Information Document Outages ID#2013-003R

Information Document
Outages
ID#2013-003R
Information documents are for information purposes only and are intended to provide guidance. In the
event of any discrepancy between the information document and the related authoritative document(s)
in effect, the authoritative document(s) governs. Please submit any questions or comments regarding
this information document to [email protected].
1
Purpose
This information document supports the following sections of the ISO rules:
Section 306.3, Load Outage Reporting;
Section 306.4, Transmission Planned Outage Reporting and Coordination; and
Section 306.5, Generation Outage Reporting and Coordinating.
The purpose of this information document is to assist market participants to understand the process of
outage reporting and the related reports posted on the AESO’s website
http://www.aeso.ca/market/8856.html Increased understanding of the process and related reports assists
in the co-ordination of outages. Outage coordination is essential to maintain system reliability, reduce the
number of hours of operation under constrained conditions, facilitate open and transparent operation of
the electricity market, and minimize market participant interruptions. This information document is likely
of most interest to market participants who use or submit outage information.
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Background
The Fair, Efficient and Open Competition Regulation came into effect on September 1, 2009. Section 4
of the regulation prohibits trading on outage information that is not available to the public unless permitted
by the regulation. In order to facilitate the public availability of outage records, section 4(2) of the
regulation imposes an obligation on market participants to provide outage records to the AESO. These
records are used by the AESO in order to comply with section 4(3): to make outage records received from
market participants available to the public. Further detail on the AESO’s legislated obligations under the
Fair, Efficient and Open Competition Regulation can be found in ID#2010-004 on the AESO’s
website.http://www.aeso.ca/market/18710.html In addition to reports related to transmission, generation
and load outages, the AESO also publishes intertie transfer capacity reports and a 24 month supply and
demand graph. These reports are also described below.
To facilitate a safe and reliable Alberta interconnected electric system; there is a need to carry out risk
assessments and coordination for planned outages to generation and major transmission elements.
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Transmission Planned Outages
3.1 Planned Outages
(a) Applicability
Section 306.4 of the ISO rules applies to all planned outages, including live-line work and recloser-block situations. Other terminology commonly used by legal owners might also apply,
such as “hold-off permits”.
(b) Planned Outage Requests
The AESO requires legal owners of transmission facilities to send in planned outage
requests for outages that are actively being planned and which are beyond a speculative
stage. The AESO further requires the legal owner to submit the request as early as possible
to enable the AESO to foresee coordination concerns. For planned outages that the legal
owner foresees to have particular coordination challenges, the AESO encourages the legal
owner to submit the requests as early as possible on a consultative basis.
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The AESO also requires the legal owner to submit a complete list of all the planned outages
that it is requesting for the coming operating week in order for the AESO to reconcile it
against previously submitted planned outage requests.
As set out in subsection 5(2) of section 306.4 of the ISO rules, transmission planned outage
requests submitted to the AESO must include the following details concerning required
planned outage information:
(i)
“the transmission facility being taken out of service”- identified by the element
designation as it appears on the legal owner operating documents.
(ii)
“dates and times”- indicating the start of switching to isolate a facility and the end of
switching to return the facility to service: For major elements, such as transmission
lines, the switching time might add approximately thirty (30) minutes to the start and
end of the intended planned outage activity. In other situations, such as protection
or telecommunication element planned outages, the switching time is expected to
be negligible.
(iii)
“nature of work and any related elements that will be affected” - a high level
description, including any related elements affected. Switching procedures or other
lengthy descriptions are not required, nor can the AESO’s outage tool accommodate
such.
(iv)
“details of the contingency assessment and any mitigation plans” - details of
contingency assessments may be submitted to the AESO in a separate document.
In cases where the legal owner’s assessment has not found any concerns, the legal
owner may submit a statement such as “No concerns identified.” The AESO does
not assess outage requests that are not accompanied by a contingency
assessment.
(v)
“confirmation of coordination with affected market participants and adjacent
transmission operators” - confirmations should include affected market participants
and adjacent interconnected transmission operators: This condition is satisfied with
a policy statement from the requesting legal owner generally describing its
coordination practice or policy. In particular circumstances, the AESO may request
the legal owner to make a specific confirmation of coordination with impacted
market participants. Market participants, includes system access customers and
interconnected facility owners.
(vi)
“isolation points” - isolation points are necessary for equipment energized from at
least one (1) point at greater than twenty-five (25) kV. Isolation points are important
for the AESO’s energy management system model to properly account for elements
taken out of service.
(vii)
“time to restore the transmission facility in an emergency” - indicate the amount of
time it would take to restore the transmission facility if an emergency required the
transmission facility to be restored.
(c) Planned Outage Pre-Work and Information
The AESO expects legal owners to coordinate with other affected legal owners and affected
market participants to determine a mutually agreed upon planned outage schedule before
submitting a planned outage request to the AESO. Market participants, includes system
access customers and interconnected facility owners.
(d) Assessments
The AESO assesses planned outage requests as far in advance as it considers feasible.
Assessments take into account many factors including, AESO’s estimation of future
conditions on the interconnected electric system and AESO engineering resource
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availability. The AESO may choose not to assess late planned outage requests. If the
AESO does not assess a planned outage, the planned outage cannot proceed.
The AESO assesses requests for outage activities as described in the following three
paragraphs. However, these guidelines may not be universally applicable.
For the purpose of this document, a planned transmission outage itself is considered N-1
contingency, and a subsequent contingency is identified as N-1-1 contingency.
The AESO uses, but is not limited to using, steady-state, voltage stability and transient
stability analyses to assess N-1 and N-1-1 conditions. The AESO also assesses the impacts
of planned transmission outages to load and the supply margin including operating reserves.
Where appropriate, the AESO consults with the affected parties and shares the study results
Based on the analyses results, the AESO may develop mitigation strategies for contingency
situations, or request changes to the legal owner’s planned outage request.
(e) Planned Outage Changes
The sooner a legal owner submits a change to an outage, the more likely the AESO will
have the opportunity to assess and approve the change. All changes to planned outages
should be made by sending an email to [email protected] The AESO expects
that a change to a planned outage is known well enough in advance to adhere to the times
as per subsection 4 of section 306.4 of ISO Rules. Changes to an outage submitted after
ten (10) AM of the business day before the change, is expected to be an emergency or a
forced outage and notification should be made by calling the AESO System Controller in
addition to sending an email to the address noted above.
When a legal owner cancels a previously requested planned outage in the time period up to
and including the day before the start-date of the planned outage, and if still during AESO
office hours, the legal owner should send an email to the AESO
([email protected]) clearly indicating its intention to not proceed with the planned
outage. If the legal owner needs to cancel a planned outage on the intended start-day of the
planned outage, it should do so by phoning the AESO System Controller, in addition to
sending an email notice to [email protected]
3.2 Transmission Planned Outage Reports
(a) Approved Outages
This report lists the transmission planned outages that the AESO has approved. This report
is located on the Market & System Reporting page of the AESO’s website at
http://www.aeso.ca/market/8856.html
(b) Long Term Critical Transmission Outages
The principal purpose of this report is to aid in the coordination of planned outages between
legal owners. This report lists transmission planned outages by month for the next twentyfour (24) months. Planned outages listed in this report are tentative and the AESO may not
have granted approval. This report is located on the Market & System Reporting page of the
AESO’s website http://www.aeso.ca/market/8856.html. The report includes planned
outages of facilities that meet one or more of the criteria listed in subsection 2(2) of section
306.4 of ISO rules.
(c) System Coordination Plan
The purpose of this report is to send information to legal owners of transmission facilities
concerning the conditions under which a planned outage can occur and provide mitigation
strategies for contingency conditions. It includes all transmission planned outages sixty-nine
(69) kV or greater that have been approved by the AESO’s Operations Coordination group
for the following operating week. It is updated on Wednesdays and may be updated at other
times, if necessary. Each posting is time-stamped.
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4
Generation Outage Reports
The AESO reports generation outages to market participants in three (3) separate reports: Daily Outage,
7 Day Hourly Available Capability and Monthly Outage Reports. These reports can be found on the
AESO’s website under Market & System Reporting http://www.aeso.ca/market/8856.html The purpose of
these reports is to illustrate generation outages based on pool participant submissions in the Energy
Trading System. These submissions are made in accordance with section 306.5 of the ISO Rules. These
reports reflect generation availability, but do not take constrained down generation into account. The
expected impact of transmission and other operating constraints (as well as outages) is reflected in the 24
Month Supply and Demand report. Additionally, all generation outage reports are current. No historical
reports are available.
4.1 Daily Outage Reports
The Daily Outage Report illustrates generation outages by the daily average amount of supply by
fuel type and time period on outage for the next three (3) months. The report shows the
difference between maximum capability and available capability of pool assets as submitted by
pool participants in the Energy Trading System. Supply within the same fuel type category is
aggregated to create one final outage amount for each fuel type for each time block. The
aggregated volume of each fuel type is then rounded off to the nearest ten (10) MW.
Note that the maximum capability differs from maximum continuous rating. The latter is the
maximum net power output that can be sustained by a generation pool asset and such values are
posted for most generating units on the AESO’s website. For most generating units, the
maximum capability and maximum continuous rating are similar. Values are most divergent for
generating units that primarily supply onsite load and only offer electric energy net-to-grid. In
these cases, the maximum continuous rating may be considerably larger than the maximum
capability. Some generating units do not report a maximum capability. These include wind
aggregated generating facilities, small power producers and generating units smaller than five (5)
MW. Outages for generating units that do not report a maximum capability value are not included
in the outage reports. The Daily Outage Report is available in HTML and CSV formats. This
report is located on the Market & System Reporting page of the AESO’s website
http://www.aeso.ca/market/8856.html.
Load is also included in the Daily Outage Report. See section 6 for further details.
4.2 Monthly Outage Reports
Similar to the Daily Outage Report, the Monthly Outage Report is also based on the difference
between maximum capability and available capability of generating pool asset as submitted by
pool participants in the Energy Trading System. The report illustrates monthly data on a rolling
24 month basis. The data is aggregated by fuel type for each hour. The hourly data is then
combined in a monthly number by averaging the hourly volumes for all hours of the month by fuel
type. The aggregated volume for each fuel type is then rounded off to the nearest ten (10) MW.
The monthly outage report is available in Graph, HTML, and CSV formats. This report is located
on the Market & System Reporting page of the AESO’s website
http://www.aeso.ca/market/8856.html.
4.3 7 Days Hourly Available Capability Reports
The 7 Days Hourly Available Capability Report illustrates the aggregate available capability factor
by fuel type for each hour over the upcoming seven (7) days. The availability factor is calculated
as the sum of the available capability divided by the total maximum capability of the fuel type.
This report is located on the Market & System Reporting page of the AESO’s website
http://www.aeso.ca/market/8856.html.
Updating of the Generation Outage Reports
All three (3) of the generation outage reports are updated at regular intervals which is illustrated by a
last updated time stamp within the report. The updating of outage reports are subject to a small delay
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due to calculation and posting. On average, they are updated every five (5) to ten (10) minutes, with
a maximum update time of twenty (20) minutes. The daily and monthly outages reports have, on rare
occasions, not been updating. If, after refreshing the report, the last updated time is more than twenty
(20) minutes, please contact [email protected]
A submission may not appear immediately. If the time at which the outage was submitted is after the
“Last updated” time on the report then no action needs to be taken. The outage has not been
included on the outage report but should appear upon the next update.
If the time at which the outage was submitted is prior to the “Last updated” time on the outage report,
follow these steps.
Check that the submission of new available capability values was made correctly in the Energy
Trading System. This can be verified by logging into the Energy Trading System, and viewing the
submission in the “Outage Scheduling” tab, for the specific time period that the outage was entered
for and checking the impact the submission would have on the outage report, noting that:
(i) outages are pro-rated across the time period (for example, an outage for one hour today
during the on-peak period shows as an outage on the daily report of 1/16th of the
magnitude).
(ii) outages are rounded to the nearest ten (10) MW; and
(iii) coal outages are converted on a percentage basis to a hypothetical coal generating unit with
a maximum capability of three hundred and fifty (350) MW.
If a problem with the outage report is still suspected after completing these checks, contact
[email protected]. The outage report may still be accurate since a countervailing outage of similar
magnitude and time may result in a zero net impact. Investigations in the past have, in almost every
instance, confirmed that the outage reports are functioning correctly. Note that the AESO does not
provide individual pool participant outage information and specifically, whether it has or has not been
included in the reports.
Coal Generating Unit Outages
A generic three hundred and fifty (350) MW generating unit maximum capability is used to protect the
identity of coal generating units, which are few in number and in some cases identifiable by size. An
outage at the smallest coal generating unit, approximately one hundred and forty-five (145) MW and
the largest coal generating unit, approximately four hundred and fifty (450) MW, both show on the
outage reports as a three hundred (350) MW outage. Three hundred and fifty (350) MW was
selected as an average or representative size.
New Generating Units
New generating units are only included in the outage reports once they have access to the Energy
Trading System and enters its available capability and maximum capability values. Pool participants
are only able to access the Energy Trading System once they have a valid supply transmission
service contract in place. Typically, this occurs on the first day of the month during which the
generating unit is expected to start generating. The outage reports reflect the outage submissions for
new generating units as required by section 306.5 of the ISO rules
While the generating unit is testing as per its testing plan submitted under section 505.3 of the ISO
rules, the outage reports reflect its available capability submissions. Typically, testing and
commissioning activities for simple cycle gas generating units are relatively short. Testing and
commissioning activities for coal generating units and some cogeneration generating units, where
commissioning may be staged, may last a number of months.
To ensure that all market participants know when a new unit is reflected in the outage report, the
AESO has adopted the business practice of including the pool asset name in the list of pool assets
and placing the generating unit on the Current Supply & Demand page found on the AESO’s website.
While the AESO is able to add a generating unit to the Current Supply & Demand page, the AESO
may not display its total net generation until the AESO has verified it is receiving accurate data.
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If a generating unit is added to the Current Supply & Demand page prior to having all their
supervisory control and data acquisition operational, the report Total Net Generation and Dispatched
(and accepted) Contingency Reserve displays a dash instead of zero (0).
Generating Unit Retirement
A generating unit that is subject to an upcoming retirement is still required to submit availability
information as specified by section 306.5 of the ISO rules An available capability of zero (0) MW in
each hour after the expected retirement date is recorded. This appears as an “outage” for the
corresponding periods in daily and monthly outage reports. Once the generating unit has retired the
pool participant no longer enters available capability values and the generating unit no longer appears
in the outage reports. At this time, the AESO has adopted the business practice of changing the
generating unit’s entry in the list of pool assets to show an ‘Operating Status’ of retired and removing
the generating unit from the Current Supply & Demand page.
5.
Load Outage Reporting
As noted previously, the load outages are combined with generation outages within the Daily Outage
Report. Like generation, the report displays load submitted outages for the current month and the next
three (3) months. The load outage records are aggregated to determine the daily load outage based on
market participant submissions. As per section 306.3 of the ISO rules, a market participant with a
planned decrease of forty (40) MW or greater in its capability to consume load, reports load outage
records to the AESO. The load outage portion of the Daily Outage Report is time stamped separately as
it not updated as frequently as the generation outages.
6.
Month Supply and Demand Graphs
The purpose of these graphs is to provide information to aid in the planning of generation and intertie
outages. The graphs represent the anticipated available supply compared with expected system demand.
The system demand includes load and required operating reserves. The supply portion accounts for
planned outages and derates of generation, including those caused by transmission outages, and
reductions to intertie capability due to transmission system conditions. Generation outages are
aggregated so an individual generating unit outage is not disclosed. The timeframe is a rolling window of
twenty-four (24) months. The graphs are updated each weekday, sometimes more than once per day, and
time-stamped.
7.
Intertie Available Transfer Capability Report
The purpose of this report is to present the current and anticipated available transfer capabilities for the
Saskatchewan, British Columbia and Montana interties to aid market awareness of Alberta import/export
capabilities. The report covers a selectable period, on an hour-by-hour basis, as far out as thirteen (13)
months. This report is located on the Market & System Reporting page of the AESO’s website at
http://www.aeso.ca/market/8856.html.
Revision History
Effective Date
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