january 7 2010 stakeholder information session presentation
TRANSCRIPT
8/7/2019 January 7 2010 Stakeholder Information Session Presentation
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Reliable Power
Reliable Markets
Reliable People
Wind Technical Rule
John Kehler
Senior Technical Specialist
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Agenda
� Purpose of Session
� Why a Wind Technical Rule
� Summary of Key Points
� Authoritative Documents� Inputs to the Wind Technical
Rule
� Overview and Discussion of theWind Technical Rule
� Next Steps
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Background
Market and Operational Framework
� Market and Operational Framework: effective September 26, 2007
� Premise of framework - If the System Operator receives a reasonable
forecast of wind power generation, then they can establish an operating
plan to accommodate the forecast wind energy by using the following
resources/tools:
± Forecasting
± The Ener gy Market Merit Order
± Regulating Reserves ± Wind Following Services
± Wind Power Management
� Market and Operational Framework: effective September 26, 2007
� Premise of framework - If the System Operator receives a reasonable
forecast of wind power generation, then they can establish an operating
plan to accommodate the forecast wind energy by using the following
resources/tools:
± Forecasting
± The Ener gy Market Merit Order
± Regulating Reserves ± Wind Following Services
± Wind Power Management
� AESO Final Recommendations for the implementation of the MOF -June 18, 2009
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Purpose
� Review and discuss the Wind Technical Rule withstakeholders prior to submission of comments (deadline for comment is Jan 22)
� Encourage stakeholders and suppliers of wind facilityequipment to comment on the Wind Technical Rule
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Key Points
� The Wind Technical Rule is:
� For all wind power facilities, any considerations for existing and newfacilities will be addressed in the Rule
� In most cases the technical intent remains the same as in the
predecessor standard� Primarily to add requirements for physical infrastructure at wind
power facilities for wind power forecasting capability, power limiting,ramp rate limiting and over-frequency control
� Proposing effective date of 180 days post AUC approval to provide
existing facilities a reasonable period of time to add or modify equipmentat wind generating facilities
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Transition of Wind Technical
Requirements
New ISO Rules Frameworkhttp://www.aeso.ca/rulesprocedures/17885.html
AESO Tariff
Authority for the Technical
Requirements currently under the
Tariff
Authority for Technical
Requirements will transition to
Part 500 of ISO Rules
Article 4
Customer Interconnection
Requirements
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Transition of Wind Technical
Requirements
Existing Requirements
� Use and consistency of definitions
� Clarify the language and incorporate newor updated definitions
� Clarify the requirements based on last 5 years experience
New Requirements
� Add grandfathering
� Add Over Frequency Control requirements
� Add Ramp and Power Limiting
requirements� Add forecasting and meteorological data
requirements
Example of anInformation
Document
Existing
Guide
Existing Requirements
New Rule andRequirements
New
Information
DocumentFuture
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Considerations in Developing Wind
Technical Rule
� Current W ind Power Facility Technical Requirements - November 2004
� Wind Power Forecasting Pilot Project Work Group recommendations
� Wind Power Management Protocol Work Group recommendations
� Wind Power Management Technical Requirements Work Group� Transition Of Authoritative Documents (TOAD) policies, template,
framework, standards and principles
� Any applicable provisions of Alberta Reliability Standards
� AES
Ofinal recommendations to implement the Market and Operational Framework for W ind Integration - June 2009
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Specific Policy Considerations
� All forms of generation in Alberta have certain basic obligations
� Wind Technical Rules are specifically for wind power facilities thatconnect to the transmission system
� W ind Power Facility Technical Requirements included ³policy placeholders´ for future technical requirements
� In a separate and future consultation on wind power integration, the AESO will consult on how and when wind power or ramp rate limiting,and wind forecasting, will be used
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Technical Considerations
� Development of technical requirements in Wind TechnicalRule is based on either:
± NERC/WECC requirements, or
± AESO requirements� Fairness amongst generating facilities,
� Technical capability of existing wind facility technology
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Performance Points
� Collector Bus ± Maximum
Authorized MW
± Gross MW
±
ReactiveP
ower requirements
± VoltageRegulation
± VoltageOperating
Range ± Over
FrequencyControl
± Monitoring
� Point of Connection ± Voltage Ride
Through
± Off NominalFrequency
± Power andRamp RateLimiting
± Monitoring
� Facility ± Meteorological
data
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Definitions
(Apply to all participants)
General Definitions
� ³generating facilities´
� ³maximum authorized MW´
� ³operator´
� ³person´
� ³wind turbine generator´
� ³transmission system´
� ³voltage regulating system´
� ³owner´
� ³gross MW´
� ³point of connection´
These definitions will move out
of Wind Technical Rule and
into Part 100: General of the
ISO Ruleshttp://www.aeso.ca/rulesprocedures/17885.html
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Applicability Section 1
Applies to all wind generating facilities
� New facilities must comply
� Existing facilities connected under 2004 technical
requirements must comply
� Grandfathering considerations to those facilities connectedunder 1999 technical requirement
� All wind generating facilities participate in wind power forecasting requirements including meteorological datarequirements
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Example of Grandfathering Rule
3
18 MW grandfathered to the1999 technical requirements
Two 3 MW turbines areupgraded over any period of time. The upgraded 6 MW must fully comply with theWind Technical Rule. The
older 12 MW remain under the 1999 requirements untilsuch time they are upgraded.
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Example of Grandfathering Rule
3
MW
Upgraded portion will be required tocomply with voltage ride through, voltageregulation, reactive power, over frequencycontrol, power limiting, ramp rate limitingand any other requirements that aredeficient to the new Wind Technical Rule
Grandfathered portion is not likely to complywith the voltage ride through and is notrequired to comply with the over frequency
control, power limiting and ramp rate limitingrequirements of the new Wind Technical Rule
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Over Frequency Control
Section 15
� Frequency control requires fast measurement and good resolution of system frequency
± 30 samples per second at 0.004 Hz resolution in the standard
� Consistent with conventional generators
± 0.036 Hz allowable deadband
± Equivalent to 5% speed drop
± Response rate equivalent to gas and hydro
� Coordinates with the off nominal frequency requirements
± Facilities can disconnect from the grid at 61.7 Hz
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59.8
60
60.2
60.4
60.6
Time (10 Minutes Per Division)
A l b e r t a F r e q u e n c y ( H z )
60.036 Hz Allowable
deadband
Time (10 Minutes Per Division)
M W (
I n % o f C a p a c i t y )
( 2 0 % p e r d i v i s i o n
)
Illustrative Example of Wind Generating Facility
MW output to an over frequency event "with"
and without" over frequency controls
Over Frequency Control Example
� Example of actual over frequency event in 2009
� Wind MW is illustrative only
� When system frequencyexceeds the allowable dead-band
� Controls will reduce MW output of the wind generatingfacility
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Power Limiting and Ramp Rate
Limiting Section 17
� Power limiting and ramp rate limiting manage the MWsproduced at the Point of Connection
± These are the MWs supplied to the market
± These are the MWs that will be forecasted
� Power limiting will be manually put in control with a Directive
� The control system must be fast and precise to maintain theMWs within reasonable tolerance of the Power Limit duringvariable and gusting wind conditions
± Prevent MW from exceeding the power limit by 2% for normal windconditions and by 5% during gusts
� Ramp rate limiting is required with a default rate of 10% per minute
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Illustrative Example of How Power
Limiting and Ramp Rate Limiting Could
Coordinate
Illustrative Example of Power Limiting and Ramp Rate
Limiting
10 Minutes Per ivision
M
Potential M s Power Limit
Combined Power and Ramp Rate Limit Actual M s
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SCADA Requirements Section 31
� New SC AD A signals from the facility to the AESO
± Potential MW capability signal
± Power limit signal
± On/off status of the power limiting controls
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Description of potential MW
capability
Measured windspeed and
direction
Local computer calculates
potential MW from the turbine
WPF SC AD A
system collectsand sums thepotential MW
from all turbinesat the WPF
Utility SC AD A
system sendsdata to the
AESO
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Wind Power Forecasting Data
Collection Section 32
� Met tower with 2 weather measurement devices ± measurement at the wind turbine
generator hub height and another takingmeasurements at a height specified by
the ISO
� Measurements are 10 minuteaverage values ± wind speed, wind direction, barometric
pressure and ambient temperature
� AESO is currently working ondetails for data transfer
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Wind Power Forecasting Data
Collection Section 36
� Historical data and facility information necessary for windpower forecasting
± Historical 10 minute averaged meteorological data, containingdetails on wind speed, wind direction, temperature and barometricpressure
± Historical data and records referenced in subsection for up to 2calendar years prior to the commissioning period of wind generatingfacilities
± Provide wind turbine generator data and records, including hubheight, turbine land coordinates, turbine power curves, high windspeed cut-out, and any applicable temperature cut-outs
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Other Changes
� Transfer trip or anti-islanding schemes are proposedadditions where the facility is not required to voltage ridethrough
� Monitoring requirements were a ³may require´ - we are nowproposing a ³must require´
� Harmonic and Flicker measurements/tests were a ³mustrequire´ - we are proposing a ³may require´
� Figures and tables moved into appendixes
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Next Steps
� January 22, 2010
± Stakeholder comments back to the AESO
� February, 2010
± Post Stakeholder comments
± Post AESO response to stakeholder comments
� March 2010**
± File Wind Technical Rule with AUC
**Date may change depending on any material changes as a result of consultation
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Questions ?
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Contact Information
John Kehler
Ph: 403-539-2622
Kevin W iens
Ph: 403-539-2672
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Reliable Power
Reliable Markets
Reliable People
Wind Power Forecasting
Update
Rob Baker
Manager Forecasting
Rob Baker
Forecasting
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Agenda ± Wind Power Forecasting
� Pilot Study
� Wind Power Forecast RFP
� Purpose and Benefits of Wind Power Forecasts
� Wind Forecast Service Cost Recovery
� Next Steps
� Questions
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Wind Power Forecasting Pilot
Project
� AESO conducted a wind forecasting pilot project in 2006 to
± Trial different methods and providers
± Identify the most effective forecasting methods in Alberta
± Identify the most effective providers of wind power forecasts
± Educate industry on the capabilities of wind power forecasting in Alberta
� Project funded by Dept of Energy, Alberta Energy ResearchInstitute, AESO with expertise provided by CanWEA
� Wind forecasters were AWS Truewind, energy & meteo, andWEPROG
� Industry working group monitored results from pilot projectand provided recommendations to AESO used to develop
Forecasting Service RFP
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Wind Power Forecasting RFP
� AESO issued a request for proposals in June 2009
� The objective of the RFP is to solicit proposals to deliver accurate wind power forecasts for the AIES with theseoutcomes:
± Availability of a production Wind Power Forecasting Service for the AESO
± Accuracy and reduced uncertainty of wind power forecasts
± A high quality Wind Power Forecasting Service and ongoingperformance improvements
� AESO involved industry stakeholders (ENM AX, CanadianHydro, Shell, Suncor, Trans Alta, and CanWEA) to provideinput and advice to the AESO regarding the selection andRFP review process
� Negotiations with a vendor are underway
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Purpose and Benefits of Wind
Power Forecasts
AESO
� Reliable operation of the power system
± Ancillary service forecasting and procurement
± Supply adequacy
Wind Developers
� Each individual wind generating facility will have access to the forecastfor its facility
Industr y / Market Participants
� Aggregate forecasts provided on the AESO website
� Transparency of aggregate wind forecasts to market participants
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Wind forecast service cost
recover y
� External wind power forecasting service cost will beallocated amongst wind power facility owners as a $/MWhcharge
� Cost recovery will begin in Q4 2010 and will be levelizedover Q4 2010 and the subsequent 3 years
� An escalation factor of 10% to the $/MWh rate will beapplied
� Variances from forecast costs and revenues will bereconciled on an annual basis
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Questions ?
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Contact Information
Rob Baker
Ph: 403-539-2614
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Reliable Power
Reliable Markets
Reliable People
Transmission Constraints
Management (TCM)
Gordon Nadeau
Market Design Specialist
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Agenda
� TCM Rule 9.4 AUC Re-Filing Proposal Discussion Paper
± AUC Decision 2009-042:
� Review AESO views on Commission findings
� Review AESO proposals on Commission directions
� Remedial Action Scheme (R AS) in the planning domain
± Review AESO approach in R AS comment response matrix
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Proposed TCM Rule 9.4
Protocol Steps to Manage Constraints
1. Determine effective generation and load
2. Directives to generate above MC are canceled
3. Dispatch off downstream Dispatch Down Service (DDS) providers
4. Curtail imports/exports as appropriate
5. Curtail downstream Demand Opportunity Service (DOS)6. Dispatch effective TMR (use DDS to reconstitute price)
7. Curtail upstream energy in reverse merit order (RMO) based onenergy offer price followed by pro rata, if congestion is sustainedbeyond T-2 period, use pro rata only
8. Dispatch downstream energy using the merit order up to replace thecurtailed upstream energy
9. Curtail downstream load
10. When curtailing effective upstream assets, curtail ancillary servicesbefore energy
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Review of Findings in
AUC Decision 2009-042 on TCM Rule 9.4
� Economic Dispatch: The use of the merit order for dispatch instructionsis aligned with regulation.
� Price Impact: Price impact of the TCM rule will be reasonable under
current and anticipated market conditions.
� Compensation: Constrained down payments are not contemplatedunder regulation.
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Review of Findings in
AUC Decision 2009-042 on TCM Rule 9.4
� Transmission ³rights´: Regulation provides for reasonable systemaccess which does not equate to a ³right´. The AESO is allowed toassign a R AS under regulation where appropriate.
� Use of TMR/DDS: The use of TMR/DDS may be applicable in certainsituations but that it is not appropriate in all constraint situations.
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AESO Proposals regarding Commission
Directions on TCM Rule 9.4
Directions:
� Scope of Rule
� Use of TMR
� Pay as bid protocol
� Define fundamental terms
� Clarify TCM process steps
Proposal:
� 9.4 is real time rule only
� TMR for reliability only and
not price management
� Pay as Bid not recommended
�Definitions provided for loadpocket and other terms
� Explain use of TMR/DDS withinsteps
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Pay as Bid Discussion
Pros
� Price impact of constraintremoved
� Creates separate sidepayments for constraints
� Congestion costs may belower than proposed TCMprotocol
Cons
� Does not promote price fidelityunder current market design
� Not the best price signal and maynot be effective in managingconstraints
� Not a generic, in-market solutionthat applies to all constraint cases
� Operationally and administrativelycomplex to implement
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Pay as Bid Discussion
AESO Conclusions
� Price signal is the appropriate method of encouraging FEOC behaviour not out of market solutions
� The Rule 9.4 protocol:
± Is effective and practical
± works within current market framework ± Is a single protocol that deals with all constraints
± Promotes price fidelity by minimizing the price impact and level of marketdistortion
� The AESO does not recommend using any pay as bid protocol withinthe TCM Rule
� Severe market distortions are not constraint management issues andwill be dealt with appropriately through other means
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Reliable Power
Reliable Markets
Reliable People
Remedial Action Scheme
(RAS) in the Planning Domain
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RAS in the Planning Domain
� Stakeholder comments on the R AS discussion paper and the AESO response to those comments were published in December 2009
� A review of the AESO approach is provided to facilitate ongoingstakeholder consultation on R AS
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RAS Discussion
Transmission Regulation gives the AESO the authority to use R AS
� R AS is permitted under the Transmission Regulation section 15(1),however, R AS is not an alternative to major system upgrades or keytransmission paths
� R AS can be temporary or permanent under section 15(1)
� Specific temporary R AS exceptions are allowed under sections 15(2)and 15(3)
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RAS Discussion
Overarching R AS rules are appropriate
� Requirement for R AS determined by Reliability Criteria and AlbertaReliability Standards - It is not appropriate to have R AS criteria in theISO rules
� Reliability Criteria documentation to be reviewed in 2010 and specificR AS criteria will be discussed
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RAS Discussion
Two types of R AS: Connection R AS and System R AS, each of whichserve different purposes and require different approaches
Connection RAS
� Assigned to and paid for by customers on a last in first off basis - Alternatively, the customer can choose to wait untilfacilities are built
� Is temporary, however, the AESO can only provide anestimate of when it is no longer needed
� Customers do not receive compensation for beingconnected to a R AS
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RAS Discussion
System RAS
� May be assigned or procured
� Customers do not receive compensation for being constrained down
� May be permanent
� System R AS applications unique:
± May develop over time with no single cause
± Variety of solutions may exist
± Could involve generation or load or both ± Compensation may be a consideration depending on the purpose and who
benefits from the protection
± Each application will require consultation on a case by case basis
± May require high level guiding rule
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Next Steps
� Comments on the TCM paper due January 15, 2010
� AESO response to comments will be provided and mayproceed to re-filing Rule 9.4 with the AUC in Q1
� OPPs will be filed in stages in 2010 and full implementationof Rule 9.4 thru OPPs and systems to proceed on a yet tobe determined schedule
� Consultation to proceed on R AS rules and a R AS
Information Document in Q1
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Contact Information
Gordon Nadeau
Ph: 403-539-2568