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TRANSCRIPT
Reliable Power
Reliable Markets
Reliable People
Implementation of Market & Operational Framework for Wind Integration Stakeholder Information Session
Monday, March 23, 2009
Metropolitan Centre, Calgary
2
Agenda
• Welcome and Purpose of Session
• Role of the AESO
• Challenges with Large Scale Wind Integration
• MOF Background
• Recommendation Paper WP Forecasting
WP Management
Supply Surplus
• Implementation and Key Initiatives Transmission Update
• Summary and Next Steps
3
Purpose of today’s session
• Provide stakeholders an opportunity to ask questions, clarify information in order to submit formal comments to MOF Implementation Recommendation Paper by April 3 deadline
• Review key recommendations in MOF Implementation Paper
WP Forecasting
WP Management
Supply Surplus
• Provide a brief update on key initiatives related to wind integration
• Review next steps in process
4
Stakeholder consultation principles
• The AESO’s consultation process offers all stakeholders an opportunity for meaningful input
• All stakeholders have the right to comment on the AESO's plans, decisions and actions
• The experience and expertise offered by stakeholders through the consultation process improves the quality and implementation of decisions
• The AESO's consultation process and rationale for decisions are transparent
• All stakeholders have the right to be informed of the AESO’s direction, plans, the status of issues, and decisions in a timely manner
• The AESO measures the effectiveness of its consultation process in order to improve future performance
5
Alberta’s electric industry
• 9,806 MW peak and 80% LF
• 12,159 MW total generation
• Over 280 generating units
• Wholesale market with about 200 market participants
• > 21,000 km of transmission
• Interties BC (up to 780 MW) & Sask. (up to 150 MW)
BC
AltaSask
5,893 MW
4,686MW(Other renewables)
214 MW
(Wind)
497 MW
869 MW
Over 12,000 MW of Wind Power Interest
6
AESO - Our core business
• Markets: develop and operate Alberta’s real-time wholesale energy market to facilitate fair, efficient and open competition
• Transmission System Development: plan and develop the transmission system to ensure continued reliability and facilitate the competitive market and investment in new supply
• Transmission System Access: provide system access for both generation and load customers
• System Operations: direct the reliable operation of Alberta’s power grid
7
Grid and Market Operations – Key functions
• Operate the AIES in a secure and reliable state Forecast and anticipate future operations (1-24 hours) Manage and monitor AIES (flows/volts) – within limits and standards Manage and dispatch transmission must run requirements Manage congestion on the system Manage interchange/transfers on interconnections Coordinate TFO operation & coordinate maintenance (GFO and TFO) Integrate new transmission facilities to interconnect generation and load Manage and direct power system restoration and emergency operations Conduct short term adequacy assessments
• Operate the Alberta market according to AESO Rules and FEOC Use merit orders to meet the supply/demand balance and ancillary services
requirements Comply with Rules for reliability and system performance (spinning and operating
reserves) Consider constraints and characteristics of individual units Ensure fair, efficient and openly competitive operation of the electricity markets
8
Operational and market uncertainty
• Load varies by seconds, minutes, hours, by day type, and with weather Operators are experienced and familiar with load patterns and it can be forecasted
within reasonable accuracy (within few percent)
• Dispatchable generation can vary - typically within 1% of dispatch order Some uncertainty with conventional supply but high capacity factors, outages are
coordinated and availability is known Supply resources may not be available or limited in capacity due to outages or de-
rates
• Pool price affects supply and demand (price sensitive load)
• Significant integration of wind generation can alter familiar operational “patterns”
Semi-dispatchable resource (only when there is fuel) More challenging to forecast (may be out by several hours and 100% magnitude) Capacity factors vary by weather, season and time of day
• Operational plans are based on best available forecasts of needs and available resources
There is always error and uncertainty in our business - we are good at managing it!
9
Challenges to integrating large scale wind
• Supply-demand balancing is more challenging with wind power – wind can be unpredictable, increase or decrease rapidly and patterns can be correlated or counter to load
• Limits to how much wind a system can accommodate – need access to flexible resources considering physical limits (ramping and start up times)
• Reliability issues > 900 MW – need mitigating measures, resources and the scale/costs can escalate
• Market Impacts – can increase variability and uncertainty
• Need Transmission – upgrades in southern part of the province and recognizing diversity
Supply Demand
Alberta System Demand and Wind Power Correlated Well Nov 6 2006
7000
7500
8000
8500
9000
Time - 1 Hr per Division
Sy
ste
m D
em
an
d M
W0
80
160
240
320
Sy
ste
m W
ind
Po
we
r
MW
Alberta System Demand and Wind Power Do Not Correlate Well Jan 6, 2006
7000
7500
8000
8500
9000
Time - 1 Hr per Division
Sy
ste
m D
em
an
d M
W
0
80
160
240
320
Sy
ste
m W
ind
Po
we
r
MW
10
Need dispatchable resources to accommodate wind
Baseload Generation
$0 Offers
Ma
rke
t C
ap
ab
ilit
y
Ab
ov
e B
as
elo
ad
Amount of dispatchable generation varies according to
market conditions
11
Wind power diversity and ramps
In Alberta there are times when there is diversity amongst wind power facilities
There are times when there is little to no diversity amongst wind power facilities
12
Correlation between pool price and wind power
• Wind generation offers into the market at zero dollars
• Pool price tends to be lower when there is a significant amount of wind generation
• Three factors influencing wind project development
1. Pool price
2. Federal incentives
3. Environmental attributes
Wind vs. Pool PriceAverage Pool Price for Varying Amounts of Wind
$83.78
$61.85$56.78
$45.19 $44.43
Annual Average Pool Price: $66.95
0
10
20
30
40
50
60
70
80
90
100
0MW to 100MW 100MW to 200MW 200MW to 300MW 300MW to 400MW 400MW to 500MW
Range of Hourly Wind Generation
Av
era
ge
Po
ol P
ric
e (
$/M
Wh
)
2007 Data
13
Wind power capacity factors
• Over 1,400 GWh of electric energy and annual capacity factor of about 35 % in 2007
• Capacity factors of wind power exceed 50 % during some
periods or minimal capacity on some
days (summer and winter peaks) due to prevailing weather conditions
• AESO and Market participants: Must become familiar with
characteristics and Factor it into day-day
operating practices, decision making processes and offer strategies
0%
10%
20%
30%
40%
50%
60%
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Ca
pa
cit
y f
ac
tor
Capacity factor by month*Annual average Capacity factor
Alberta wind power generated 1431 GWh of electricity energy in 2007
0%
10%
20%
30%
40%
50%
60%
20% 30% 40% 50% 60% 70% 80% 90% 100%
Total Wind Generation Output
Perce
ntage
of T
ime a
t a G
iven O
utput
Leve
l Spain Wind Power Distribution(2001 – 2005)
14
AESO’s wind integration journey
2003 2004 2005 2006 2007
Study 1200 MW of Wind
Power
New Standard
specific for Wind Power
Facilities
Phase 1 Study
Study up to 2000 MW
Confirms need for Mitigating
MeasuresPH II Study
and Temporary Threshold
Confirm effectiveness of Mitigating Measures
Market and Operational Framework
(MOF) introduced
AESO-CANWEA
collaboration
Initiate Wind Power
Forecasting Pilot
2008
Workgroups on Supply
Surplus and Wind Power Management
Finalize Forecasting
Pilot
2009
Implement MOF Recommendations
Workgroup findings incorporated into
paper
CanWEA Award
UWIG Award
15
The AESO’s commitment
“Our ultimate objective… is to refocus the dialogue with industry to integrate as much wind into the Alberta system as feasible without compromising system reliability or the fair, efficient, and openly competitive operation of the market.”
16
How to add more wind?
• To integrate more wind the operator needs to “know what to do” and “have the necessary resources/tools”
• Current resources/tools
The energy merit order
Regulating reserves
• New resources/tools
Wind power forecasting
Additional regulating reserves
Supply / load following service, (i.e. the service would accommodate pumped storage, batteries, others)
Power and/or ramp-rate limiting of wind power facilities
17
Challenges and solutions
CHALLENGES MOF SOLUTIONS
Flexible Resources for wind power
EMO, AS, load products and Load-Supply following
Wind variability, supplysurplus, ramping events
Predictability of wind powerWind power forecastingrules and requirements
Wind power management, forecasting & Supply Surplus Protocol
Transmission development Transmission plans, NID’s and forecasts of wind projects
Wind interconnection projects Queue management
Cost AllocationLoad
Transmission & Ancillary Services
Wind Facility OwnersForecasting and Power management
18
Wind Generation Planned in 2009/2010
0
500
1000
1500
2000
Q1
-20
09
Q2
-20
09
Q3
-20
09
Q4
-20
09
Q1
-20
10
Q2
-20
10
Q3
-20
10
Q4
-20
10
Timeline
Win
d M
W C
ap
ac
ity
High Probability Wind MW Med Probability Wind MW Low Probability Wind MW
Wind power development (2009-2010)
Additional RegulatingReserves
Wind Power Forecasting, Wind Power Management
Supply Surplus, DDST
19
MOF Recommendation Paper
• Next major step in the implementation of the Market and Operational Framework (MOF)
Represents the culmination of valuable work done through industry work groups.
Provides an overview of the MOF
Describes current system resources and mechanisms used to manage variability and ramps (load and supply) on the power system and challenges with large scale integration
• Provides a set of recommendations regarding enhancements to rules, practices and procedures and requirements needed to implement the MOF:
Wind power forecasting requirements
Wind power curtailment protocol
Supply surplus protocol
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Wind Power Forecasting
John Kehler
21
Wind Forecasting is a Foundation
• To integrate more wind the operator needs to “know what to do” and “have the necessary resources/tools” over all timeframes
• An wind power forecast (including uncertainty) enhances AESO ability to maintain system reliability
• In order to maintain reliability we must learn how to deal with
Forecast errors: timing and magnitude
Forecast uncertainty
• Forecasting enables the efficient use of resources
Time (hour of day)0 4 8 12 16 20 24
Sys
tem
Lo
ad
(M
W)
seconds to minutes
Regulation
tens of minutes to hours
Load Following
day
Scheduling
22
Forecasting
• The biggest challenge to forecasting is to predict when ramping starts and ends
• The benefit, if done well, will allow us to make efficient use of resources to manage the ramps
0
50
100
150
200
250
300
350
Sep06 1
2:0
0
Sep06 1
4:2
4
Sep06 1
6:4
8
Sep06 1
9:1
2
Sep06 2
1:3
6
Sep07 0
0:0
0
Sep07 0
2:2
4
1-min MW
fcst 1
fcst 2
fcst 3
2 hour ahead forecast
23
Ramp Statistics
• In the pilot project the AESO applied a 20% per hour wind capacity criteria to define a wind power ramping event
Pilot Project Results - 234 ramp up/down events
• This metric is not a concern at 545 MW of wind generation
• At higher levels of wind penetration (i.e. 2000 MW +) an event where 20 % of installed wind capacity/hour is ramping will become a significant event depending on when it occurs
A 400 MW/hour in opposition to a typical load ramp will be a significant event
24
Wind forecasting
• Pilot project 3 vendors – ‘AWS Truewind (USA)’,
‘WEPROG (Denmark)’ and ‘energy and meteo (Germany)’– contracted to study wind characteristics and develop methodologies that work for Alberta:
– Ramping – how to detect large ramps
– Uncertainty – how to determine level of uncertainty in forecast
– Facility Owner – define requirements for wind power facility operators
– Regulating Reserves – how to use forecasts to support AS procurement
– Information to Industry – how to provide forecasts to market participants
Plan to have wind power forecasting operational by December 2009
Forecasts Delivered at 12 AM Apr 14
0
50
100
150
200
250
300
350
400
450
500
Apr1400:00
Apr1404:00
Apr1408:00
Apr1412:00
Apr1416:00
Apr1420:00
Apr1500:00
Apr1504:00
Apr1508:00
Apr1512:00
Apr1516:00
Apr1520:00
Aggr
egat
e of
Exi
stin
g Fa
cilit
ies
(MW
)
Actual Wind fcst 1 fcst 2 fcst 3
25
What we learned from the pilot Learning = Opportunity
• Alberta difficult to forecast wind with the forecast errors higher than other jurisdictions
Mountains plus Pacific Ocean to west add complexity and limit upwind data density
Complex weather: Chinooks
• Forecasts need to be tuned for system operator needs
Ramping events – some significant ramp events missed. Of missed events, the down ramps were the most challenging
26
Wind power forecasting recommendations
Recommendation 1
• Centralized forecasting approach
Recommendation 2
• RFP forecasting service provider should proceed as soon as practicable
Recommendation 3
• Commence consultation on rules, procedures, standards and technical requirements regarding submission of wind generator forecast data/information including
data requirement such as turbine availability and on-site meteorological data as described above,
communication protocols, and
data quality required from wind generation facilities (or individual forecasters) to deliver forecasts to the AESO
27
Wind power forecasting recommendations (cont)
Recommendation 4
• Determine the capability, resources, systems and time required to perform the data management function.
In parallel, the AESO will include data management as an optional requirement in the wind forecasting RFP
Recommendation 5
• Monitor forecasting, market and operational results and develop measures of forecasting accuracy.
The AESO intends to leverage available data and forecasting resources toward this end
Recommendation 6
• Aggregate wind forecasts should be transparent and made available to all market participants, particularly near term to real time.
28
Recommendation for centralized forecasting
WPF WPF
WPFWPF
WPF
AESO
Wind Power ForecastService Provider
Meteorological data, MW output
and turbine availability from
each WPF
Data from Numerical Weather Prediction models
(i.e. from Environment
Canada)
Wind Power Forecast data and information to the
AESO
Centralized meaning “one wind power forecasting service provider for all WPFs”
29
WPF forecast data and information
Current MW
Wind Speed
Wind Direction
Barometric Pressure
Wind Power Facility
AESOMet Tower
Temperature
Wind Power Forecaster
MW forecast(s)
Wind Speed
Wind Direction
Pressure
Temp
Me
t D
ata
CurrentTurbine
AvailabilityFuture
TurbineAvailability
Wind Speed
Barometric Pressure
Temperature
Wind Direction
Options discussed for WPF data are:
1) WPF data to Third Party then to Forecaster then to AESO
2) WPF data to AESO then to Forecaster
3) WPF data to Forecaster then to AESO
Preferred options are 2) and 3)
Power Curve for each WPF
30
Possible cost and allocation to WPF owners
• Based on cost experience during the wind power forecasting pilot project, provision of a forecasting services and data management could be less than $500k annually.
Costs borne at a WPF for met towers, data loggers and communication are not considered in this cost.
With 1000 MW of wind power this would be less than $0.20 per MWh of wind power generators
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Wind Power Management
John Kehler
32
The operational issues
• There may be times that the system cannot absorb all the wind generation
• The AESO would first consider the forecast demand, the wind power conditions, forecast wind power and what is available in the energy market for dispatch before resorting to wind power management
To help the system controllers recognize and manage these situations, the AESO is developing a Dispatch Decision Support Tool
• The following conditions could trigger the use of wind power management: Forecast loss of wind and insufficient ancillary services or ramping services
Supply surplus conditions
Insufficient ancillary services
Unforeseen (i.e. not forecasted) wind conditions
Disturbance and emergency conditions
• During over frequency conditions wind power facilities will need to participate in frequency control
33
Wind power managementSystem Operation
There may be times when wind power is forecast to ramp down and dispatching EMMO up may require pre-curtailment of wind generation to ensure supply-demand balance
There may be times when wind power is forecast or is ramping up and limiting wind generation may be required until such time the EMMO can catch up
34
The operational issue
7am Forecasts on [2007/09/05] for Next Day
0
50
100
150
200
250
300
350
400
450
500
Sep05 19:12
Sep06 00:00
Sep06 04:48
Sep06 09:36
Sep06 14:24
Sep06 19:12
Sep07 00:00
Sep07 04:48
Pre-7AM F1
Pre-7AM F2
Pre-7AM F3
Actual Wind
0
50
100
150
200
250
300
350
Sep06 12:00
Sep06 14:24
Sep06 16:48
Sep06 19:12
Sep06 21:36
Sep07 00:00
Sep07 02:24
1-min MW
fcst 1
fcst 2
fcst 3
Day ahead forecasts miss the event
2 hour ahead forecast miss the event
System Operator would determine how much wind MW the system can accommodate.
Then issue a power limit
Actual MW
Forecast MW
Unforeseen Wind Power Event
35
WPM recommendations
• Pro-rata allocation of system wide wind curtailments;
• Use of Potential MW Capability to allocate wind power curtailments; and,
• Curtailments should be re-assessed and re-allocated:
– every 20 minutes if the limit for any one WPF has changed by greater than 5 MW
36
Description of potential MW capability
Measured windspeed and
directionLocal computer
calculatesPotential MW
from the turbine
WPF SCADASystem collectsand sums thePotential MW
from all turbinesat the WPF
Utility SCADAsystem sends
data to theAESO
37
Illustrative Example of WPM
Start of System Wind Limit event
WPF limits based on current wind power conditions at the time limit is issued
WPF limits re-allocated as Potential MW Capability changes
Potential MW Capability Wind Power generated
End of System Wind Limit event
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Supply and Surplus
Anita Lee, P. Eng.
Manager, Operating Policies and Procedures
39
Supply and surplus
• Wind generators and co-generation are currently exempt from OPP 103 (Dispatching Multiple $0 Offers) for managing supply surplus conditions
• The MOF clearly indicated that, with higher levels of wind generation, the existing supply surplus management protocol needed to be reviewed
40
Supply and surplus
• WG recommendation: Market be first given an opportunity to take voluntary actions when $0 SMP is anticipated or is occurring
• Required changes: Provide market indication of potential supply surplus conditions,
similar to Short Term Adequacy (STA) assessments for supply shortfall
41
Supply and surplus
• WG recommendation: all supply facilities should participate in reducing MW generation during supply surplus conditions subject to a new “Minimum Operating Level (MOL)”
• Required changes: Define MOL as:
A physical, not an economic constraint, and is
The lowest generation level for a generator as limited by the following requirements: legal/regulatory, environmental, health and safety, equipment reliability, operating level required to serve dispatched ancillary services, or operating level required to prevent damages to third party equipment
42
Supply and surplus
• Required changes (cont’): Define a mechanism/process for pool participants to declare and
submit the MOL
Revise the "inflexible block" current definition to permit partial dispatch of a $0 inflexible offer
Wind generators: MOL = 0 MW and is flexible
43
Supply and surplus
WG recommendation: $0 SMP Management Protocol
1. Curtail import transactions
2. Considering transmission system operating and reliability constraints (area TMR requirements, etc), apply the following, if effective*:
• Curtail flexible $0 blocks, by pro-rata**
• Curtail one or more inflexible $0 blocks to the asset’s MOL***
3. Curtail one or more assets to 0 MW (go off line), considering the asset’s minimum off time
44
Supply and surplus
*Consideration for “effectiveness”: If curtailment allocation by pro-rata results in small volumes of
curtailment to a large number of generating assets, it may not be effective.
This issue will be explored in the development of the related OPP.
45
Supply and surplus
**Consideration for “fairness”: Flexible blocks and inflexible blocks should be used in the protocol
in a fair manner (i.e. one type should not be treated preferentially than the other)
46
Supply and surplus
***Consideration for impact to a co-gen’s DTS contract: If the generation at a co-gen facility is curtailed (e.g. to its MOL),
the co-gen facility may have to import more supply from the AIES causing ratcheting of its contracted DTS level
This requires further evaluation and if there are inappropriate consequences, the AESO may consider amendments to the AESO tariff
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Technical Requirements/Standards
John Kehler
48
Technical requirement standards
• Interconnection Standards In Nov 2004, AESO developed and
implemented an interconnection standard specific for wind power facilities
Standard includes voltage ride through (low and high voltage), static and dynamic reactive power and voltage regulation
Standards will be updated to include:
– Wind Power Management (ramp rate limiting, power limiting and over frequency governing)
– SCADA and Communication requirements for Wind Power Management
– Requirements for Wind Power Forecasting
49
Over frequency control
• Over frequency conditions can occur in Alberta when; Our interconnections trip during a heavy export
Disturbances within WECC
• Arresting the over frequency condition requires governor control systems on the generator units
• To ensure that wind power facilities contribute to arresting an over frequency condition, a virtual governor (over frequency control) is to be added to the wind power facilities.
• Significant over frequency conditions (greater than 60.1 Hz) can occur a couple times per year
• This requirement was identified in the 2004 standard
50
Illustration of Over Frequency Control
Time
Win
d P
ower
MW
Unconstrained Wind MW
Wind MW with Supplemental OverFrequencyOver Frequency Excursion
Illustrative Over Frequency Event
Over frequency control
• Reduce the MW output to ‘over frequency’ conditions
51
Over frequency control
• System frequency can momentarily go above 60.036 Hz 2008 data suggests
– 5% probability between 60.036 Hz and 60.1 Hz
– 0.01% above 60.1 Hz
Based on the proposed droop characteristic for WPFs this would have been less than 0.02% production in 2008.
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System Operator Tools
John Kehler
53
Supply-demand balancing inputWhat is changing?
How good is the load forecast today?
How good is the load forecast today?
What is the wind power forecast? What is the ramp rate?
What is the wind power forecast? What is the ramp rate?
What are the Interconnection schedules?
What are the Interconnection schedules?
What is the load forecast change? What is the ramp rate?
What is the load forecast change? What is the ramp rate?
How good is the wind power forecast today?
How good is the wind power forecast today?
Net ChangeRamp rate requirement
Is the merit order changing?
Is the merit order changing?
What generators are still ramping from the last dispatch? How much energy is still to come?
What generators are still ramping from the last dispatch? How much energy is still to come?
54
Supply-demand balancingDispatch decision
What are the Regulating Reserve units doing?
What are the Regulating Reserve units doing?
What is the ramp rate capability in the merit order over the next 10, 20, 30 minutes?
What is the ramp rate capability in the merit order over the next 10, 20, 30 minutes?
How much capacity to dispatch to get the required ramp
rate?
How much capacity to dispatch to get the required ramp
rate?
Do I need to dispatch more ancillary services?
Do I need to dispatch more ancillary services? Will I need to
activate any Wind Power Management procedures?
Will I need to activate any Wind Power Management procedures?
Dispatch Decision
Will I need to activate Supply Surplus / Shortfall procedures?
Will I need to activate Supply Surplus / Shortfall procedures?
55
Repeat when necessary
What are the Regulating Reserve units doing?
What are the Regulating Reserve units doing?
What is the ramp rate capability in the merit order over the next 10, 20, 30 minutes?
What is the ramp rate capability in the merit order over the next 10, 20, 30 minutes?
How much capacity to dispatch to get the required ramp
rate?
How much capacity to dispatch to get the required ramp
rate?
Do I need to dispatch more ancillary services?
Do I need to dispatch more ancillary services? Will I need to
activate any WPM procedures?
Will I need to activate any WPM procedures?
Dispatch Decision
Will I need to activate Supply Surplus / Shortfall procedures?
Will I need to activate Supply Surplus / Shortfall procedures?
56
System operator tools
• Dispatch Decision Support Tool (NEW) Provide visibility of capacity and ramping
capability of the energy market Incorporate wind power forecasting Provide hourly and 6 hour outlook on market
conditions (including wind) Prototyping/testing with operators
• Wind Power Forecasting Tool (NEW) Incorporate requirements from the wind power
forecasting pilot project
• Wind Power Management Tool (NEW) Automate the wind power management protocol
and procedures (limits or ramp rate limiting)
• Supply Surplus Tool (update existing tools) Automate the supply surplus protocol and
procedures
• Short Term Adequacy Tool (update existing tools)
57
Functionality of DDST
Resources• Energy Market Merit Order
• Generator ramping characteristics
• Regulating reserve merit order
• Load Supply Following (future)
• Wind Power Management (new)
What Is Going to Change
System Change• Load forecast
• Actual and forecast Interchange Schedules
•3 Modes for Wind power forecast
•Input External Wind Power Forecast
•Persistence Forecast
•Persistence Ramp Forecast
System Considerations• ATC Limits
• Uncertainty Analysis
Where We Are At
System Status• What supply has been dispatched
• What is the Actual generator output
Heart of DDSTProvide 1 hr forecast of supply
demand balance and a6 hr outlook
What If?
System Control can toggle up and down
the merit order to see the impact of the dispatch on the
forecast imbalance
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Update on Key Initiatives and Next Steps
Warren Frost, P. Eng.
Vice President, Operations & Reliability
59
Transmission is a key enabler
• Transmission and intertie capacity are critical enablers for the development of wind generation resources in order to
Interconnect variable energy resources located in remote regions of the province
Deliver ramping and ancillary services from inside and outside Alberta to balance supply and demand
Exchange any surplus energy with other jurisdictions.
• Direction is consistent with the PES (announced in December 2008), which sets the context for comprehensive upgrades to the transmission system
Develop transmission to areas of renewable and low-emission energy
Ddevelop additional interties to ensure access to adequate electricity supply and to provide great export opportunities for producers
• AESO has advanced plans for the south region of the province to accommodate the large scale development of wind generation
60
Wind capacity and generation scenarios
1000
1500
500
2008 2009 2010 2011 2012 2013 2014 2015 2016
2000
2500
3000
3500
4000
2017
61
Transmission development to interconnect wind generation
SW Facilities Application• AUC approved AltaLink’s application March 10• 240 kV Pincher Creek to Lethbridge• Interconnect 1000 MW of wind
South NID• AUC filed Notice of Hearing March 9• 240 kV loop to interconnect up to 2,700 MW of
wind over next 10 years
East Central Alberta (Hanna area) • Consultation on need underway (10 Open
Houses recently completed)• Interconnect 1,400 MW of wind
•Interconnection Queue Management• Strong interest in wind development – over
12,000 MW in the queue• Queue Management Business Practice and
associated project milestones ensure that projects are progressing
62
Summary and next steps
• Recommendation Paper & Comment Matrix posted to AESO website – March 5
• Stakeholder Consultation Session – March 23
• Deadline for stakeholder comments on the paper – April 3
• AESO publishes stakeholder comments received to website – April 17
• Final Recommendation Paper posted to AESO website (includes stakeholder comments & AESO responses) – Q2 2009
• First Phase of System Operator Tools Operational – Q2 2009
• Wind Power Forecasting RFP Issued – 2Q 2009
• Consultation on proposed ISO and OPP Rule changes indicated in the Final Recommendation Paper Forecasting Obligations Wind Power Management Supply Surplus Protocol
• File with AUC, rules, operating policies and procedures that govern the integration of wind integration including wind power management, forecasting obligations, and supply surplus conditions – Fall 2009
63
Process
Comments on
Recommendation paper
Post comments
Post final recommendations
Develop Draft rule/OPPs
Post Draft rule/OPPsfor review
Post comments
Post final rule/OPPs
Approve and file with AUC
64
Next steps
65
Summary
• 543 MW on AIES without operational issues or increase in AS There has been no requirement to increase Regulating Reserves volumes System performance is good (CPS2 at 98% and no OTC violations) This is consistent with our study results from 2005
• Gaining experience (ISO and industry) and learning from events Collaborative relationship with CanWEA has been invaluable Weekly wind reports published and continuous learning NERC IVGTF Continued collaboration with UWIG
• We must be prepared for the large scale integration of wind
• This is the next major step in the implementation of the Market and Operational Framework (MOF)
Need your input on the recommendations regarding enhancements to rules, practices and procedures and requirements needed to implement the MOF:
– Wind power forecasting requirements
– Wind power curtailment protocol
– Supply surplus protocol
66
Questions