forecast

STC

State Transition Cost

STT

State Transition Time

STUC

Short-Term Unit Commitment

SUC

Start Up Cost

SUE

Start Up Energy

SUF

Start Up Fuel

SURT

Start Up Ramp Time

SUT

Start Up Time

Trading Hour

TBD

To Be Determined

TEP

Tucson Electric Power

Tie Generator

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Acronym

Definition

TNA

Transmission Network Application

TOP

Transmission Operator Provider

TOR

Transmission Ownership Contract

TEE

Total Expected Energy

TTEE

Total Target Expected Energy (based on RDOT)

UAT

User Acceptance Testing

UEL

Upper Economic Limit

UFR

Upper Forbidden Region

User Interface

UIE

Uninstructed Energy Imbalance

User Limited

UOL

Upper Operating Limit

URL

Upper Regulation Limit

VER

Variable Energy Resource

VOM

Variable Operations & Maintenance

VOMC

Variable Operations & Maintenance Cost

WebOMS

Web-based Outage Management System

WEIM

Western Energy Imbalance Market

XML

Extensible Markup Language

XSD

XML Schema Definition