Market Performance and Planning Forum · SLAP_PGKN (New LCA) SLAP_SDG1 SLAP_SDG1 SLAP_PGNB SLAP_PGNB Not defined SLAP_VEA SLAP_PGNC SLAP_PGNC ... 15 15 15 15 5 15 15 15 15 15 15 5

Market Performance and Planning

Forum

September 20, 2016

Objective: Enable dialogue on implementation

planning and market performance issues

• Review key market performance topics

• Share updates to 2016 release plans, resulting from

stakeholders inputs

• Provide information on specific initiatives

–to support Market Participants in budget and

resource planning

• Focus on implementation planning; not on policy

• Clarify implementation timelines

• Discuss external impacts of implementation plans

• Launch joint implementation planning process

Page 2

Last updated: September 16, 2016

Market Performance and Planning ForumAgenda – September 20, 2016

1:00 – 1:30 Policy Update Brad Cooper

1:30 – 2:30 Release Update Adrian Chiosea

Time: Topic: Presenter:

10:00 – 10:10 Introduction, Agenda Kristina Osborne

10:10 – 10:30 Sub LAP Areas Update Jim Price

10:30 – 11:30 Market Performance and Quality

Update

Guillermo Bautista

Alderete

Amber Motley

11:30 – 12:00 Load Bias Adjustments Kyle Westendorf

12:00 – 1:00 Lunch

Sub-LAP Areas Update

Jim Price

Senior Advisor, Market & Integration Studies

Slide 4

Recap: Sub-LAPs group buses within default load

aggregation points (LAPs) with similar grid impacts

• Other than publication of locational marginal prices

(LMPs), Sub-LAPs have two purposes:– Aggregations of demand response and distributed energy

resources must be within Sub-LAPs.

– Sub-LAPs allow more precise reflection of congestion costs for

congestion revenue rights (CRRs) than default LAPs, and allow

additional CRRs to be awarded when congestion limits awards

to default LAPs.

• Tariff does not list Sub-LAPs, or prescribe how

boundaries of Sub-LAPs are determined.

• Existing Sub-LAPs were identified when current market

design was implemented in MRTU, and are outdated

Page 5

Recap: Updated Sub-LAPs reflect local capacity areas

for RA, and notable congestion within some areas

• Existing boundaries were based on Reliability Must-Run

(RMR) study areas, discussion with transmission planners,

and preliminary “LMP Study” results.

• Now, ISO relies less on RMR, and has resource adequacy

(RA) requirements including local capacity areas (LCA).– Reference: http://www.caiso.com/planning/Pages/ReliabilityRequirements

• Basing Sub-LAP boundaries on RA local areas will allow

demand response to qualify as local RA resources.

– Operations engineering concerns also lead to reflecting some RA

sub-areas in defining some Sub-LAPs.

• Several Sub-LAP boundaries shift slightly to reflect RA

areas, and some can be merged.

Page 6

http://www.caiso.com/planning/Pages/ReliabilityRequirements

Most Sub-LAPs retain same name. Name changes

indicate splitting or merging areas.

Current Sub-LAP New Sub-LAP Current Sub-LAP New Sub-LAP

SLAP_PGCC SLAP_PGCC SLAP_SCEC SLAP_SCEC

SLAP_PGEB SLAP_PGEB SLAP_SCEN SLAP_SCEN

SLAP_PGF1 SLAP_PGF1 SLAP_SCEW SLAP_SCEW

SLAP_PGFG SLAP_PGFG SLAP_SCHD SLAP_SCHD

SLAP_PGHB SLAP_PGHB SLAP_SCLD SLAP_SCLD

SLAP_PGLP SLAP_PGZP SLAP_SCNW SLAP_SCNW

SLAP_PGKN (New LCA) SLAP_SDG1 SLAP_SDG1

SLAP_PGNB SLAP_PGNB Not defined SLAP_VEA

SLAP_PGNC SLAP_PGNC

SLAP_PGNV SLAP_PGNP

SLAP_PGP2 SLAP_PGP2

SLAP_PGSA SLAP_PGSI

SLAP_PGSB SLAP_PGSB

SLAP_PGSF SLAP_PGSF

SLAP_PGSI SLAP_PGSI

SLAP_PGSN SLAP_PGNP

SLAP_PGST SLAP_PGST

Page 7

Updated Sub-LAPs will apply to annual and monthly

CRRs issued for 2017

• Process requirements have made it necessary to run

annual CRR process with 2016 network model, then

updates take effect 1/1/2017

• ISO’s CRR staff has discussed transition with CRR

market participants and published updated Sub-LAP

detail on CRR portal

• Analysis has not shown adverse impacts on CRR

simultaneous feasibility test

Page 8

June 2015 Supply DR Integration Working Group

compliance report identified Sub-LAP updates as priority

Page 9

• PDR & RDRR locations will need to reflect new Sub-LAP

areas effective 1/1/2017– Locations can be effective-dated to reflect updated Sub-LAPs

• Registrations may be impacted due to changed attribute of

underlying locations– Registrations can be effective-dated to reflect updated Sub-LAPs

• Pre-defined Resources will be available for revised Sub-

LAPs effective 1/1/2017– Available on request

• Transition detail reviewed in 9/1/2016 conference call, and

in Customer Partnership Group meetings in October

Six (6) confirmed Registrations have been identified as being

impacted beginning 2017

Demand Response Registration System (DRRS) model

enhancements facilitate Resource ID implementation

10

• ISO has published updated Sub-LAP mapping at

http://www.caiso.com/participate/Pages/Load (“Load

participation and demand response”)

• Resource will be created on demand in the Masterfile

when requested through the GRDT process

– Market simulation and production activation dates for DRRS

phase 2 allow 4-week market simulation (9/19 – 10/14/2016),

followed by 1-week buffer before 10/24/2016 activation.

• In future years, ISO will continue to update Sub-LAPs

– Any changes to local capacity areas from Resource Adequacy

process are identified about May 1.

– Other ISO business processes will track RA changes.

http://www.caiso.com/participate/Pages/Load

Market Performance and Quality Update

Amber Motley

Manager, Short Term Forecasting

Guillermo Bautista Alderete, Ph.D.

Manager, Market Validation and Quality Analysis

Slide 11

Page 12

Price convergence improved in July and August.

Page 13

Price convergence at Malin

Page 14

Price convergence at Palo Verde

Page 15

RT prices lower than DA prices for both NP 15 and SP 15 in

August.

Page 16

Insufficient upward ramping capacity in ISO decreased

since June.

Page 17

Insufficient downward ramping capacity remained low in

2016.

Page 18

Congestion revenue rights market revenue inadequacy

without including auction revenues.

Page 19

Congestion revenue rights market revenue sufficiency

including auction revenues.

Page 20

Exceptional dispatch volume in the ISO area continued at low

levels.

Page 21

Daily exceptional dispatches by reason

Page 22

Real-time Bid cost recovery

Page 23

Bid cost recovery (BCR) by Local Capacity Requirement area

Page 24

Minimum online commitment (MOC)

Page 25

Pmax of MOC Cleared Units

Page 26

Binding minimum online commitments in July and August

MOC NameNumber (frequency) of binding hours in

July and August

Humboldt 7110 1403

HNTBH 7820 571

MOC PEASE 227

SCIT MOC 84

Orange County 7630 16

MOC COLGATE 2

Page 27

IFM under-scheduling of solar generation increased in July

Page 28

IFM under-scheduling of wind generation rose in July and

August

Page 29

Renewable (VERS) schedules including net virtual supply

and aligns with VER forecast in July and August

http://www.caiso.com/Pages/documentsbygroup.aspx?GroupID=EFF75C

2E-F28E-4087-B88B-8DFFAED828F8

http://www.caiso.com/Pages/documentsbygroup.aspx?GroupID=EFF75C2E-F28E-4087-B88B-8DFFAED828F8

Page 30

RTD renewable (VERS) curtailment fell since March

Page 31

Hourly distribution of maximum RTD renewable (VERS)

curtailment in August

Page 32

Wind, solar and hydro production

Monthly wind (VERS) downward flexibility in FMM

Page 33

Monthly solar (VERS) downward flexibility in FMM

Page 34

Monthly solar (VERS) downward flexibility in FMM from

11 AM to 5 PM

Page 35

Page 36

ISO area RTCO and RTIEO remains at relatively low levels in

July and August.

2015 2016 (YTD)

RTCO $55,393,053 $38,380,554

RTIEO $14,278,500 $6,524,835

Total Offset $69,671,553 $44,905,389

Page 37

Price correction events down continued at low levels

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EIM Price trends

Page 38

15-minute PACW Aggregate Price 15-minute PACE Aggregate Price

5-minute PACW Aggregate Price 5-minute PACE Aggregate Price

Nevada prices since December

Page 39

Net Transfers by area

Page 41

EIM BCR in July and August

Page 42

EIM Exceptional Dispatch in July and August

Day-ahead load forecast

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How will the August 21,2017 affect California BA?

Slide 49

N. San Joaquin

Mojave

LA Basin

Coachella and Imperial

Valley

Colorado

River

S. San Joaquin

Las Vegas

100% Eclipse @10:19 a.m. 100% Eclipse @10:30 a.m.

What will be the potential MW impact on CAISO?

Slide 50

Start of eclipse: 9:02

Total production drop: 5050 MWs @10:22

Up ramp estimated @ 56MWs/min

End of Eclipse: 11:56

The effects of rooftop solar and solar in EIM regions.

Slide 51

EIM Entity

Distribution

MWs

Commercial

MWs

Arizona 187 956

Nevada 75 374

PacifiCorp 871

PSE 0.5

Total 262 2201.5

1204

19671768

2525

488

885

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lled M

Ws

Behind The Meter Growth

SCE PGE SDGE

Growth Projection from CEC

Lesson learned from Europe.• Transmission System Operators

– Higher reserves

– Committed to zero Area Control Error

– Strategic use of pump storage

– Limited generation planned outages

– Reduced high voltage direct current line capacities between the Nordic,

United Kingdom and Continental Europe.

– Activated emergency telecommunications, with back up

– Specialized training for operators.

– Raised awareness with market players and distribution system

operators.

• Germany

– Procured 2 times normal regulations

– Germany established special operational concepts for reserves

• Italy– Reduce northern net transfer capability

– Reduced day ahead PV production from 7 a.m. to 2 p.m. Slide 52

Potential mitigations to be studied:

Slide 53

• Scheduling Coordinator engagement

• Reserve procurement

• Gas supply coordination

• Flexi-Ramp usage

• Special Operating Procedures

• EIM transfer capability

• WECC/Peak RC coordination

• Hydro reserves

What is the Mitigation Measure timeline?

• A preliminary timeline has been developed to allow

sufficient time to address any issues arising from the

eclipse:

– September – December 2016

• Announce eclipse study at Market Performance

and Planning Forum Sept 20.

• Request MP input.

– January – March 2017

• Develop Solar Eclipse Mitigation Procedure.

• Circulate with SCs for comment.

• Publish Procedure.

Slide 54

Load Forecast Adjustments

Kyle Westendorf

Associate Market Monitoring Analyst,

Department of Market Monitoring

Page 55

Frequency of positive and negative load adjustments

by BAA (5-minute market)

Page 56


Average absolute size of load adjustments as a

percent of total area load (April – June)

Page 57


Frequency of load forecast adjustment by reason

(5-minute market)

Page 58


Sample #1 – Wind deviation from forecast in

PacifiCorp East (April 13, 2016)

Page 59


Sample #2 – Load deviation from forecast in

PacifiCorp East (July 8, 2016)

Page 60


Mitigation of power balance relaxation by load bias

limiter (5-minute market)

Page 61


Policy Update

Brad Cooper

Manager, Market Design and Regulatory Policy

Page 62

Ongoing policy stakeholder initiatives

• Contingency modeling enhancements

– On hold

• Generator contingency and remedial action scheme

modeling

– Straw proposal targeted late Sept

– 2017 Q1 Board meeting, projected Fall 2018

implementation

• Stepped transmission constraints

– Conducting analysis, straw proposal targeted for Q4

– 2017 Q2 Board meeting, projected Fall 2018

implementation

Page 63

Ongoing policy stakeholder initiatives (continued)

• Reliability services – phase 2

– Revised draft final proposal - Sept 16

– Stakeholder call - Sept 23

– Oct 2016 Board

• Flexible resource adequacy criteria and must-offer

obligation – phase 2

– Schedule TBD based on findings of flexible capacity

assessment

– Board TBD

• Bid cost recovery enhancements

– Revised straw proposal targeted for Sept

– 2017 Q1 Board meeting

– Projected Fall 2018 implementation

Page 64

• Commitment Cost and DEB Enhancements

– Issue paper - Sept 20

– Stakeholder call - Sept 27

– Q3 2017 Board

– Potential Fall 2017 partial implementation

• Metering rules enhancements

– Stakeholder comments on second supplement to draft

final proposal due - Sept 19

– Board TBD

• Energy storage and distributed energy resources (ESDER)

Phase 2

– Multi-topic initiative with policy development in progress

on all topics.

– Board TBDPage 65



• Aliso Canyon - Phase 2

– Straw proposal summary - Sept 6

– Draft final proposal - Sept 21

– Oct 3 BOG

• Self schedules BCR allocation and bid floor

– Draft final proposal addendum - Sept 16

– Oct 2016 BOG

• Stakeholder initiatives catalog

– Draft initiatives catalog - Sept 15

– Final policy initiatives roadmap - Nov 30

– Feb 2017 EIM Governing Body and Board

Page 66


• Regional integration California greenhouse gas compliance

– Straw proposal - Oct 6

– Feb 2017 Board

• Transmission access charge options

– 2nd revised straw proposal - Sept 28

– Stakeholder meeting - Oct 7

– Board TBD

• Regional resource adequacy

– Revised straw proposal - Sept 29

– Stakeholder meeting - Oct 6

– Draft final proposal and stakeholder meeting Dec 2016

– Board TBD

Page 67

• ISO tariff load serving entity

– Draft final proposal Sept 14

– Oct 2016 Board

Page 68


Policy stakeholder initiatives coming soon

• Planned to start in Q4

– Frequency response – phase 2

Page 69

Release Plan Update

Adrian Chiosea

Manager, Strategic Initiative Management

Page 70

Release Plan 2016

Page 71

Independent 2016

• Demand Response Registration Enhancements

• Capacity Procurement Mechanism Replacement

• Reliability Services Initiative

• Commitment Cost Enhancements Phase 2 (remainder)

• RIMS Functional Enhancements

• ADS Client Replacement (Mandatory)

Fall 2016

• Energy Imbalance Market (EIM) 2016 Arizona Public Service (APS)

• Energy Imbalance Market (EIM) 2016 Puget Sound Energy (PSE)

• OMAR Replacement

• BAL-003 Compliance

• Flexible Ramping Product

• BCR modifications and VER settlement

• Acceptable Use Policy - CMRI

• PIRP System Decommissioning

• Energy Imbalance Market (EIM) Year 1 Enhancements Phase 2

• Energy Storage and Distributed Energy Resources (ESDER)

Release Plan 2017

Page 72

Independent 2017

• RTD Local Market Power Mitigation (LMPM) Enhancements

• CRR Clawback Modifications

Fall 2017 (tentative, to be confirmed)

• Bidding Rules Enhancements – Part B

• Reliability Services Initiative Phase 1B

• Reliability Services Initiative Part 2 – partial implementation (policy to define)

• Commitment Cost Enhancement Phase 3

• EIM 2017 Portland General Electric (PGE)

• ADS User Interface Replacement

• Metering Rules Enhancements

Release Plan – 2018 and subject to further planning

Page 73

Spring 2018

• EIM 2018 Idaho Power Company

Fall 2018 – tentative, subject to impact assessment

• Reliability Services Initiative Part 2 – reminder

• Stepped Transmission Constraints

• Bid Cost Recovery Enhancements

• Generation Contingency and Remedial Action Scheme

• Flexible Resource Adequacy Criteria and Must-offer Obligation Phase 2

• ESDER Phase 2

• Regional Resource Adequacy

• Transmission Access Charge Options

Subject to further release planning:

• Reactive Power Requirements and Financial Compensation – no system changes are

anticipated

• Additional Data Transparency Enhancements (OASIS API changes) – work starting after Fall

2016 release; ISO will make it available for market participants to adopt as they need.

• Contingency Modeling Enhancements

Release Schedule 2016 - 2017

Page 74

http://www.caiso.com/Documents/ReleaseSchedule.pdf

Please do not delete slide.

http://www.caiso.com/Documents/ReleaseSchedule.pdf

2016 – Demand Response Registration Enhancements

Project Info Details/Date

Application Software Changes

Enhance Demand Response Registration functionality and processes

Develop new registration user interface for DRRS

Develop new APIs for support of enhanced registration processes

BPM Changes Metering

Business Process Changes Automation of internal registration-related processes

Page 75

Milestone Type Milestone Name Dates Status

Board Approval Board Approval N/A

BPMs Publish Final Business Practice Manuals (Metering) Aug 29, 2016

Post Draft BPM changes (Metering) Aug 04, 2016

External BRSExternal BRS - Enabling Demand Response Phase 2 -

RegistrationJun 04, 2015

Tariff Tariff N/A

Config Guides Config Guide N/A

Tech Spec Tech Specs - DRRS Phase 2 - Registration Sep 17, 2015

Market Sim Market Sim Window Sep 19, 2016 - Oct 14, 2016

Production Activation Post-Mrkt Consol - DRRS Phase 2 - Reg Oct 24, 2016

2016 – Capacity Procurement Mechanism Replacement

(CPM)Project Info Details/Date


Competitive Solicitation Process (CSP):

CSP replaces the existing administrative price process for annual, monthly and intra-monthly CPM

events for flexible and generic RA capacity. CSP will cover all events that allow the ISO to procure

additional capacity.

CIRA:

− Bid Submittal system for SCs to submit capacity bids (not an existing bid type)

− Capacity bids to implement new validation rules (not an existing bid type)

− Capacity Bid submittal to be on a yearly, monthly, and intra-monthly level

− LSE/LRA deficiency calculation to be performed for CSP for Generic and Flexible RA data

− Existing CPM calculation to be deprecated for trade dates after the effective date of

implementation.

− Manage import allocation and bilateral trades of import allocation

Settlements:

Settlements will need new CPM formulas that will result in charge code impacts.

Reporting:

If an annual or monthly CPM occurs greater than two times (over a rolling 24 month period) or more

than 50% of the LSE’s RA requirement is CPMed, a report must be given to Market Participants.

OASIS:

− Publish all finalized offers into the competitive solicitation process on a rolling five-quarter delay.

(Deferred)

Business Process Changes

− Solicitation for soft offer cap. Timeline for submittal needs to be defined.

− Submittal process for annual/monthly CPM bid submittal

− New business process for amount of capacity being relied on (non-RA from partial RA)

− New process for Competitive Solicitation Process (annual/month/intra-monthly)

Page 76

Milestone Details/Date Status

BPM Changes

Reliability Requirements – PRR issued 11/4/15

Market Instruments – issue PRR 1/8/16 -

Billing & Settlements – PRR issued 1/11/16


− Solicitation for soft offer cap. Timeline for submittal needs to be defined.

− Submittal process for annual/monthly CPM bid submittal

− New business process for amount of capacity being relied on (non-RA from partial RA)

− New process for Competitive Solicitation Process (annual/month/intra-monthly)

Board Approval February 5, 2015

External BRS March 31, 2015

Tariff Filed: May 26, 2015 FERC Approved: October 1, 2015

Technical SpecificationsCIRA Session 1 Fall 2016, MPs will use UIs

OASIS Session 2 Fall 2016

Draft Configuration Guides November 23, 2015 Session 2

External Training

October 21, 2015: Session 1 – Onsite w/Webinar, Full Day (combined w/ CPG Call)

• Training Materials – posted SP & RP page on 10/19

January 6, 2016: Session 2 - Onsite w/ Webinar option, Full Day

• Training Materials – post 1/5

Page 77


(cont.)


Market

Simulation

April 11– May 6, 2016: Session 2

• 4/11-4/15: Unstructured

• 4/18-4/22: Structured Week 1& 2

• 4/25-4/29: Structured Week 3 - On-Site 4/26-4/29


• 7/18-7/22: Re-run Structured Week 1 & 2

• 7/25-7/29: Re-run Structured Week 3 (Monthly)

• 8/22-8/26: Re-run Structured Week 3 (Intra-Monthly Scenarios 7B an 8B) Post Structured Scenarios

• SIBR Rules, Release Notes, Specs posted – 12/11

• CIRA User Guide – 1/18

• 9/12-9/16: Re-run Structured Week 3 for 2 Entities

Production

Activation11/1/2016: Session 2 Effective Date - FERC Approved

Page 78


(cont.)



CIRA:

− Manage new NQC/EFC process request for resource types. This will impact both internal users

and Market Participants

− Manage Import Allocation (CPM Replacement initiative is covering this scope but is needed for

this initiative)

− Manage RA obligation (taking into consideration substitution capacity and replacement capacity

as RA capacity) will impact RA, Settlements, market, and outage. The output of CSP will be

needed

− Publish RA Obligations externally

− Display Comparative snapshot of DA/RT obligation (outages, energy bids, RA

obligation). Display input of RAAIM calculations

− Display SCP and CPM availability calculation output for historic trade dates

− Creation of substitution rules for flexible resource adequacy resources

− Modify existing DA/RT generic substitution rules

− DA substitution timeframe shall change from 6 AM to 8 AM

− Enable the release of substitute capacity for generic and flexible resources

− Allow imports to substitute for other imports and CAISO system resources. The RA obligation

will be at a daily level

− Use result of Pre-qualification analysis (the pre-qualification analysis is a manual process) for

real time substitution validation

− API for substitution and release functionality

− Enable Generic CPM substitutions

− Enable Flexible CPM substitutions

− Build Submit & Retrieve APIs to support Substitutions (4 types) and release of sub capacity

− Substitution will now be in CIRA

− Addition of RAAIM exempt and planned outage exemption flag

− Allow the outage correction process to exempt outage from RAAIM calculations up to 5 business

days

OMS:

− Add 5 nature of work attributes and various validations

− Remove SCP Exempt flag from display

Page 79

2016 – Reliability Services Initiative (RSI) – 1A

Project Info Details/Date Status


MasterFile:

− Will store Use Limit Plan. There will be a new template (ULPDT – Use Limit Plan

Data Template)

RAAM:

− Decommission RAAM

Settlements:

- RAAIM (RA Availability Incentive Mechanism) NEW – replaces SCP for backstop.

Current SCP will retire with implementation of RAAIM. Will assess whether generic

and flexible RA resources comply with MOO and better captures use limited resource

availability.

- New charge code changes are needed for implementation of the RA

Reporting:

- Report on the effectiveness of the RAAIM results (1 year after implementation)

(Deferred)

Other:

- Modification of Use Plan with new validation rules

- LSE cost allocation methodology needs to automated.

- Publish list of all available prequalification combinations

Page 80

2016 – Reliability Services Initiative (cont.) -1A


BPM Changes

Reliability Requirements - issued PRR #888 on 1/12/16

Outage Management - issued PRR #889 on 1/12/16

Billing & Settlements - issued PRR on 1/11/16

Business Process

Changes

− Process to assign NQC values to NGR/PDR/DG resources

− Process for PDR/NGR/DG testing

− Process for RA Availability Incentive Mechanism (RAAIM). Must retire SCP business process flows.

− Modify DA/Real Time Substitution Process

− Process for allocating year end unallocated RA Availability Incentive Mechanism (RAAIM) funds

Board Approval March 26, 2015

External BRS March 31, 2015

Tariff Filed: May 28, 2015 FERC Approved: October 1, 2015

Technical Specifications

CIRA Session 2 Fall 2016, MPs will use UIs

MasterFile Session 2

• posted tech spec 9/24 on Release Planning Page

• posted ULDT 9/11 to RP page

• posted ULR documentation/ sample templates to RP page on 12/4

OMS Session 2

• posted tech spec 12/2

Draft Configuration

GuidesNovember 23, 2015 Session 2

Page 81

2016 – Reliability Services Initiative (cont.) – 1A


External TrainingJanuary 6, 2016: Session 2 – Onsite w/ optional Webinar, Full Day


Market Simulation

April 11– May 6, 2016: Session 2


• 4/18-4/22: Structured Week 1& 2

• 4/25-4/29: Structured Week 3 - On-Site 4/26-4/29


• 7/18-7/22: Re-run Structured Week 1 & 2

• 7/25-7/29: Re-run Structured Week 3

• 8/22-8/26: Re-run Structured Week 3 (Intra-Monthly Scenarios 7B an 8B)

• 8/22- 9/23: MOO Flag API in MAP Stage for Unstructured Testing

• Post Structured Scenarios

• SIBR Rules, Release Notes, Specs posted – 12/11/15

• CIRA User Guide – 1/18/16

• MF UI User Guide – 1/6/16

• OMS User Guide – embedded in application

• CIRA User Guide – 1/18/16

• 9/12-9/16: Re-run Structured Week 3 for 2 Entities

Production Activation 11/1/2016: Session 2 Effective Date - FERC Approved

Page 82

2016 – Reliability Services Initiative (cont.) – 1A

2016 – Commitment Costs Phase 2Project Info Details/Date


For the Early Jan 2016 release, the project will

• Clarify definition, qualifications, and requirements for use-limited resources

• Implementation of the use limited definition (No longer applicable)

• Implement revised must-offer rules

• Impacted Systems:

• MF

• SIBRCCE2 Early 2016 release implementation will be coordinated as part of the Reliability Services

Initiative (RSI) project

Page 83

Milestone Type Milestone Name Status

Board Approval Yes. March 26-27, 2015

TariffFiled: May 28, 2015 Approved in Part: September 9, 2015(FERC rejected the proposed revisions to the definition of “use limited resources”, but

approved all other tariff revisions.)

BPM Changes Market Operations (Use Plan) – issued PRR #887 on 1/11/16

Business Process Changes No

External Business Requirements November 24, 2015

Technical Specifications No

External TrainingJanuary 6, 2016: Session 2 – Onsite w/ optional Webinar, Full Day


Draft Configuration Guides No

Market Simulation February 8th, 2016 – July 29th, 2016 (Unstructured)

8/22-8/26:: Re-run Structured Week 3 (Intra-Monthly Scenarios 7B an 8B)

Production Activation 11/1/2016: Session 2 Effective Date - FERC Approved

2016 – RIMS Functional Enhancements


Application Software ChangesFunctional enhancements resulting from the Customer Partnership Group CPG.

More details to be provided in the future.

BPM Changes

Generator Interconnection and Deliverability Allocation Procedures

Generator Interconnection Procedures

Managing Full Network Model

Metering

Generator Management

Transmission Planning Process

Customer Partnership Group 10/16/15

Application and Study Webinar 3/31/16

Page 84


Board Approval Board approval not required N/A

BPMs Generator Interconnection and Delivery Allocation Apr 29, 2016

External BRS External BRS not Required N/A

Tariff No Tariff Required N/A

Tech Spec No Tech Specifications Required N/A

Production Activation RIMS5 App & Study Mar 21, 2016

RIMS5 Queue Management, Transmission and Generation Oct 31, 2016

Page 85

ADS Client Update - Mandatory


Application Software ChangesADS client software is being impacted by an underlying mandatory infrastructure

software upgrade, necessitating adoption of a newer version of the ADS client.

The ISO will provide an updated ADS client version 6.0.x, that is required for an

infrastructure upgrade planned before year-end.

Market participants must adopt this new client before the ISO executes an

internal infrastructure upgrade in Q4 2016.

Participants will be given a two-month window to install the new client prior to the

decommissioning of all client versions less than 6.0.x (5.2.8.0; 5.2.4.0, etc.).

Without the newer version, market participants will not be able to connect to the

ADS system.

There are no functional changes in client version 6.0.x.

Page 86

Fall 2016 GRDT Changes

The following changes will be made to the Master File Generator RDT:

Resource WorksheetRemove Green House Gas Cost (EIMY1P2)

Add O&M Adder Type (non-modifiable; ECIC)

Remove MOO Flag (RSI)

Remove Stranded Load (not applicable to Gens/TGs)

Configuration WorksheetStartup Heat Input

Transition WorksheetRemove Max Transition Cost

Remove Transition Fuel

Remove Transition Energy

Add Transition Midpoint MW (modifiable; new for EIMY1P2)

Add Transition Midpoint Time (modifiable; new for EIMY1P2)

* Note: GRDT v9.0 will no longer be supported.

Fall 2016 CMRI/OASIS/ADS High-Level Summary API changes

Page 87

Project CMRI OASIS ADS

BCR/VER

Update (add FCU Forecast marketServiceType):

ExpectedEnergyAllocationDetails v3

Decom:

ExpectedEnergyAllocationDetails v1

N/A N/A

Forecasting (PIRP Decom)

Data Transparency

New: EIRForecast v1

New: ElectricityPriceIndex v1

N/A N/A

EIM Year 1 Phase 2- GreenHouseGasCapData v1

-EIMInterchangeScheduleData

v1

-PRC_RTM_SCH_CNSTR

(Scheduling Constraint Shadow

Prices)

-ENE_HRLY_BASE_NSI (EIM BAA

Hourly Base NSI)

- ENE_HRLY_BASE_LOSS (EIM

BAA Hourly Base Loss)

- ENE_EIM_TRANSFER_TIE (EIM

Transfer by Tie)

Add Energy,Loss,GHG components:

- PRC_SPTIE_LMP

- PRC_CD_SPTIE_LMP

- DAM_SPTIE_LMP_GRP

- RTPD_SPTIE_LMP_GRP

- RTD_SPTIE_LMP_GRP

Add 'GHG' product:

- PUB_BID

N/A

• New Fall 2016 APIs available in MAP-Stage as of Phase 2 market simulation.

Fall 2016 CMRI/OASIS/ADS High-Level Summary API changes

(cont’d)

Page 88

Project CMRI OASIS ADS

Flex Ramp

New:

- ResourceMovementPoint v1

- ResourceLevelMovement v1

Update:

- MarketAwards v4

- SchedulePrices v4

- MarketSchedules v3

- EIMTestResults v2 minor

version v20161001

Decom:

- MarketAwards v2

- SchedulePrices v2

- MarketSchedules v1

New:

- SLD_ADV_FCST (Advisory CAISO Demand Forecast)

- ENE_UNCERTAINTY_MV (Uncertainty Movement by

Category)

- ENE_FLEX_RAMP_REQT (Flexible Ramp

Requirements)

- ENE_AGGR_FLEX_RAMP (Flex Ramp Aggr Awards)

- ENE_FLEX_RAMP_DC (Flex Ramp Surplus Demand

Curves)

- SLD_SF_EVAL_DMD_FCST (Sufficiency Evaluation

Demand Forecast)

Existing versions 6

& 7 remain PROD

versions

Independent and Fall 2016 Release Market Simulation

Page 89

Link to Fall 2016 Release Market Simulation Plan -

http://www.caiso.com/Documents/MarketSimulationPlan_Fall2016Release.pdf

Fall and Independent Release 2016 Initiative Start Date (Trade Date)

End Date (Trade Date

Structured Simulation Start (Trade Date)

Expected Participation

Fall 2016 Release Market Simulation Phase 1

Energy Imbalance Market – APS and PSE7/6/2016 7/29/2016 7/6/2016

Arizona Public Service and Puget Sound Energy

OMAR Replacement 7/7/2016 7/29/2016 EIM Entities and ISO MPs

RSI/CPM Structured Scenario Testing (Independent) 7/19/2016 9/16/2016 7/19/2016 ISO MPs

Fall 2016 Release Market Simulation Phase 2

RSI/CPM Unstructured Testing (Independent) 8/23/2016 9/23/2016 ISO MPs

DRRS Enhancements Phase 2 (Independent) 9/19/2016 10/14/2016 EIM Entities and ISO MPs

Energy Imbalance Market - One Year Enhancements Phase 2 8/23/2016 9/23/2016

Arizona Public Service, NV Energy, PacifiCorp and Puget Sound Energy

BCR/VER 8/23/2016 9/23/2016 EIM Entities and ISO MPs

Frequency Response (BAL-003) 8/23/2016 9/23/2016 ISO MPsCMRI AUP 8/23/2016 9/23/2016 EIM Entities and ISO MPs

ESDER 8/23/2016 9/23/2016 EIM Entities and ISO MPs

Flexible Ramping Product 8/23/2016 9/23/2016 8/31/2016 EIM Entities and ISO MPs

Forecasting and Data Transparency/PIRP Application Decommissioning 8/23/2016 9/23/2016

EIM Entities and ISO MPs

http://www.caiso.com/Documents/MarketSimulationPlan_Fall2016Release.pdf

Fall 2016 – EIM Arizona Public Service


Application Software Changes Implementation of Arizona Public Service as an EIM Entity.

BPM ChangesEIM BPM will be updated to reflect new modeling scenarios identified

during APS implementation and feedback from APS.

Market Simulation

ISO promoted market network model including APS area to non-

production system and allow APS exchange data in advance of Market

Simulation on 3/7/16.

Integration/Day in the Life Testing March 7 – May 30, 2016

Market Simulation July 5 – July 29, 2016

Parallel Operations August 1 – September 30, 2016

Page 90



BPMs BPMs N/A

External BRS External BRS N/A

Tariff APS files tariff revisions with FERC Feb 12, 2016


Tech Spec Tech Specs N/A

Market Sim Market Sim Window Jul 05, 2016 - Jul 29, 2016

Production Activation EIM - Arizona Public Service Oct 01, 2016

Fall 2016 – EIM Puget Sound Energy



Implementation of Puget Sound Energy as an EIM Entity.

WebOMS - Provide Balancing Authorities with the ability to submit outages to

WebOMS and the ability to submit PeakRC through their Coordinated Outage

Scheduling System (COS).

BPM Changes EIM BPM will be updated based on feedback from PSE.

Market Simulation

ISO promoted market network model including PSE area to non-production

system and allow PSE exchange data in advance of Market Simulation on

3/7/16.

Integration/Day in the Life Testing March 7 – May 30, 2016

Market Simulation July 5 – July 29, 2016


Page 91



BPMs BPMs N/A

External BRS OMS - BRS External Design Jul 24, 2015

Tariff Tariff filing at FERC Feb 12, 2016

Config Guides Settlements N/A


Market Sim Market Sim Window Jul 05, 2016 - Jul 29, 2016

Production Activation EIM - Puget Sound Energy Oct 01, 2016

Fall 2016 – OMAR Replacement



The scope of the project is to replace the current OMAR Online application with a new

CUI framework based interface and provide standard B2B web services integration. B2B

services will be modified to align with CIM standard and to convert to GMT, and the

existing FTP solution will be replaced. The new solution will also remove the custom

OMAR certificates by leveraging the CAISO Multiple Application (CMA) certificates.

BPM Changes Metering and Definitions & Acronyms (references to systems may need to change)

Business Process ChangesPotential Level-II business process changes under –

• Manage Market & Reliability Data & Modeling

• Manage Operations Support & Settlements

Page 92



BPMs Business Practice Manuals Aug 10, 2016

External BRS Publish External BRS Oct 02, 2015

Tariff Tariff N/A

Config Guides Configuration Guide N/A

Tech Spec Publish Tech Specs Dec 21, 2015

Market Sim Market Sim Window Jul 07, 2016 - Sep 23, 2016

Production Activation Post-Mrkt Consol - OMAR Replacement Oct 01, 2016

OMAR Online Replacement Simulation

Page 93

The OMAR Online Replacement Market Simulation timeline:

• July 7, 2016 - September 23, 2016 Unstructured

• MRI-S for metering API - available July 7, 2016

• MRI-S for metering GUI - available August 11, 2016

No historical data will be migrated in MAP Stage, all data must be uploaded to

be retrieved.

• OMAR Online Replacement initiative Tech Spec –

http://www.caiso.com/Documents/OMAROnlineReplacementTechnicalSpeci

ficationClean_v16.pdf

http://www.caiso.com/Documents/OMAROnlineReplacementTechnicalSpecificationClean_v16.pdf

ACL Groups for OMAR (MRI-S) and PIRP (CMRI)

Replacement

Page 94

ACL (Access Control List) functionality – ACLs define a subset of

resources belonging to an SCID

• Ability to use ACL groups for the read-only role for both the Metering

Replacement (MRI-S) and PIRP (CMRI) is currently unavailable

o Work around is to continue to use existing OMAR and PIRP applications

for read only roles filtered at the resource level

• SCID-level read-only access for Metering Replacement (MRI-S) is also

currently not available

o Work around is to continue to use existing OMAR application for read

only access

• Target is to have this functionality available in the Fall Release

• Adequate time for testing the new read only roles in the Map-Stage

environment will be made available, including post 10/1

OMAR Use Cases

Page 95

ISO Polled Meter data

• MRI-S supports ability to submit and view meter data for users with SCID-level access

• MRI-S does NOT support ability to view (read-only) meter data for user with ACL-level access

• If ACL-level access is required for ISO polled meter data, continue to use OMAR until this functionality is available in MRI-S

SC Submitted Meter data

• MRI-S supports ability to submit (read-write) meter data for users with SCID-level access

• MRI-S does NOT support ability to view (read-only) for SCID and ACL-level access

• Meter data submitted via MRI-S WILL NOT BE VIEWABLE USING THE EXISTING OMAR APPLICATION

• If ACL-level or SCID-level read-only access is required for SC submitted meter data, continue to use OMAR until this is available in MRI-S

PIRP Use Cases

Page 96

• CMRI supports ability to view data for users with SCID-level access

• CMRI does NOT support ability to view data for ACL-level access

• Work around is to continue to use PIRP until the ACL CMRI role is available

Page 97



• To procure transferred frequency response from external BAs through a

competitive solicitation process

• Allocate the cost of TFR to metered demand: new charge code

• Require generators to manage their plants consistent with NERC published

reliability guidelines for primary frequency control

• Require generators to provide governor control and plant level control

system data to the ISO, including Droop Setting, Deadband, frequency

responsive maximum output level, Plant-level distributed control

systems(DCS) with frequency bias term (Y/N), level temperature loop

controls(@what output and/or temperature; Y/N)

• Increase market transparency of the ISO’s frequency response performance

through its Monthly Market Performances Reports

• Clarify the authority of ISO to designate any reserve as contingency only

reserve regardless of resource’s election

Fall 2016 – BAL-003 Compliance


Board Approval BOG Approval Mar 25, 2016

BPMs BPMs N/A

External BRS Post External BRS May 03, 2016

Tariff File Tariff Apr 21, 2016

Receive FERC order TBD

Config Guides Draft Configuration Guides Jun 10, 2016

Tech Spec Tech Spec N/A

Production Activation BAL- 003 Frequency Response Oct 01, 2016

Fall 2016 – Flexible Ramping ProductSystem Description

Real-Time Market

• FMM and RTD markets (no DA) will procure two new market products (each with award

and price), Flex Ramp Up (FRU) and Flex Ramp Down (FRD), based on upper and lower

uncertainty histogram FRP requirements and the Flex Ramping Capacity surplus

demand curves.

• FRP award-eligible resources are 5-minute dispatchable and have economic energy bids

in RTM.

• Forecasted Movement shall apply to all resources that have movement from binding to

the first advisory interval of a given RTPD or RTD market run.

• Uncertainty Movement for resources classified under the Supply Category shall only

apply to VER resources with DOT Instructions that meet (within tolerance) their VER

Forecast. This is a simplification such that uncertainty movement only applies to supply

resources with schedules based on a forecast. Intertie and Load category resources shall

still have uncertainty movement calculated. All uncertainty movement is in RTD only.

• No FRU/FRD bids or self-schedules allowed in RTM, rather FRP prices are set by the

opportunity cost based on the submitted economic energy bid.

• FRP awards are not reserved between markets and re-procured each new market run.

Market Optimization Constraint Additions/Changes:

• RTM enforces BAA-level and EIM Area FRU and FRD minimum requirements.

• FRP Surplus Cost Function procures Flexible Ramping Product uncertainty awards up to

the point where the LMP is less than the expected cost of not serving FRP

• FRU price cap ($247/MWh); FRD price cap (-$152/MWh)

• FRU/FRD awards prohibited for resources operating in Forbidden Region or undergoing

MSG Configuration Transition

• Resource Upper/Lower Operating Limits modified to consider FRP Awards;

• Resource Up/Down Ramping Capability Constraint modified to include FRU and FRD

awards, respectively

• ISL/ITC import/export constraints will include FRU/FRD in addition to AS awards.

Page 98

Fall 2016 – Flexible Ramping Product

System Description

MasterFile

• (existing field, read only) MasterFile shall define resource eligibility for FRU and

FRD awards. Resource eligibility parameters are maintained by CAISO (no

additional certification required). Although FRP eligible, resources must also have a

RTM energy economic bids to receive FRP awards.

EIM

• BSAP UI will provide uncertainty requirement and ramping capacity surplus demand

curve information

• Existing EIM Flexible Ramping Sufficiency Test will now also perform for downward

flexible ramp capability over the next trading hour on a BAA-basis

• Introduction of new BAA upward/downward Capacity Constraints, regarding

Available Balancing Capacity (ABC)

• Flexible Ramp Up (FRU) and Down (FRD) will be procured in RTUC

• Net Demand Movement shall no longer be considered in the EIM Ramping

Sufficiency Test (instead, Net Forecast Movement will be used)

• BAAs shall only pass sufficiency tests (both upward and downward) if all intervals of

trade hour have sufficient ramping capability in the respective direction.

• As transfers may be retracted, partial fulfillment of FRU and FRD is provided for

BAAs with net EIM transfers in the direction relevant to the FRP type

ADS

[6/7 Update]: Due to prohibitive cost and resource allocation constraints, CAISO shall

implement FRP-related functional improvements during the ADS Replacement release

in Fall 2017.

Therefore for Fall 2016 Release:

• ADS UI features and APIs shall revert back to their current Production features and

technical specifications, respectively.

• No deprecation of existing ADS API versions shall be scheduled for Fall 2016

Release

Page 99


System Description

CMRI The following shall be provided by CMRI reports and APIs (movement amounts publish

T+1):

Movement Calculation Points (FMM and RTD binding and first advisory MW

schedules used for both forecasted movement and uncertainty movement

calculations)

Forecasted Movement by Resource (FMM and RTD)

Uncertainty Movement by Resource (RTD only)

FRU and FRD Uncertainty Awards by Resource (FMM and RTD)

FRU and FRD Price by Resource, including the following FRU and FRD price sub-

components (that sum to the total FRU and FRD prices):

BAA Constraint Shadow Price

EIM Area Constraint Shadow Price

EIM Balancing, Capacity, and Upward/Downward Flexible Ramping Sufficiency Test

results by BAA (provided whether pass or fail)

Note: Forecasted and Uncertainty Movements are calculated for MSG resources at the

plant level.

OASIS The following shall be provided by OASIS reports and APIs (movement amounts publish

T+1):

Demand Forecast by Forecast Zone (ex post) now includes first advisory interval

Hourly and 15-Minute Sufficiency Evaluation Demand Forecasts (ex ante)

Uncertainty Movement by Category Type (Supply, Intertie, Load) (RTD Only)

Histogram and Final Uncertainty Requirements by BAA and by EIM Area (FMM and

RTD)

Histogram Surplus Demand Curves by BAA and by EIM Area (FMM and RTD)

FRU and FRD Aggregate Awards by BAA and by EIM Area (FMM and RTD)

FRU and FRD Shadow Price by BAA Group constraint (FMM and RTD; by

individual BAA and by EIM Area)

Page 100


System Description

Settlements • Settlements shall receive and consume, if relevant, the FMM and RTD resource-

specific flex ramp product awards (FRU and FRD) due to uncertainty, FMM and RTD

forecasted movement, RTD uncertainty movement , and price information, including

total FRP Price (FRU and FRD) and relevant constraint contribution.

• Settlements shall also receive relevant category-specific (supply, intertie, and load)

RTD uncertainty movement for FRU and FRD and by relevant constraint contribution.

• Resource Forecasted Movement shall settle at the FMM FRP price (FRU and FRD),

then settle the RTD incremental movement amount at the RTD FRP price (FRU and

FRD). Rescission quantities settle at RTD FRP prices.

• Resource Uncertainty Movement shall settle on a daily basis with a monthly

resettlement

• Any FRP rescission shall first apply to the uncertainty award, and then forecasted

movement (if any remaining)

• Both Forecasted Movement and FRP Award allocations shall apply to BCR

• FRP rescission payments/charges shall not apply to BCR

Page 101


System Description

BPM changes Market instruments

Market Operations

Definitions & Acronyms

Settlements & Billing

Page 102


Board Approval Project Approved by Board of Governors Feb 03, 2016

BPMs Market Ops– As emergency PRR Sep 20, 2016

Market Instruments – PRR 936 Sep 06, 2016

Definitions and Acronyms – PRR 920 Jul 28, 2016

External BRS External Business Requirements Mar 14, 2016

Tariff File Tariff Jun 24, 2016

Config Guides Post Draft Config guides Jun 10, 2016

Tech Spec Publish CMRI Technical Specifications Apr 15, 2016

Publish OASIS Technical Specifications Apr 08, 2016

Publish ADS Technical Specifications Mar 30, 2016

Market Sim Market Sim Window Aug 16, 2016 - Sep 23, 2016

Production Activation Flexible Ramping Product Oct 01, 2016

Fall 2016 – BCR Modifications and VER Settlements


Application

Software

Changes: CMRI,

Settlements

CMRI: Shall publish the Expected Energy Allocation records with a new market service type

‘FCS’. Note: ‘FCS’ stands for ‘forecast’ and represents capacity above the forecast.

Proposed scope

Policy Topics:

• Ramp rate for variable energy resources.

• Residual imbalance energy settlement for economic bidding variable energy resources.

• Persistent deviation metric applied to variable energy resources.

• Default energy bids for economic bidding variable energy resources.

• Day-ahead metered energy adjustment factor.

• Tariff clarifications following market issues bulletin.

BPM Changes Settlements and Billing

Page 103


Board Approval Board Approval Jul 01, 2015

BPMs Publish Final Business Practice Manuals (Market Operations; System Operations; PRR 918) Sep 16, 2016

External BRS Post External BRS Dec 31, 2015

Tariff File Tariff May 25, 2016

Tariff Approved Jul 20, 2016

Config Guides Settlements Configuration Guide Apr 08, 2016

Tech Spec Publish Technical Specifications (CMRI) Apr 15, 2016


Production Activation BCR Modification and VER Settlement Oct 01, 2016

Fall 2016 – Acceptable Use Policy – CMRI



Scope includes enforcement of Acceptable Use Policy for CMRI

services to support the full implementation of 1 call per service per

identity (as designated by certificate) every 5 seconds. An error

code of 420 will be returned for any violation instance of the use

policy.

Page 104



BPMs BPMs N/A

External BRS External BRS N/A

Tariff Tariff N/A


Tech Spec Tech Spec N/A


Production Activation Acceptable Use Policy - CMRI Oct 01, 2016

Fall 2016 – PIRP Decommissioning


Application Software Changes:

PIRP/CMRI

• Forecast Data Reporting (resource-level) that was performed in

PIRP will be done in CMRI. Rolling Hour Ahead, Locked Hour Ahead,

and Rolling Day-Ahead forecasts.

• PIRP Decommissioning to occur TBD.

• CMRI to receive the Electricity Price Index for each resource and

publish it to the Market Participants.

BPM Changes CMRI Technical Specification; New APIs will be described.

Business Process Changes MPs will receive the VER reports from CMRI rather than PIRP.

Page 105



BPMs Publish Draft Business Practice Manuals (Market Instruments; PRR 936) Sep 06, 2016

External BRS External Business Requirements Jun 29, 2015

Tariff Tariff Filing Activities N/A

Config Guides Settlements Configuration N/A

Tech Spec Publish Technical Specifications (CMRI; Wind and Solar) Apr 15, 2016

Tech Spec Publish Technical Specifications (CMRI: PIRP Decommissioning) Feb 05, 2016

Market Sim PIRP Decommissioning, CMRI Reports, ForecastingAug 23, 2016 - Sep 23,

2016

Production Activation PIRP Decommissioning, CMRI Reports, Forecasting Oct 01, 2016

Fall 2016 – EIM Year 1 Enhancements Phase 2

Page 106

System Description

Master File

EIM transfer limit congestion treatment:

• Define ISL/ITC for multiple ETSR scheduling limits

• Define ISL/ITC for EIM BAA to support FMM

• Remove GHG bid CAP from MF, always use ECIC/RLC

IFM/RTM

EIM transfer limit congestion treatment

• EIM transfer congestion component by BAA share

• EIM transfer limit subject to LMPM

• Allow multiple ETSR limits in ISL/ITC constraint

• Enforce ISL for EIM BAA by intertie

Include Loss component in LMP for SP-Tie

BSAPEIM entity shall submit base schedule to reflect latest information from e-tags, not limited to

approved e-tags.

CMRI• Publish GHG bid Cap (CMRI)

• Publish after fact EIM interchange schedules

OASIS

• Publishing by type of constraints, include EIM Transfer Constraints, HVDC, and other constraints.

• Allow API for GHG bid at public bids

• Publish base NSI for EIM BAA along with Base schedule test results at T-75, T-55 and T-40

• Publish LMP with Loss component for SP-tie

Fall 2016 – EIM Year 1 Enhancements Phase 2 (cont.)


BPM Changes Energy Imbalance Market

Business Process Changes Manage market and grid, Manage operations support and Settlements

Page 107


Board Approval Board Approval occurred in year 1 phase 1 N/A

BPMs Post BPM Sep 20, 2016

Draft Report Section of EIM & MI BPM Aug 23, 2016

External BRS External Business Requirements Feb 16, 2016

Tariff File Tariff Apr 28, 2016

Receive FERC order Jun 30, 2016

Config Guides Post Draft Config guides N/A

Tech Spec Publish CMRI Technical Specifications Apr 12, 2016

Publish OASIS Technical Specifications Apr 08, 2016

Publish Master File Technical Specifications Apr 21, 2016


Production Activation EIM Year 1 – Phase 2 Oct 01, 2016

Fall 2016 - Energy Storage and Distributed Energy Resources (ESDER)


Scope and

Application

Changes

2015 scope:

1. NGR model enhancement:

a. Update documentation on NGR to ISO BPMs to capture material and clarifications

b. Clarify how the ISO uses state of charge in market optimization.

c. Allow initial state of charge as a submitted parameter in the day-ahead market. (SIBR)

d. Allow option to not provide energy limits or have ISO co-optimize an NGR based on state of charge (SIBR,

IFM/RTM)

2. PDR/RDRP enhancement:

a. Support alternative performance evaluation method: MGO

b. Support Baseline Type-II

3. Multiple use applications:

a. DERA provides services to distribution system and wholesale market

b. DERA provides services to end-use customers and wholesale market

Include provisions:

1. Daily SQMD for DERA; 2. Settle DERA deviation through UIE; 3. Not address potential double payment; 4. No limitation

DERA for distribution system; 5. treat PDR/RDRR as serve end-use and wholesale market.

Page 108


Board Approval Board Approval Feb 04, 2016

BPMs Post Draft BPM changes Aug 03, 2016

External BRS Post External BRS May 05, 2016

Tariff File Tariff Submission May 20, 2016

Tech Spec Create ISO Interface Spec (Tech spec) N/A

Post Release Notes (No API Changes) Jun 20, 2016


Production Activation Storage and Aggregated DER Oct 01, 2016

2017 - Real Time Dispatch Local Market Power Mitigation



• CMRI – Display mitigated bids from RTD process

• Oasis (Open Access Sametime Information System): Display

RTD reports for Market Clearing, the Pnode clearing, similar to

current RTPD reports

• RTM (Real Time Market)

• RTPD: Perform the LMPM run as an integral part of the

binding interval RTPD run

• RTD: Proposed mitigation in RTD run would work the same

way as the current RTPD run

BPM Changes

• Energy Imbalance Market (EIM): under the proposed RTD method,

bids are not necessarily mitigated for the whole hour

• RTD MPM will work the same way as the current RTPD MPM


• Manage Markets & Grid

• ATF – System Operations: Add MPM Application to Real Time and

annotate inputs and outputs

• ATF – System Operations, Real Time: Add MPM to diagram with

inputs and outputs

• Level II – Manage Real Time Operations – maintain balancing area

Page 109

2017 - Real Time Dispatch Local Market Power

Mitigation (cont.)

Page 110

ProjectCMRI OASIS ADS

RTD LMPM Update (add RTD results):

MPMResults v3

Update (add RTD results)-

- PRC_MPM_RTM_LMP

- PRC_MPM_RTM_NOMOGRAM

- PRC_MPM_RTM_NOMOGRAM_CMP

- PRC_MPM_RTM_FLOWGATE

- PRC_MPM_CNSTR_CMP

- PRC_MPM_RTM_REF_BUS

-ENE_MPM

N/A


Board Approval Board of Governors (BOG) approval Mar 24, 2016

BPMs Post Draft BPM changes (EIM) Oct 03, 2016

Post Draft BPM changes (RTD MPM) Oct 03, 2016

External BRS Post External BRS Apr 08, 2016

Tariff File Tariff Jun 21, 2016

Receive FERC order Dec 01, 2016

Config Guides Configuration Guide N/A

Tech Spec Publish Technical Specification - OASIS Apr 08, 2016

Publish Technical Specification - CMRI Apr 14, 2016

Market Sim Market Sim Window Nov 04, 2016 - Dec 20, 2016

Production Activation RTD - Local Market Power Mitigation Enhancement Jan 30, 2017

2017 – Congestion Revenue Rights (CRR) Clawback Modifications



MQS/CRR Clawback:

If import bid <= day-ahead price, then the import is not considered a

virtual award.

If export bid >= day-ahead price, then the export is not considered a

virtual award.

If an import/export bid/self-schedule in real-time market is less than

the day-ahead schedule, then the difference shall be still subject to

CRR clawback rule.

CRR clawback rule should include convergence bids cleared on

trading hubs and load aggregation points in the flow impact used to

determine if the 10% threshold is reached.

Inform Market Participants of CRR annual allocation/auction for 2017.

BPM Changes Market Operations Appendix F

Business Process Changes TBD

Page 111

Schedule of major milestones - TBD

Fall 2017 - Bidding Rules Enhancements – Part B

Page 112



Developments under consideration include:

• MasterFile:

• Provide ability to submit requests for new fuel regions (Policy Section 8.1.1.3)

• Include resource-specific start-up electricity costs in proxy costs based on wholesale

projected electricity price, unless resource verifies costs incurred are retail rates (RDT

change)

• Allow ability to submit a weighting when using a more than one fuel region.

• Automation of the Aliso Canyon process for creating NEW Fuel Regions

• OASIS:

• Publish fuel regions (public information)

Business Process Change

• Manage Transmission & Resource Implementation

• Manage Entity & Resource Maintenance Updates

• Manage Full Network Model Maintenance

• Manage Market Quality System (MQS)

BPMs Market Instruments, Market Operations, Reliability Requirements


Fall 2017 - Reliability Services Initiative Phase 1B



Developments under consideration include:

Scope:

• Default flexible qualifying capacity provisions for phase 2 consideration (we might need data

collection performed in order to support RSI Phase 2

• Redesign of Replacement Rule for System RA and Monthly RA Process

• RA Process and Outage Rules for implementation for 2017 RA year

• Scope not delivered in RSI Phase 1A (Grandfathered Contracts, RAAM Decommissioning –

SCP & CPM screens from RAAM to CIRA, Acquired Contracts, OASIS reporting, web

services related to APIs for CSP offers, APIs for Generic/Flex Substitutions, and Release of

Generic/Flex Subs – UI & API)

Impacted Systems:

• CIRA

• OASIS

• Integration (B2B)

• Settlements

• Decommission RAAM

Business Process Changes Manage Market & Reliability Data & Modeling

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Scope:

1. Clarify use-limited registration process and documentation to determine opportunity

costs

2. Each submission evaluated on a case-by-case basis to determine if the ISO can

calculate opportunity costs

• ISO calculated; Modeled limitation

• Market Participant calculated; Negotiated limitation

3. Enhanced definition of “use-limited” in response to FERC’s rejection of the proposed

definition in Cost Commitment Enhancements Phase 2

4. Change Nature of Work attributes (Outage cards)

1. Modify use-limited reached for RAAIM Treatment

2. Add new demand response nature of work attribute for RDRR and PDR

Impacted Systems:

1. CIRA

2. CMRI

3. IFM/RTN

4. SIBR

5. MasterFile

6. OASIS

7. OMS

8. Settlements

BPM ChangesMarket Instruments, Outage Management, Reliability Requirement, Market Operations,

Settlements & Billing

Business Process ChangesLevel II – Manage Reliability Requirements

Level II – Manage Day Ahead Market

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Fall 2017 - Commitment Cost Enhancements Phase 3


Fall 2017 – EIM Portland General Electric


Application Software Changes Implementation of Portland General Electric as an EIM Entity.

BPM ChangesEIM BPM will be updated to reflect new modeling scenarios identified

during PGE implementation and feedback from PGE.

Market Simulation

ISO promoted market network model including PGE area to non-

production system and allow PGE exchange data in advance of Market

Simulation.


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Board Approval board approval not required N/A

BPMs BPMs N/A

External BRS No external BRS N/A

Tariff Tariff filing at FERC N/A

Config Guides Settlements N/A


Technical Specification N/A

Market Simulation Market Sim Environment Window Jun 29, 2017 - Jul 31, 2017

Production Activation EIM - Portland General Electric Oct 01, 2017

TBD - Additional Data Transparency Enhancements (OASIS API

changes)

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Project OASIS

Data

Transparency

Atlas Reference:

1) Price Correction Messages (ATL_PRC_CORR_MSG)

2) Scheduling Point Definition (ATL_SP)

3) BAA and Tie Definition (ATL_BAA_TIE)

4) Scheduling Point and Tie Definition (ATL_SP_TIE)

5) Intertie Constraint and Scheduling Point Mapping (ATL_ITC_SP)

6) Intertie Scheduling Limit and Tie Mapping (ATL_ISL_TIE)

Energy

1) EIM Transfer Limits By Tie (ENE_EIM_TRANSFER_LIMITS_TIE)

2) Wind and Solar Summary (ENE_WIND_SOLAR_SUMMARY)

Prices

1) MPM Default Competitive Path Assessment List (PRC_MPM_DEFAULT_CMP)

2) Real-Time Load Aggregation Point Settlement Prices

• Independent changes,

won’t impact existing

services

• Will be made available in

Production and cutover

schedule is discretionary

Market Performance and Planning Forum

2016 Schedule

• November 17

Please submit questions or meeting topic suggestions

through CIDI; select the “Market Performance and Planning

Forum” category.

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