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design was implemented in MRTU, and are outdated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
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.
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
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
0
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Insta
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
Last updated: September 16, 2016
Average absolute size of load adjustments as a
percent of total area load (April – June)
Page 57
Last updated: September 16, 2016
Frequency of load forecast adjustment by reason
(5-minute market)
Page 58
Last updated: September 16, 2016
Sample #1 – Wind deviation from forecast in
PacifiCorp East (April 13, 2016)
Page 59
Last updated: September 16, 2016
Sample #2 – Load deviation from forecast in
PacifiCorp East (July 8, 2016)
Page 60
Last updated: September 16, 2016
Mitigation of power balance relaxation by load bias
limiter (5-minute market)
Page 61
Last updated: September 16, 2016
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
Ongoing policy stakeholder initiatives (continued)
Ongoing policy stakeholder initiatives (continued)
• 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
Ongoing policy stakeholder initiatives (continued)
• 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
Ongoing policy stakeholder initiatives (continued)
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.
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
Application Software Changes
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
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)
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
2016 – Capacity Procurement Mechanism Replacement
(cont.)
Milestone Details/Date Status
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
• 5/2-5/27: Unstructured
• 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
2016 – Capacity Procurement Mechanism Replacement
(cont.)
Project Info Details/Date
Application Software Changes
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
Application Software Changes
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
Milestone Details/Date Status
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
Milestone Details/Date Status
External TrainingJanuary 6, 2016: Session 2 – Onsite w/ optional Webinar, Full Day
• Training Materials – post 1/5
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
• 5/2-5/27: Unstructured
• 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
Application Software Changes
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
• Training Materials – post 1/5
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
Project Info Details/Date Status
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
Milestone Type Milestone Name Dates Status
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
Project Info Details/Date
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
Fall 2016 – EIM Arizona Public Service
Project Info Details/Date
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
Milestone Type Milestone Name Dates Status
Board Approval Board Approval N/A
BPMs BPMs N/A
External BRS External BRS N/A
Tariff APS files tariff revisions with FERC Feb 12, 2016
Config Guides Config Guide N/A
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
Project Info Details/Date
Application Software Changes
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
Parallel Operations August 1 – September 30, 2016
Page 91
Milestone Type Milestone Name Dates Status
Board Approval Board Approval N/A
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
Tech Spec Tech Specs 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
Project Info Details/Date
Application Software Changes
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
Milestone Type Milestone Name Dates Status
Board Approval Board Approval N/A
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
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
Project Info Details/Date
Application Software Changes
• 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
Milestone Type Milestone Name Dates Status
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
Fall 2016 – Flexible Ramping Product
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
Fall 2016 – Flexible Ramping Product
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
Fall 2016 – Flexible Ramping Product
System Description
BPM changes Market instruments
Market Operations
Definitions & Acronyms
Settlements & Billing
Page 102
Milestone Type Milestone Name Dates Status
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
Project Info Details/Date
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
Milestone Type Milestone Name Dates Status
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
Market Sim Market Sim Window Aug 23, 2016 - Sep 23, 2016
Production Activation BCR Modification and VER Settlement Oct 01, 2016
Fall 2016 – Acceptable Use Policy – CMRI
Project Info Details/Date
Application Software Changes
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
Milestone Type Milestone Name Dates Status
Board Approval Board Approval N/A
BPMs BPMs N/A
External BRS External BRS N/A
Tariff Tariff N/A
Config Guides Config Guide N/A
Tech Spec Tech Spec N/A
Market Sim Market Sim Window Aug 23, 2016 - Sep 23, 2016
Production Activation Acceptable Use Policy - CMRI Oct 01, 2016
Fall 2016 – PIRP Decommissioning
Project Info Details/Date
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
Milestone Type Milestone Name Dates Status
Board Approval Board Approval N/A
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.)
Project Info Details/Date
BPM Changes Energy Imbalance Market
Business Process Changes Manage market and grid, Manage operations support and Settlements
Page 107
Milestone Type Milestone Name Dates Status
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
Market Sim Market Sim Window Aug 23, 2016 - Sep 23, 2016
Production Activation EIM Year 1 – Phase 2 Oct 01, 2016
Fall 2016 - Energy Storage and Distributed Energy Resources (ESDER)
Project Info Details/Date Status
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
Milestone Type Milestone Name Dates Status
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
Market Sim Market Sim Window Aug 23, 2016 - Sep 23, 2016
Production Activation Storage and Aggregated DER Oct 01, 2016
2017 - Real Time Dispatch Local Market Power Mitigation
Project Info Details/Date
Application Software Changes
• 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
Business Process Changes
• 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
Milestone Type Milestone Name Dates Status
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
Project Info Details/Date
Application Software Changes
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
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Schedule of major milestones - TBD
Fall 2017 - Bidding Rules Enhancements – Part B
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Project Info Details/Date
Application Software Changes
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
Schedule of major milestones - TBD
Fall 2017 - Reliability Services Initiative Phase 1B
Project Info Details/Date Status
Application Software Changes
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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Schedule of major milestones - TBD
Project Info Details/Date
Application Software Changes
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
Schedule of major milestones - TBD
Fall 2017 – EIM Portland General Electric
Project Info Details/Date
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.
Parallel Operations August 1 – September 30, 2017
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Milestone Type Milestone Name Dates Status
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
Tech Spec Tech Specs 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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