Transcript PowerPoint template draft - Alberta Electric System Operator

Reliable Power
Implementation of Market &
Operational Framework for Wind
Integration
Reliable Markets
Stakeholder Information Session
Monday, March 23, 2009
Metropolitan Centre, Calgary
Reliable People
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
2
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
3
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
4
Alberta’s electric industry
• 9,806 MW peak and 80% LF
• 12,159 MW total generation
5,893 MW
4,686MW
(Wind)
497 MW
(Other renewables)
214 MW
869 MW
• Over 280 generating units
• Wholesale market with about
200 market participants
BC
Alta
Sask
• > 21,000 km of transmission
• Interties BC (up to 780 MW) &
Sask. (up to 150 MW)
Over 12,000 MW of
Wind Power Interest
5
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
6
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
7
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 derates
• 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!
8
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
Supply
Demand
• Limits to how much wind a
system can accommodate –
• Market Impacts – can increase
variability and uncertainty
• Need Transmission – upgrades in
southern part of the province and
recognizing diversity
320
8500
240
8000
160
7500
80
7000
System Wind Power
MW
9000
0
Time - 1 Hr per Division
Alberta System Demand and Wind Power
Do Not Correlate Well Jan 6, 2006
9000
320
8500
240
8000
160
7500
80
7000
System Wind Power
MW
need mitigating measures, resources
and the scale/costs can escalate
System Demand MW
• Reliability issues > 900 MW –
Alberta System Demand and Wind Power
Correlated Well Nov 6 2006
System Demand MW
need access to flexible resources
considering physical limits (ramping
and start up times)
0
Time - 1 Hr per Division
9
Need dispatchable resources to
accommodate wind
Market Capability
Above Baseload
Amount of dispatchable
generation varies according to
market conditions
Baseload
Generation
$0 Offers
10
Wind power diversity and ramps
In Alberta there are times when
there is diversity amongst wind
power facilities
There are times when there is little
to no diversity amongst wind power
facilities
11
Correlation between pool price and
wind power
•
Wind generation offers
into the market at zero
dollars
Wind vs. Pool Price
Average Pool Price for Varying Amounts of Wind
•
Pool price tends to be
lower when there is a
significant amount of
wind generation
Three factors influencing
wind project
development
100
90
Average Pool Price ($/MWh)
•
80
Pool price
2.
Federal incentives
3.
Environmental attributes
Annual Average
Pool Price: $66.95
$83.78
70
60
$61.85
$56.78
50
$45.19
40
$44.43
30
20
10
0
0MW to 100MW
1.
2007 Data
100MW to 200MW
200MW to 300MW 300MW to 400MW
400MW to 500MW
Range of Hourly Wind Generation
12
Wind power capacity factors


•
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
60%
Capacity factor by month*
Annual average Capacity factor
50%
40%
30%
20%
10%
0%
Jan
Percentage of Time at a Given Output Level
•
Over 1,400 GWh of electric
energy and annual capacity
factor of about 35 % in 2007
Capacity factors of wind
power
Capacity factor
•
Alberta wind power generated 1431 GWh of electricity energy in 2007
Feb
60%
Mar
Apr
May
Jun
Jul
Aug
Sep
Oct
Nov
Dec
Spain Wind Power Distribution
(2001 – 2005)
50%
40%
30%
20%
10%
0%
20%
30%
40%
50%
60%
70%
80%
Total Wind Generation Output
90%
100%
13
AESO’s wind integration journey
2003
2004
2005
New
Standard
specific for
Wind Power
Facilities
2007
AESOCANWEA
collaboration
Phase 1
Study
Study 1200
MW of Wind
Power
2006
Study up to
2000 MW
Initiate Wind
Power
Forecasting
Pilot
Confirms need
for Mitigating
Measures
PH II Study
and
Temporary
Threshold
Confirm
effectiveness
of Mitigating
Measures
2008
Workgroups
on Supply
Surplus and
Wind Power
Management
Market and
Operational
Framework
(MOF)
introduced
2009
Implement MOF
Recommendations
Workgroup findings
incorporated into
paper
Finalize
Forecasting
Pilot
CanWEA Award
UWIG Award
14
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.”
15
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
16
Challenges and solutions
CHALLENGES
MOF SOLUTIONS
Predictability of wind power
Wind power forecasting
rules and requirements
Flexible Resources for
wind power
EMO, AS, load products and
Load-Supply following
Wind variability, supply
surplus, ramping events
Wind power management,
forecasting & Supply Surplus Protocol
Transmission development
Transmission plans, NID’s and forecasts
of wind projects
Wind interconnection projects
Queue management
Cost Allocation
Transmission & Ancillary Services
Load
Wind Facility Owners
Forecasting and Power management
17
Wind power development (20092010)
Wind Generation Planned in 2009/2010
1500
1000
500
Q4-2010
Q3-2010
Q2-2010
Q1-2010
Q4-2009
Q3-2009
Q2-2009
0
Q1-2009
Wind MW Capacity
2000
Timeline
High Probability Wind MW
Med Probability Wind MW
Low Probability Wind MW
Additional Regulating
Reserves
Wind Power Forecasting,
Wind Power Management
Supply Surplus, DDST
18
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
19
Reliable Power
Wind Power Forecasting
Reliable Markets
John Kehler
Reliable People
• 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
System Load (MW)
Wind Forecasting is a Foundation
0
• In order to maintain reliability we
must learn how to deal with
 Forecast errors: timing and
magnitude
seconds to minutes
Regulation
4
8
Time (hour of day)
16
12
20
24
tens of minutes to hours
day
Load
Following
Scheduling
 Forecast uncertainty
• Forecasting enables the efficient
use of resources
21
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
350
300
1-min MW
250
f cst 1
200
f cst 2
f cst 3
150
100
50
0
Sep07 02:24
Sep07 00:00
Sep06 21:36
Sep06 19:12
Sep06 16:48
Sep06 14:24
Sep06 12:00
2 hour ahead forecast
22
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
23
Wind forecasting
• Pilot project
– 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
Forecasts Delivered at 12 AM Apr 14
Aggregate of Existing Facilities (MW)
 3 vendors – ‘AWS Truewind (USA)’,
‘WEPROG (Denmark)’ and ‘energy
and meteo (Germany)’– contracted
to study wind characteristics and
develop methodologies that work for
Alberta:
500
450
Actual Wind
fcst 1
fcst 2
fcst 3
400
350
300
250
200
150
100
50
0
Apr14 Apr14 Apr14 Apr14 Apr14 Apr14 Apr15 Apr15 Apr15 Apr15 Apr15 Apr15
00:00 04:00 08:00 12:00 16:00 20:00 00:00 04:00 08:00 12:00 16:00 20:00
 Plan to have wind power forecasting
operational by December 2009
24
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
25
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
26
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.
27
Recommendation for centralized
forecasting
Centralized meaning “one wind power forecasting
service provider for all WPFs”
Wind Power
Forecast data and
information to the
AESO
Wind Power Forecast
Service Provider
WPF
AESO
WPF
WPF
WPF
WPF
Meteorological
data, MW output
and turbine
availability from
each WPF
Data from
Numerical Weather
Prediction models
(i.e. from
Environment
Canada)
28
WPF forecast data and information
Met Tower
Met Data
MW forecast(s)
Wind Speed
Wind Speed
Wind Direction
Wind Direction
Barometric Pressure
Barometric Pressure
Pressure
Temperature
Temperature
Temp
Wind Power
Facility
Wind Power
Forecaster
Wind Speed
Wind Direction
AESO
Current MW
Current
Turbine
Availability
Future
Turbine
Availability
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
Power Curve for
each WPF
3) WPF data to Forecaster then to AESO
Preferred options are 2) and 3)
29
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
30
Reliable Power
Wind Power Management
Reliable Markets
John Kehler
Reliable People
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
32
Wind power management
System 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 supplydemand 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
33
The operational issue
System Operator would determine how much wind MW
the system can accommodate.
Unforeseen Wind
Power Event
Then issue a power limit
7am Forecasts on [2007/09/05] for Next Day
Pre-7AM F1
Actual
MW
Pre-7AM
F2
500
450
300
Pre-7AM F3
Forecast
MW
Actual Wind
400
350
1-min MW
250
fcst 1
200
fcst 2
350
300
250
fcst 3
150
200
100
150
50
100
50
0
Sep07 02:24
Sep07 00:00
Sep06 21:36
Sep06 19:12
Sep06 16:48
Sep06 14:24
Sep07 04:48
Sep07 00:00
Sep06 19:12
Sep06 14:24
Sep06 09:36
Sep06 04:48
Sep06 00:00
Sep05 19:12
Day ahead forecasts miss the
event
Sep06 12:00
0
2 hour ahead forecast miss the event
34
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
35
Description of potential MW
capability
Local computer
calculates
Potential MW
from the turbine
WPF SCADA
System collects
and sums the
Potential MW
from all turbines
at the WPF
Measured wind
speed and
direction
Utility SCADA
system sends
data to the
AESO
36
Illustrative Example of WPM
Start of
System Wind
Limit event
End of
System Wind
Limit event
WPF limits
based on
current wind
power
conditions at
the time limit
is issued
WPF limits reallocated as
Potential MW
Capability
changes
Potential MW Capability
Wind Power generated
37
Reliable Power
Supply and Surplus
Reliable Markets
Anita Lee, P. Eng.
Reliable People
Manager, Operating Policies and Procedures
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
39
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
40
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
41
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
42
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
43
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.
44
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)
45
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
46
Reliable Power
Technical
Requirements/Standards
Reliable Markets
John Kehler
Reliable People
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
48
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
49
Over frequency control
Wind Power MW
• Reduce the MW
output to ‘over
frequency’ conditions
Illustration of Over Frequency
Control
Illustrative Over
Frequency Event
Time
Unconstrained Wind MW
Wind MW with Supplemental Over
Frequency
Over Frequency Excursion
50
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.
51
Reliable Power
System Operator Tools
Reliable Markets
John Kehler
Reliable People
Supply-demand balancing input
What is changing?
What is the
load forecast
change? What
is the ramp
rate?
How good is
the load
forecast
today?
What are the
Interconnection
schedules?
What generators
are still ramping
from the last
dispatch? How
much energy is
still to come?
Is the merit
order
changing?
How good is
the wind
power
forecast
today?
Net Change
Ramp rate requirement
What is the
wind power
forecast?
What is the
ramp rate?
53
Supply-demand balancing
Dispatch decision
What is the ramp
rate capability in
the merit order
over the next 10,
20, 30 minutes?
What are the
Regulating
Reserve
units doing?
Do I need to
dispatch more
ancillary
services?
How much
capacity to
dispatch to get the
required ramp
rate?
Will I need to
activate any
Wind Power
Management
procedures?
Will I need to
activate Supply
Surplus /
Shortfall
procedures?
Dispatch Decision
54
Repeat when necessary
What
Whatisisthe
theramp
ramp
rate
ratecapability
capabilityinin
the
merit
order
the merit order
over
overthe
thenext
next10,
10,
20,
20,30
30minutes?
minutes?
What
Whatare
arethe
the
Regulating
Regulating
Reserve
Reserveunits
units
doing?
doing?
Do
DoI Ineed
needto
to
dispatch
dispatchmore
more
ancillary
ancillary
services?
services?
How
Howmuch
muchcapacity
capacity
to
todispatch
dispatchto
toget
get
the
required
the requiredramp
ramp
rate
rate??
Will
WillI Ineed
needto
to
activate
activateany
any
WPM
WPM
procedures?
procedures?
Will
WillI Ineed
needto
to
activate
activateSupply
Supply
Surplus
Surplus/ /Shortfall
Shortfall
procedures?
procedures?
Dispatch Decision
55
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)
56
Functionality of DDST
Resources
• Energy Market Merit Order
Where We Are At
What Is Going to Change
System Status
System Change
• Generator ramping characteristics
• What supply has been dispatched
• Load forecast
• Regulating reserve merit order
• What is the Actual generator output
• Actual and forecast Interchange Schedules
•3 Modes for Wind power forecast
• Load Supply Following (future)
•Input External Wind Power Forecast
• Wind Power Management (new)
•Persistence Forecast
•Persistence Ramp Forecast
What If?
System Control can
toggle up and down
the merit order to see
the impact of the
dispatch on the
forecast imbalance
Heart of DDST
Provide 1 hr forecast of supply
demand balance and a
6 hr outlook
System Considerations
• ATC Limits
• Uncertainty Analysis
57
Reliable Power
Update on Key Initiatives and
Next Steps
Reliable Markets
Warren Frost, P. Eng.
Reliable People
Vice President, Operations & Reliability
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
59
Wind capacity and generation
scenarios
4000
3500
3000
2500
2000
1500
1000
500
2008
2009
2010
2011
2012
2013
2014
2015
2016
2017
60
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
61
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
62
Process
Comments on
Recommendation paper
Post Draft rule/OPPs
for review
Post comments
Post comments
Post final recommendations
Post final rule/OPPs
Develop Draft rule/OPPs
Approve and file with AUC
63
Next steps
64
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
65
Questions
66