market services stakeholder session
DESCRIPTION
Market Services Stakeholder Session. January 12, 2011. Agenda. Consultation and Conceptual Design. Review Progress Against Objectives 12 – 18 months. Share our Research & Learnings from Other Markets. Clear Interpretation of Policy Framework. Share our Data & Analysis. - PowerPoint PPT PresentationTRANSCRIPT
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Market Services Stakeholder Session
January 12, 2011
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Agenda
Introductions, 2010 in review, the year ahead Kelly Gunsch
Market Suspension Anita Lee
Supply Surplus Ruppa Minhas
Coffee Break
Wind Integration Jacques Duchesne
Intertie Framework – ATC Allocation Kevin Dawson
Transmission Constraint Management / Remedial Action Schemes
Gordon Nadeau
Questions & Answers
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Consultation and Conceptual Design
Definition of the Problem
Clear Interpretation of Policy Framework
Share our Data &Analysis
Share our Research& Learnings
from Other Markets
Review ProgressAgainst Objectives
12 – 18 months
Iterative Consultation if New Ideas, New Concerns,
New Data
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Solution Development and Implementation
Conceptual design
- define success
- idea generation
- stakeholder consultation
- iterative
- rules development
*AUC approval now required
Detailed design
- processes
- systems
- procedures
- training
Implementation
- process changes
- system changes
- testing & training
Operationalize
Steps may be iterative, performed more than
once within each initiative
Feedback loop – is the implemented solution achieving the initial objectives?
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2010 & 2011 Priorities
• Wind
– Integrate new wind
– Complete implementation of Phase 1
– Phase 2
• Interties
– Integrate MATL
– ATC Allocation
– Intertie (ATC) restoration initiatives
– Implementation of long term framework
• Demand Response
– LSSi
– Brattle Review
• TCM & RAS
– Compliance Filing & Phased Implementation
– Draft RAS Rule
• Contingency Rules
– Supply Surplus
– Market Suspension
• FEOC Regulation Implementation
– AESO Rule updates necessary
• Outage Information Sharing
• Market Rule Transition (TOAD program)
• OR Redesign
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Market Suspension
Anita Lee, P.Eng. PMP
January 12, 2011
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Purpose of review
• Current rule is outdated (e.g., pricing methodology)
• Current rule does not differentiate between events of lesser impact (such as temporary loss of the dispatch tool) and events of more significant impact (such as an AIES blackout)
• Ensure market suspension is only used as a last resort
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Status Update
• Recommendation Paper issued December 2, 2010
• Stakeholder comments due January 14, 2011 – comments to be sent to [email protected]
• Development of rule changes in Q1 2011
• Stakeholder consultation on rule changes in Q2 2011
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Highlights of Recommendation Paper
• Limited Market Operation
– Triggered when:
• There is a temporary outage to market operation tools (DT or ETS)
• The System Controller cannot access market operation tools after evacuation from the System Coordination Centre and before the Backup Coordination Centre is activated
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Highlights of Recommendation Paper
• During limited market operation:
– The System Controller will use the best available EMMO for energy market dispatch
– DDS dispatch and AS dispatch will be limited
– Payments to Suppliers on the Margin (PSM) will be suspended
– The System Marginal Price (SMP) will be set by the highest price block dispatched in the EMMO in use
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Highlights of Recommendation Paper
• Market suspension triggered when:
– There has been an extended period of market operation tool outage,
– The System Controller has evacuated the System Coordination Centre and cannot access or activate the Backup Coordination Centre,
– The AIES has broken into two or more electrical islands, or
– The AIES has experienced a blackout
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Highlights of Recommendation Paper
• A market suspension
– Must be authorized by the AESO CEO or his designate, except in the case of an AIES blackout where it can be declared by the System Controller
• During a market suspension
• The System Controller will not necessarily follow the EMMO, but will direct generation as necessary to maintain system reliability
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Highlights of Recommendation Paper
• System Marginal Price during a market suspension will be determined as:
– 30 day rolling average on peak price and 30 day rolling average off peak price, prior to initiation of the market, or
– $999.99 when all available energy is dispatched and the System Controller invokes Supply Shortfall procedures in order to manage supply and demand balance
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Highlights of Recommendation Paper
• A cost-based mechanism will be provided
– To ensure generators’ operating costs are covered
– The cost calculation formula is similar to that for Long Lead Time Energy (LLTE), except generator start up costs are only included if a generator is directed by the System Controller to start during a market suspension, and
• Directed off by the SC during the market suspension, or
• Dispatched off by the SC upon the cancellation of the market suspension and return to normal market operation
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Next Steps
• Comments on the Market Suspension Recommendation Paper are due this Friday, January 14, 2011 to [email protected]
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Questions?
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Supply SurplusRecommendations
Ruppa Minhas
January 12, 2011
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Status Update
• AESO responses to stakeholder comments on the Supply Surplus Discussion Paper published December 2, 2010
• Supply Surplus Recommendation Paper published for stakeholder comment on December 2, 2010
– Stakeholder comments on the Recommendation Paper are due January 14, 2011
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Supply Surplus
• Supply Surplus:
– More supply than demand at $0
• Purpose:
– Provide recommendations on the solutions for managing supply surplus conditions
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Recommendations - Summary
• No exemption for wind generators and cogenerators
• Implement of voluntary generator curtailment request (VGCR)
• Allow exports within T-2
• Update minimum stable generation (MSG)
• Supply surplus report
– Implemented December 8, 2010
• A voluntary generator curtailment program (VGCP)
– Not recommended
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Recommendation - No exemption for wind and cogenerators
• It is necessary to include all generation types in the supply surplus procedures so that they are all on a level playing field
• Allowing a blanket exemption for one generation type will not accomplish this
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Recommendation - No exemption for Cogenerators
• To ensure a FEOC market the rules must consider, and, to the extent possible, accommodate the different characteristics of each generation type without unduly favouring one type of generation over another
• Minimize the impact to cogen facilities as a result of supply surplus:
– Electric energy produced and consumed on site is not subject to the ISO rules: EUA, Section 2(1)(b)
• Cogenerators will not be curtailed below 0MW net to grid
– Generators will be curtailed to their MSG level
• Revise MSG definition to better accommodate current generator limitations
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Minimum Stable Generation
• MSG definition and application requires an update
• MSG workgroup
– Meeting was held in October 2010
• Further consultation:
– Meeting again soon:
• To finalize the proposed definition
• To discuss options for changing the application of MSG
–To allow participants to change the MSG value on a time-ahead basis
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Comparison – Supply Surplus and Supply Shortfall
Supply Surplus Supply Shortfall
$0
• More supply than demand
• Need to achieve supply-demand balance
$999.99
• More demand than supply
• Need to achieve supply-demand balance
Curtail current hour import transactions
• Included within existing and recommended procedure
Reduce export ATC to zero
• Step 6 in OPP 801
Voluntary Generator Curtailment Request
• Request to market to allow generators to voluntarily curtail supply
Request to market to provide supply
• Step 4 in OPP 801
Allow exports within T-2
• Low cost and easy to implement
Allow imports within T-2
• Step 5 in OPP 801
Assess an assets involvement in RR, consider re-dispatch if required
• Included within existing and recommended procedure
Issue directive for excess reserves
• Step 19 in OPP 801
Supply Surplus Report
• Provides the market with an indication of potential supply surplus conditions
Supply Adequacy Report
• Provides the market with an indication of potential supply shortfall conditions
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Voluntary Generator Curtailment Program (VGCP)
• VGCP not recommended at this time
• Received mixed participant support and most participants were not in favour
• May be a more complex solution than is required
• Not required at this time
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Recommendation – Supply Surplus Procedure
1) Curtail current hour import
2) Maximize the posted export ATC limit
3) Send out a VGCR request to voluntarily reduce generator output.
4) Dispatch flexible blocks of the $0 offers for partial volumes on a pro-rata basis and direct wind generation on a pro-rata basis.
5) Direct assets with inflexible $0 offers to MSG
6) Assess an assets involvement in RR, consider re-dispatch if required
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Supply Surplus Report
• Available on the AESO website on December 8, 2010
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Next Steps
• Stakeholder comments on recommendation paper due January 14, 2010 to [email protected]
• MSG workgroup meeting soon
– Invite will be sent out through the weekly stakeholder email and posted on the AESO website once scheduled
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Questions?
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Coffee Break
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Wind Integration Program
Jacques Duchesne P. Eng.
Program Manager, Wind Integration
January 12, 2011
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Wind Integration – Objectives
Phase 1:
• Wind integration management plan designed and implemented to safely integrate 1100 MW of wind by end of 2011
Phase 2:
• Wind integration plan for up to 4000 MW
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Agenda
• Program overview
• Status update phase 1
– Wind Technical Rule
– Wind power management
– Forecasting
• Status update phase 2
– Discussion Paper
– Stakeholder sessions
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Wind Integration Program – High Level View
Wind Power
Forecaster Selection
Wind Power
Forecast Integration
Short-Term
Plan Design
Wind Technical Rule
Phase 2
Design & Consultation
Phase 2 Implementation
Short-term
Market studies
Long-Term
Market Studies
Wind Power Management
2010 2011 2012 / 2013
Wind Power
Forecast Integration Design
Wind Power Forecast Roll-out
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Phase 1 Update
• Wind Technical Rule
– Filed with AUC August 2010
– Hearing scheduled for February 28
• Phase 1 Recommendations - September 2010
– Use EMMO as primary tool
– Use wind power management when wind ramping up too fast
– For wind ramp down, activate contingency reserves from standby. No additional volume required at 1100 MW wind.
– Continue implementation of centralized forecast
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Wind Forecast
• Signed contract with WEPROG January 2010
• Forecast will:
• Reduce wind related Area Control Error (ACE) events
• Decrease the amount of wind generation impacted by Wind Power Management
• Provide visibility to system controllers
• Developed implementation guide November 2010
• Roll-out to existing wind farms in progress
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Phase 2 - Status
• Market and Operational Studies completed December 2010
– Cases: 1575 MW, 1700 MW, 2500 MW & 4000 MW
• Issued Discussion Paper for comments – December 2010
– Comments due back January 28
• Will hold stakeholder consultation to explore in Q 2011
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Phase 2 Summary – Discussion Paper
• Rely on the Energy Market Merit Order
• Increase regulating reserve volumes.
• Refine short-term wind integration recommendations
• Develop a ramping service
• Develop a wind firming service: A market service could be developed to firm overall wind production
• Develop must offer must comply (MOMC) rules for wind
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Next Steps
• Phase 1
– Tool to calculate ramp rate and system wind power limit
– Consult on rule defining use of WPM
– Site specific forecast integration
• Phase 2
– Stakeholder comments due back January 28
– Ongoing consultation – wind working group Q1 2011
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Next Steps
• Comments on the Phase 2 Wind Integration Discussion Paper are due Friday, January 28, 2011 to [email protected]
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Questions?
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Intertie Framework – Available Transfer Capacity Allocation
Kevin Dawson, Program Manager, Interties
January 12, 2011
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Intertie Framework – Today’s Agenda
• Summary of Intertie Framework Recommendation Paper
• Overview of recent ATC information package (letter, term sheet)
• Discussion on ATC allocation recommendation
– Options considered
– Recommendation
– Next steps
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Intertie Framework Recommendation Paper
• Intertie Framework Recommendation Paper published October 7, 2010 contained four main recommendations:
– ATC allocation by energy price and then pro rata
– Implement dynamic scheduling
– Develop and implement a merchant transmission service (MTS) tariff
– Plan system so each intertie can simultaneously transfer path rating
• Stakeholder comments have been received and posted
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Intertie Framework – ATC Allocation
• Immediate focus on ATC allocation as third tie line under construction will result in requirement to allocate limited ATC among multiple interties
• ATC letter and term sheet posted December 16, 2010 – For information purposes
– Provides overview of new rule framework
• Process going forward
– Rule drafting in progress (in integrated format)
– Rule cycle for February / March
• Fulsome opportunity for comment on rule change and rule language
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Intertie Rules – Term Sheet Overview
• Rule framework integrates previous OPPs with rules
– Limits Total and Available Transfer Capacity (TTC, ATC)
– Scheduling
– Validation and setting of schedules
– Congestion management on the interties
– Dispatching intertie schedules
• Term sheet provides overview of new rule format outlining proposed rule provisions and how they map to current rules and OPPs
– Highlights where rule changes are recommended – allocation of ATC
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ATC Allocation – Design Choices
• Approval process– Approve tags, allow for other scheduling authorities to make cuts
using their criteria (tariff)
• Alternative does not recognize commercial product in other jurisdiction and may prematurely reject tags
• Timeline– Xx:45 consistent with objective noted above
• Earlier alternatives, e.g., T-2, perhaps more consistent with rest of market but don’t recognize products in other jurisdictions and may reduce overall intertie utilization
• Procedures– Submissions, scheduling and congestion management
• Discussed below
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ATC Allocation Recommendation
• Recall – current method is to curtail on a last in, first out (LIFO) basis
• New proposal – pro rata– At xx:45, assessment and validation
– Test for oversubscription first at system, then AC, then intertie level
– Resolve any oversubscription by:
• Netting out counterflows and wheelthroughs
• Price (when implemented)
• Pro rata of equal priced offers / bids at assessment level (system, AC, intertie)
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Example ATC Pro Rata Allocation Math
• Simplified example – no wheelthrough and only 1 tag per import/export
• In this example, system limit is OK but AC import limit is violated
• BC and Montana imports pro-rated down by 100 MW to come within limits
• All interties are within limits
Import Export Import Export Import Export Import Export Import ExportCapability 700 700 300 300 150 150 700 700 850 650Scheduled 550 50 300 0 50 0 850 50 900 50Net Sch. 500 300 50 800 850
Adjustment -65 -35 -100
Final Sch. 485 50 265 0 50 0 700 750
MT Intertie SK Intertie Net AC limit System limitBC Intertie
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Congestion Management Choices
• Number of choices considered and rejected:– Pro rata math limited to maximum of ATC on any line instead of
schedules
• Recognize incentive to over schedule, however “must supply” if dispatched
• May need to revisit if “must supply” risk is not sufficient to limit behaviour, but mathematically implementation is problematic
– Curtail first at intertie level, then AC, then system
• No opportunity at xx:45 to optimize process. Recognize that on occasion cut at intertie level may be more efficient. Will monitor to see if occurrence more frequent than expected.
• Expect ability to “net schedule” at system level should allow for maximized utilization of ATC
– Curtail by participant not tag
• Fairness issue
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Next Steps
• ATC term sheet comments welcome but not required
• Rules process for integrated rule language to commence in February
• Expect rule filing with AUC by end of March, 2011
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Questions?
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Transmission Constraint Management & Remedial Action Schemes
Gordon Nadeau
January 12, 2011
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Transmission Constraint Management
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Transmission Constraint Management AUC Decision 2009-042
• Original proposed rule was deemed to be technically deficient and the AESO has addressed those deficiencies by:
– defining the scope of the rule
– providing clarity around certain steps
– defining specific fundamental terms
– defining the use of TMR
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Transmission Constraint Management AUC Decision 2009-042
• ENMAX proposal:
– Not generally consistent with the AESO’s approach, as stated by the Commission
– has perverse incentives
– not compatible with the current market design
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Transmission Constraint Management - Rule Filing
• Submitted the rule 9.4 as a compliance filing on December 16, 2010
• TCM update letter on the AESO progress on TCM Initiatives
• TCM rule language comment response matrix
• Rule was filed in accordance with section 20.5(2) of the EUA
• AUC will provide further direction
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Transmission Constraint Management-Implementation
• Once a final decision is received:
– Operational tool development
– OPPs will be aligned and filed in stages in 2011 and full implementation of Rule 9.4 thru OPPs and systems to proceed through 2012
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Remedial Action Schemes
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Remedial Action SchemesBackground
• Remedial Action Scheme (RAS) consultation has proceeded in parallel with TCM rule 9.4; part of comprehensive consultations on constraint management
• On July 20 2010, the AESO initiated formal rule consultation on a proposed Connection RAS rule and provided a draft RAS ID to help clarify the policies applied to Connection RAS
• Stakeholder comments on the proposed Connection RAS rule were posted to the AESO website on September 9, 2010
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Current Connection RAS Status
• The AESO is currently considering stakeholder comments
• Some stakeholders are seeking clarity on AESO connection policies; others are looking for firm AESO commitments during the connection process
• The AESO is of the view that further consultation is required to discuss these issues and potentially broaden the scope of the Connection RAS rule
• Targeting first half of 2011 for filing rule with AUC
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Questions?
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Thank you