miso’s midwest market initiative
DESCRIPTION
MISO’s Midwest Market Initiative. APEX Ron McNamara October 31, 2005. Who We Are. The Midwest ISO is an independent, non-profit entity that monitors the transmission grid of high voltage electricity across much of the Midwest. Operational Since December 15, 2001 23 Transmission Owners - PowerPoint PPT PresentationTRANSCRIPT
MISO’s Midwest Market Initiative
APEX
Ron McNamaraOctober 31, 2005
The Midwest ISO is an independent, non-profit entity that monitors the transmission grid of high voltage electricity across much of the Midwest.
Who We Are
Midwest ISO Membership
Operational Since December 15, 2001 •23 Transmission Owners•36 Control Areas•119,207 MW of peak load•137,000+ MW generating capacity •97,000+ miles of transmission lines•947,000 square miles•15.1 million customers• 1,504 generating units in the reliability footprint• Carmel and St. Paul Control Centers
The Role of RTOs
Monitor flow of power over the grid
Schedule transmission service
Perform transmission security analysis for the Reliability Area footprint
Manage power congestion through LMPs
Approve transmission & coordinate generation maintenance outages
Perform long term planning & analysis for region
Operate Real-Time & Day-Ahead Markets
MISO Day 1 Operations
Bilateral transactions facilitated by “physical” transmission service provided under regional OATTMISO’s primary responsibilities related to the market include:
• Acceptance and analysis of requests to reserve transmission capacity for future scheduling of transactions
• Acceptance of schedules for approved reservations• Monitoring transmission usage• Providing reliability coordination• Invoicing participants monthly for use of transmission lines as
well as other associated services
MISO Day 2 Operations
In addition to the “Day 1” activities, MISO began operating energy markets on 1 April 2005:
• Implementation of market-based congestion management system through LMP
• Day Ahead Market• Real Time Spot Market• Financial Transmission Rights
Midwest ISO Energy Markets
Some critical design elements: Real-Time Centralized Security Constrained Economic Dispatch
with Locational Marginal Pricing (LMP) Day-Ahead Security Constrained Economic Dispatch with
Locational Marginal Pricing (LMP) Security Constrained Unit Commitment in Day-Ahead Market Financial Transmission Rights that settle against Day-Ahead
Market Reliability Assessment Commitment (RAC) Seams with other markets *Ancillary service markets including Resource Adequacy
Midwest ISO Energy Markets
Market design accommodates: Self-Schedules and Bilateral Schedules Pre-OATT Contracts (grand fathered agreements) Ancillary Service Procurement Control Area Activities Use Limited and Demand Response Resources Accommodate Retail Access Programs Load Aggregation and Trading Hubs Market Power Mitigation
Real-Time Centralized Dispatch
MISO uses the Security Constrained Economic Dispatch (SCED) program every 5 minutes of each operating hour
MISO sends control areas Net Scheduled Interchange (NSI) and basepoints for generators
– NSI and resource basepoints sent every 5 minutes– Dynamic Schedules sent every 5 minutes– Ramped Control Area NSI sent every 4 seconds– Ramped Dynamic Schedule values sent every 4 seconds
Control Areas will be responsible for regulation between dispatch interval and for operating reserves
MISO calculates ex-post Real-Time LMPs based on actual system activity
Day-Ahead Market
MISO uses a Security Constrained Unit Commitment programs and a Security Constrained Economic Dispatch (SCED) program to find the least cost-commitment and schedule
MISO calculates Day-Ahead LMPs based on schedule
Day-Ahead Market accommodates:
Multi-part generation offers (Start-up cost, no-load cost, incremental cost curve)
Fixed and price sensitive demand bids
Virtual supply offers and virtual demand bids
Transmission Rights
• MISO allocates Financial Transmission Rights to participants based on existing OATT transmission service.– 4 tiers…with a restoration step.– Yearly, seasonal, peak/off peak.– Monthly “true up” process.
• FTRs allow parties to hedge congestion costs in the Day-Ahead Market
• MISO also runs FTR auctions in which participants can bid to buy and offer to sell FTRs
• In addition to FTRs for OATT transmission service, MISO accommodates scheduling under pre-OATT transmission service.
RAC Process
The following principles have guided development of this RAC process: The RAC process should allow the Midwest ISO to commit the capacity it deems necessary to reliably operate the grid at the least commitment cost;
The RAC process should have a transparent and equitable implementation process;
The RAC process is not intended to create any ‘new’ markets outside of the existing proposed energy markets; and
The RAC process should be incentive compatible with the Midwest ISO’s proposed Day-Ahead and Real-Time Energy Markets;
Midwest ISO Seams
SPP TVA
MAPP
IMO
PJM
In co-operation with our neighbors we developed and implemented seams agreements that result in improved information sharing, communications, and coordination:
– RTO to other RTO/ISO’s (PJM,SPP,IMO)
– RTO to other Reliability Coordinators (TVA)
– RTO to other Control Areas (MAPP)
The Reliability Charter
Midwest ISO & Balancing Area roles and responsibilities: Real-Time Energy Market
Multi-Balancing Area Implementation The Midwest ISO will not directly control generation 5-minute LMP Base-points produced by the Midwest ISO and sent to
Market Participants using 5-minute Load Forecast at Balancing Area granularity
Net Scheduled Interchange calculated by the Midwest ISO and sent to each Balancing Area continuously
Balancing Area performs regulation between 5 minute LMP base-points
Generation limits sent by market participants has generation set aside for regulation and operating reserves “blocked off” from LMP dispatch
Improved Reliability Functions Center Around System Operations Dispatch
Security-ConstrainedEconomicDispatch Congestion
Redispatch
Real-TimeBalancing
CoordinateInter-utility
Flows w/Others
Keep FlowsWithin Limits
Maintain Voltage and Frequency
Monitor Flows, Limits &
Contingencies
Grid OperatingInstructions
Manage OperatingReserves
Benefits for participantsReduced barriers to trade
– Elimination of pancaked transmission rates– Uniform access -- one stop shopping for transmission service and
interconnection– TLR replaced with market-based redispatch
Coordinated markets– Liquidity/transparency– Expanded choices
• Self-scheduled generation or load• Bilateral transactions• Spot purchases or sales• Forward hedging• Virtual transactions
Actual Results - Real Time Peak Prices
Real-Time Peak Price Trend of MISO and Neighboring Markets
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4/1/20054/8/20054/15/20054/22/20054/29/20055/6/20055/13/20055/20/20055/27/20056/3/20056/10/20056/17/20056/24/20057/1/20057/8/20057/15/20057/22/20057/29/20058/5/20058/12/20058/19/20058/26/20059/2/20059/9/20059/16/20059/23/20059/30/200510/7/2005Time
$/MWh
MISO_AvgPeak_RT PJM_AvgPeak_RT NYISO_AvgPeak_RT IMO_AvgPeak_RT
Actual Results - Average Peak Prices
7-Day Rolling Average of Real-Time Peak Prices of MISO and Neighboring Markets
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Time
MISO_AvgPeak_RT PJM_AvgPeak_RT NYISO_AvgPeak_RT IMO_AvgPeak_RT
Concluding Remarks
• Just the beginning:– Commitment process– Capacity Mechanism– Ancillary Services– Multiple control areas– Joint and Common Market Activities– Enough to keep us busy for several years to come!
• Questions?– [email protected]– 317.249.5774