Spring 2018 IESO Operations Outreach "Integration" - June 2018
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Spring 2018 IESO Operations Outreach
“Integration”
June 2018
Agenda
Time Agenda Item Responsible Party Expected Actions
8:45am Coffee
9:15am Opening/Welcome Remarks Dave Devereaux Information
9:20am Operations Update Pedro Rebellon Information and
• Review of Winter Operations Discussion
• Ice Storm Preparation
• Summer Outlook
09:50am Break
10:00am Quarterly Outage Assessments Joseph Ricasio Information and
Discussion
10:25am Market Update Jessica Tang Information and
• Review of Price Spikes Discussion
• 30 Minute Reserve for Flexibility
10:40am Break
10:55am New Technology Diljeet Singh Information and
Discussion
11:10am Integrating New Facilities / Equipment Samuel Jager Information and
Bryan Hartwell Discussion
11:40am Closing Remarks Dave Devereaux Information
2
Spring 2018 IESO Operations Outreach Operations Integration Update Pedro Rebellon Engineering Manager Operations Planning June 20, 2018
Presentation Outline
• Winter 2017-2018 Review
– Winter colder than usual, increased reliance on gas resources;
• April 2018 Ice Storm Review
– Forecast, anticipated impact, integration to secure power system
– Preparations showed value – limited impact on load/generation
• 2018 Summer Outlook
– Reliability Outlook remains positive for Summer 2018
Positive outlook is the result of the consistent effort and contribution
by all stakeholders – thank you!
4
Winter 2017-2018 Review
5
Energy Adequacy Assessment Winter 2017-18
Source: 18-month Outlook, October 2017-March 2019
Winter 2017-18 forecast showed sufficient energy supply for the firm scenario
Integration of gas units ensured availability and operability
6
Generator Output by Fuel – Monthly Report
Source: IESO Web Site Public Reports
Winter 2017-18 colder than usual; integration of higher
demand and more reliance on gas-fired resources 7
April 13-16 2018 Ice Storm Review
8
Ice Effects on Power System Equipment
• Ice build-up on insulators increases risk of
outages due to flashover, exacerbated by
high contamination levels;
• Ice accumulation on overhead conductors
may lead to catastrophic failure of poles,
line towers and structures;
• Possible consequences:
– Pole damage, permanent faults;
– Flashover/trip of multiple circuits,
entire switchyards and stations;
– Widespread load/generation loss
Ice may impact multiple
elements and facilities, well
beyond power system
design criteria
9
April 2018 Ice Storm Forecast and Outcome
Weather Forecast Fri 13 - Mon 16 Weather summary for Ontario and the national capital
April 2018: region issued by Environment Canada at 4:57 p.m. EDT
Monday 16 April 2018:
Strong winds, heavy rain, ice pellets, A major winter storm struck Southern Ontario over the
up to 30 mm freezing rain; storm moving weekend seriously affecting travel and causing numerous
from Southwest to Eastern Ontario; power outages due to falling trees and wires. Here is a
summary of the weather that the storm has produced in
some places. Total precipitation amounts are from early
Saturday morning until 2 pm this afternoon.
• Toronto: 18 hours of ice pellets, 6 hours of freezing
rain, packed ice pellet depth 7 to 12 cm. Winds
gusted as high as 96 km/h
• Ottawa: 9 hours freezing rain Sunday and 6 hours
freezing rain today; winds gusts of 60 to 70 km/h
• Hamilton: 11 hours of ice pellets Saturday, 6 hours
of ice pellets mixed with freezing rain Sunday, then
8 hours of freezing rain. Winds gusts to 87 km/h
Sunday afternoon. Maximum packed ice pellet depth
15 cm.
• London: 14 hours of freezing rain mixed with ice
pellets;
• Windsor: 6 hours of freezing rain
10Integration to Secure Power System
Storm Preparation Actions Stakeholders
Cancelled outages planned for the weekend Generators, transmitters, loads
Recalled ongoing outages of major transmission circuits Transmitters
Committed additional generation resources and staffing Generators
Confirmed gas supply availability, return units on outage Gas transmitters, generators
Coordinated assistance with neighboring jurisdictions Reliability Coordinators
Verified insulator contamination levels at various stations Transmitters
Improved safe posture limits to preserve energy in
Generators, transmitters
Northeast and Northwest regions of Ontario
Increased operability posture (FETT interface) Generators, transmitters
Informed Crisis Management Support Team (CMST) CMST
Storm preparations proved valuable, storm impact on
load and generation was limited and contained
11Impact of April 2018 Ontario Ice Storm
More than twenty 115 & 230 kV circuit trips, mostly
caused by high winds and galloping conductors
earlier in the storm; several structures damaged;
After the ice storm was over, heavy rain caused a
roof leak at a major transformer station, leading to
more trips of transmission circuits;
Near 400 MW total cumulative load loss
Significant impact
on wind turbines
due to blade icing,
causing unplanned
power derates and
shutdowns
Ice accumulation on towers and conductors less than forecasted;
some evidence ice buildup varied depending on elevation 12Summer 2018 Outlook
13Summer 2018 Weather Forecast
Summer weather
forecast: above
normal
Severe weather forecast:
hotter and drier than
usual in some regions
14Reserve Above Requirements
Source: IESO 18-month Outlook Jul 2018 – Dec 2019
Reserve Above Requirement = Available Resources – (Demand + Required Reserve)
10,000
Reserve Above Requirement [MW]
8,000 Firm Scenario
Normal Weather
6,000
4,000
2,000
0
Firm Scenario
-2,000 Extreme Weather
-4,000
01 Jul 2018 16 Sep 2018 02 Dec 2018 17 Feb 2019 05 May 2019 21 Jul 2019 06 Oct 2019 22 Dec 2019
Week Ending
Reserves are at or above requirement for Summer 2018
15Forecast peak demand Summer 2018
Source: IESO 18-month Outlook Jul 2018 – Dec 2019
Season Normal Weather Peak (MW) Extreme Weather Peak (MW)
Summer 2018 22,076 24,535
Winter 2018-19 21,328 22,235
Summer 2019 22,016 24,460
Year Normal Weather Energy (TWh) % Growth in Energy
2015 136.2 -1.9%
2016 136.2 0.0%
2017 132.3 -2.8%
2018 (Forecast) 133.7 1.0%
2019 (Forecast) 134.0 0.3%
Summer Peak 2018 Winter Peak 2019 Summer Peak 2019
Notes Description Firm Planned Firm Planned Firm Planned
Scenario Scenario Scenario Scenario Scenario Scenario
1 Installed Resources (MW) 37,044 37,060 36,922 37,998 36,866 38,396
2 Total Reductions in Resources (MW) 12,122 12,127 10,449 10,461 10,254 10,722
3 Demand Measures (MW) 630 630 793 793 533 533
4 Firm Imports (+) / Exports (-) (MW) -102 -102 -500 -500 0 0
5 Available Resources (MW) 25,451 25,462 26,766 27,830 27,144 28,207
Sufficient resources for the firm scenario peak demand, with no anticipated
reliance on support from external jurisdictions
16Energy Adequacy Assessment Summer 2018
Source: IESO 18-month Outlook Jul 2018 – Dec 2019
Sufficient energy supply for the firm scenario, with no anticipated reliance on support
from external jurisdictions
17Reliability Outlook remains positive for
Summer 2018
Sufficient capacity and energy supply, with no anticipated
reliance on support from external jurisdictions
Reserves are at or above requirement for Summer 2018
Natural gas storage levels expected to be adequate; gas-fired
generating units demonstrated unit readiness; gas-electric
coordination meeting held in May 2018
If extreme weather conditions occur, the IESO may reject some
generator maintenance outages to ensure that Ontario demand
is met during the summer peak
Positive outlook is the result of the consistent effort and contribution
by all stakeholders – thank you!
18Thank You!
19Spring 2018 IESO Operations Outreach The Growing Significance of an earlier Operating Plan Joseph Ricasio Senior Power System Specialist, Operations Planning June 20, 2018
Reliable operations of the Ontario grid
benefits from a good operating plan.
Together, we have, and will continue to
strive for a good operating plan.
21Agenda
1. What is a good operating plan?
2. Why an earlier operating plan?
3. How we establish an early operating plan?
4. Example of how we benefitted
22What is a reliable Operating Plan?
Adequacy: The ability of the power system to provide
sufficient capacity and energy to meet demand, and have
sufficient transmission to deliver supply to connected
loads.
Security: The ability of the power system to withstand
reasonably foreseeable contingencies, and not result in
instability, uncontrolled separation, or cascading
outages.
23Why Operating Plan is more significant now?
Ontario system is aging and changing
• Significant upgrades to Transmission Stations
• Nuclear refurbishment & retirements
• Changing supply mix
Demands an earlier Operating Plan
• Market participants (MPs) benefits from earlier certainty
• Outage assessments will require longer lead time due to
complexity of unique or unfamiliar scenarios
• Earlier outage facilitation will help reduce and simplify
out-of-scope scenarios
24Agenda
1. What is a good operating plan?
2. Why an earlier operating plan?
3. How we establish an early operating plan?
4. Example of how we benefitted
25Outage Management System Redesign (OMSR)
Considerations
• More uncertainty the further out an assessment is
conducted.
• More time spent on assessment if assumptions change.
Therefore, assessment is ideally not as comprehensive.
• Quarterly advanced approval is meant for outage plans
that ensure a high certainty of a reliable Operating Plan
(i.e. pre-studied scenarios).
26Adequacy: Normal to Extreme Weather Criteria
Reserve Above Requirement (RAR) = Available Resources - (Demand + Required Reserve)
10,000
8,000 Firm Scenario
Normal Weather Firm Scenario
6,000 Extreme Weather
RAR [MW]
4,000
2,000
0
-2,000
-4,000
01 Jul 2018 16 Sep 2018 02 Dec 2018 17 Feb 2019 05 May 2019 21 Jul 2019 06 Oct 2019 22 Dec 2019
Week Ending
Considerations
• Extreme criteria will impact generator (and possibly
transmission) requests in the Summer.
• 2000MW for Extreme imports is assumed if this is
achievable.
27Security: Outage Conflict Checker (i.e. Matrix)
Rule Name Element List Threshold Reason
Circuit A
West Region Circuit B 1 Thermals
Circuit C
Considerations
• If outage plan is within Outage Matrix, high certainty
that outage plan is approved.
• Exceptions for outage combinations that are
unavoidable (e.g. clearance).
• Dynamic outage guide – relax the rule if too restrictive,
and add a rule if found to be a reliability concern.
28Agenda
1. What is a good operating plan?
2. Why an earlier operating plan?
3. How we establish an early operating plan?
4. Example of how we benefitted
29Background of Operating Plan Example
Flow East Toward Toronto
(FETT):
Consists of 4 500kV circuits
and 6 230kV circuits
Outage request:
Multiple non-recallable
generation outage East of
FETT
Study findings:
Insufficient generation to
address re-prep limit and
reserve requirements
30Lessons Learned from Operating Plan Example
Adequacy: Imports
assumption could be
impacted (Michigan &
New York bottled)
Security: FETT
transmission vs East of
FETT generation
Need to adapt and
prepare to new future
(i.e. reoccurring scenario)
31Benefits of looking ahead
More time spent on
complex outage
combination, and resulted
in a good operating plan
Outage plans salvaged (e.g.
reschedule and re-scoping)
instead of rejection
Additional improvements
will be applied prior to next
set of outage plans
32Continue to improve the Operating Plan
Resource &
Study & MP Long
Transmission
Matrix Term
Planning
Updates Coordination
Coordination
33Summary
1. What is a good operating plan? Acceptable
adequacy, security, and operability.
2. Why an earlier operating plan? System is aging,
and many complex non-recallable long-term critical
outages underway.
3. How we establish an early operating plan?
Added up to 7 months of early assessment, greater co-
ordination, & outage conflict checker.
4. Example of how we benefitted. More time spent
on assessment and co-ordination resulted in:
– Earlier certainty, and salvaging of outages.
– A good integrated operating plan.
34Questions?
35Market Update Jessica Tang Operational Assessments, IESO
RESERVE FOR FLEXIBILITY
37 37Some Factors Affecting Need for Flexibility
VG may be Potential for
providing requiring more
VG Forecast
flexibility flexibility
Committed
Potential for
resources may be
requiring more
providing
flexibility
flexibility
Demand Forecast
38Enabling System Flexibility
• The proposed solution was to increase the 30-minute OR
requirement to indicate the need for flexibility to the
market.
• The solution leverages off existing market processes, and
may meet the need for flexibility by scheduling or
committing additional resources as required.
39Enabling System Flexibility
• The process to increase the 30-minute OR requirement
for flexibility was implemented on May 23rd, 2018.
• An Advisory Notice is issued when the 30-minute OR
requirement is increased for flexibility, and the increase
is also reflected through the Total Operating Reserve
Requirement amount in the Adequacy Report.
40New Technology Integration Diljeet Singh Market & Technology Integration, IESO
Agenda
• IESO Operations Update - MTI
• Energy Storage – Background
• Energy Storage – Operational Challenges
• Grid-LDC Interoperability Standing Committee
Update
42Market & Technology Integration (MTI)
• Need for a dedicated unit within Operations to facilitate
transition of projects/products/services from innovation
to operational stage
• MTI – a new team created within Operations to
champion the following:
– Assess and anticipate potential impacts of changing power system
markets and technology on Operations
– Enable seamless integration of these changes into IESO administered
markets (IAM) and system operations (via tools, processes, & staff
training)
– Leverage opportunities from and manage risks of these changes to
ensure efficient execution of IAM and effective system operations
43IESO’s Energy Storage Portfolio (110.5 MW capacity
procured as of April 2018)
44Energy Storage Procurement & Timeline
2012 2014 2015 2017
Alternative Technologies for Grid Energy Storage Procurement - Phase II
Regulation (6 MW) (16 MW)
• Evaluate alternative technologies • Investigate storage for responding to
for regulation service market signals
• Different technologies selected for
technology diversity
Grid Energy Storage Procurement - Phase I
(33 MW)
• Investigate storage for regulation, and
Regulation RFP (55 MW)
reactive support and voltage control
• Two new storage facilities selected
(RSVC)
through competitive RFP
• Projects across different zones to
• Complement existing 100 MW
evaluate their effectiveness at alleviating
regulation service
local constraints or restrictions
45NORTHEAST
ESSA OTTAWA
BRUCE
EAST
TORONTO
SOUTHWEST
NIAGARA
WEST
46Energy Storage - Operational Challenge
What the IESO system
Reality…
model “sees”…
G Generator Load
A SINGLE storage facility that TWO separate facilities with no
can withdraw, store and inject storage capacity and no discernable
energy relationship with each other
47Energy Storage - Operational Challenge
What the IESO system
The result…
model “sees”…
• Risk of conflicting dispatch
between the two facility
components modeled
• Dispatch Scheduling and
Optimization (DSO) model
has no awareness of storage
capacity or ability to
optimize it
G Generator Load
TWO separate facilities with no
storage capacity and no discernable
relationship with each other
48Grid-LDC Interoperability Standing Committee
Update
Objective:
• Establish a partnership to discuss issues & opportunities for
a more coordinated operation of Ontario’s electricity system;
• Identify how existing capabilities can be enhanced to
increase the efficiency & reliability of Ontario’s electricity
system, and
• Increase awareness of upcoming changes at both the grid &
distribution levels to understand the impact on system
operations and develop new capabilities to manage them.
49Grid-LDC Interoperability Standing Committee
Update
DER Survey: Gain better understanding of DER penetration levels,
technical limitations and communication (visibility & control)
– Survey revised based on LDC feedback and re-issued
– High response rate received from participating LDCs
LDC Data Sharing Pilot: Improve operational visibility and forecast
accuracy through greater visibility of DERs
– First Pilot: Receive aggregated embedded generation telemetry from 2 LDC’s
– Started adding aggregated telemetry for DERs < 5 MW by station for Alectra
and Enwin
Standing Committee Agenda for 2018:
– Develop an Operational Risk Assessment with LDCs, identifying and
prioritizing risks, creating need for new operational capabilities
50Summary
• MTI is a necessity within Operations given
the evolving market & system conditions
• Storage portfolio is growing and coming
online
• Grid-LDC Interoperability Standing
Committee is moving well
51Questions
The Connection Assessment Process Samuel Jager, Connection Assessments, IESO June 2018
Introducing Connection Assessments
• New facilities or modifications of existing facilities connecting to the
IESO-controlled grid change the operating characteristics of the
system (locally and/or globally).
• The Connection Assessment and Approval (CAA) process ensures
these changes don’t have an adverse effect on the reliability of the
IESO-controlled grid (Section 6 of Chapter 4 of the Market Rules).
• The CAA process is implemented via System Impact Assessments
(SIAs) and the Expedited System Impact Assessments (ESIAs) (Market
Manual 2.10).
54The Connection Assessments Process
• Applicants must seek out the Connection Assessments process prior
to connecting.
• Occurs ahead of registering equipment in the Operations
Integration process
55SIA Process Overview
Through the following steps, the SIA process identifies solutions to
maintain the reliability of the IESO-controlled grid:
• Connection applicants submit an SIA application
• The IESO enters an SIA agreement with the connection applicant and
performs the necessary studies.
• The IESO issues a draft SIA report to the connection applicant and
transmitter for review and comments.
• Once agreement is achieved on the report the IESO issues a final SIA
report and a NoCA or NoDR to the connection applicant.
56Clarifications and Opportunities
• We want to hear from you! Please contact the connection assessments
(CA) group anytime there’s a question or concern.
• The CA group routinely looks to improve delivery of services while
maintaining system reliability.
• The CA group targets to follow up on any inquiry as soon as possible -
typically within 2 business days.
• All communication during the SIA process is confidential. Only the
final SIA/ESIA report is published by the IESO
• We encourage kick-off meetings (face-to-face, if preferred) and regular
meetings on project status to ensure all parties are well informed.
57Clarifications and Opportunities (contd.)
• Spare equipment used for regular maintenance or repairs that involve
replacement of primary equipment can be pre-assessed
• Though the SIA/ESIA is intended to assess the final stage of the project,
providing information on critical intermediate stages within the
SIA/ESIA raises awareness amongst all involved parties
• The current application forms contain sufficient provisions for
submitting both temporary and spare equipment information to the
IESO for connection assessments.
• Our team is currently working with regulating bodies and industry to
improve the effectiveness of integrating of non-traditional generation
including DER technologies into our processes
58Connection Assessments Information
• Market Manual 2.10: Connection Assessment and Approval
Procedure http://www.ieso.ca/en/sector-participants/market-
operations/-/media/2b4b86bbada344a9a36beeab0e722fbe.ashx
• Webpage: http://www.ieso.ca/en/sector-participants/connection-
assessments/obtaining-a-connection-assessment
• Contact: connection.assessments@ieso.ca
59Operations Integration Bryan Hartwell, Operations Integration, IESO June 2018
Introducing Operations Integration
• New facilities or modifications of existing facilities need to
integrated into tools and business processes for reliable real-time
operation of the IESO controlled grid and IESO administrative
markets.
• The IESO uses the facility registration process to assess whether
market participant’s facilities or boundary entities meet all
minimum requirements defined by the market rules.
• The IESO has established procedures, via Market Manual 1.1 and
1.2, for the implementation of the Operations Integration process.
61Operations Integration
• The following main processes are part of Operations Integration:
1. Participant Authorization
2. Facility Registration
3. Commissioning facility (test, re-test, test again)
4. Manage the current information (updates)
5. Performance Validation
62Facility Registration Lifecycle
63Registration Approval Notification - RAN
• RANs are issued for different reasons, such as:
– New equipment
– Updated/Modified equipment
– New organization/participation types
– De-registrations and withdrawals
– Various stages of a facility lifecycle (e.g.: on-potential, on-load,
commissioning, injection, or dispatchable, etc.)
– Register for Demand Response
• Purpose:
– Inform Control Room of changes to ICG and IAM that affect operation of such.
– A checklist to ensure IESO activities to support change are completed; such as:
modelling, metering, commissioning, etc.
64Registration Approval Notification
Year # of RANs issued
2005 96
2014 363
2015 424
2016 362
2017 448
65Performance Validation
• Not strictly a part of the registration process itself,
• Registered data is verified through study and field testing,
• Verify facilities have met requirements stipulated in SIA,
• Verify facilities comply with regulatory standards.
66Upcoming Additions to Online IESO
• User changes to Market Meter Participant role
• User changes to Owner/Operator role
• User initiation of facility/org name change, or withdrawal from
market
67Questions?
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