Transcript Determine Facility Ratings, System Operating Limits and

Determine Facility Ratings, SOLs and
Transfer Capabilities
An Overview of the Set of
Proposed Standards
Paul Johnson
Chair of the Determine Facility Ratings
Standard Drafting Team
Presentation Overview
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Proposed Standards
Highlights of Standards
Key Requirements & Functions Responsible
Challenging Definitions
Controversial Issues
V0 Retirements
Effective Dates
Questions
6 Standards
1.
2.
3.
4.
5.
6.
Document Facility Rating Methodology
Develop and Communicate Facility Ratings
Document SOL Methodology
Develop and Communicate SOLs
Document Transfer Capability Methodology
Document and Communicate Transfer
Capabilities
Facility Ratings Methodology
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Respects most limiting equipment rating
Identify method of determining rating
Consideration of:
V0 only requires normal &
Manufacturer’s ratings
emergency ratings &
doesn’t identify generators
Design criteria
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• Ambient conditions
• Operating limitations
• Other assumptions
End users need a ‘range’ of
limits, only some of which
are ‘normal’ and
‘emergency’
System Operating Limits Methodology
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Cannot exceed Facility Rating
How to identify IROLs
In pre and post contingency state SOLs
provide:
• BES system stable (transient, dynamic, voltage)
• Facilities within Facility Ratings
• Facilities within thermal, voltage & stability limits
• Cascading outages & uncontrolled separation
shall not occur
V0 has no criteria for
developing SOLs used in
operations horizon
Which SOLs are Also IROLs?
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Some IROLs can be identified in advance –
some can only be identified in real-time
An IROL is an SOL that, if violated under
certain conditions, could lead to one or more
of the following:
• Cascading outages
• Uncontrolled separation
• Instability
V0 doesn’t require
documenting
methodology for
determining IROLs
Transfer Capabilities Methodology
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Respect all SOLs
Consideration of:
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Transmission system topology
System demand
Generation dispatch
Current and projected transmission uses
V0 has no criteria for
developing Transfer
Capabilities
Key Requirements &
Responsible Functions
Methodology
Who Has or
Develops?
Who Sees or
Receives?
Facility Ratings
Gen Owners
Trans Owners
PAs
TPs
RCs
TOPs
System Operating
Limits
PAs
RCs
PAs
TPs
RCs
TOPs
TSPs
Transfer
Capabilities
PAs
RCs
RROs
PAs
TPs
RCs
TOPs
TSPs
Key Requirements &
Responsible Functions
Product
Who
Develops?
Who
Receives?
Facility Ratings
Gen Owners
Trans Owners
PAs
TPs
RCs
TOPs
System Operating
Limits
PAs, TPs
RCs, TOPs
PAs
TPs
RCs
TOPs
TSPs
Transfer
Capabilities
PAs
RCs
RROs
PAs
TPs
RCs
TOPs
TSPs
Proposed Changes to V0 Definitions
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Cascading Outages
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Contingency
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Interconnection Reliability Operating Limit (IROL)
Cascading Outages
V0: The uncontrolled successive failure of system
elements triggered by an incident at any location
within the Interconnection. Cascading results in
widespread electric service interruption that cannot be
restrained from sequentially spreading beyond an
area predetermined by studies.
New: The uncontrolled successive loss of BES
Facilities triggered by an incident (or condition) at any
location resulting in the interruption of electric service
that cannot be restrained from spreading beyond a
pre-determined area.
Contingency
V0: The failure, with little or no warning, of one
or more elements of the transmission system.
This includes, but is not limited to, generator,
transmission line, transformer, and circuit
breaker failures or misoperations.
New: The unexpected loss of one or more
BES Facilities caused by a single initiating
event.
Interconnection Reliability Operating
Limit (IROL)
V0: The value (such as MW, MVar, Amperes,
Frequency or Volts) derived from, or a subset of
the System Operating Limits, which if exceeded,
could expose a widespread area of the Bulk
Electric System to instability, uncontrolled
separation(s) or cascading outages.
New: A System Operating Limit that, if violated,
could lead to instability, uncontrolled separation,
or Cascading Outages that adversely impact the
reliability of the Bulk Electric System.
Controversial Issues
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Flexible planning & operating horizons
Peer review
Schedules for delivery set by recipients
Table 1 Category C Events and SOLs
Partial retirement of V0 Standards
Planning & Operating Horizons
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Standard requires no gaps in times covered
Operating
Horizon
Real
Time
1
Year
Ahead
Planning
Horizon
2
Years
Ahead
3
Years
Ahead
4
Years
Ahead
Planning & Operating Horizons
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Defaults:
• Operating Horizon = real-time up to 1 yr
• Planning Horizon = 1 yr and beyond
Operating
Horizon
Real
Time
1
Year
Ahead
Planning
Horizon
2
Years
Ahead
3
Years
Ahead
4
Years
Ahead
Peer Review
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Goal is to find a fair balance
• Owners rights versus impact on others
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‘Allow’ but don’t ‘require’ peer review
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Challenges must be documented & acknowledged
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Threat of liability is motivator
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Idea from Blackout Recommendations
Schedules for Delivery . . .
. . . to those entities that have a reliability-related
need for such … and make a written request that
includes a schedule for delivery of such …
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If you need to send limits to several different entities
- deliver to all entities according to the most limiting
schedule
Table 1 - Category C Events
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Category C – (Loss of 2 or more Elements)
applicable to planning studies with all facilities in
service
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In most real-time operations, one or more facilities
already out of service - operate to protect the system
from a 2nd (or 3rd or 4th…) contingency
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SOLs established considering ‘Category C’ events
would probably result in overly restrictive SOLs
Partial Retirement of V0 Standards
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V1 Standards started before V0 Standards
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No 1-to-1 relationship between V0 and V1
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Does partial retirement lead to confusion?
Retirement of V0 Requirements
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TOP-004 – Transmission Security
• Retire two requirements
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FAC-004 – Methodologies for Determining
Electrical Facility Ratings
• Retire entire standard
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FAC-005 – Electrical Facility Ratings for
System Modeling
• Retire entire standard
R6. TOPs, individually and jointly with other TOPs, shall
develop, maintain, and implement formal policies and
procedures to provide for transmission reliability. These
policies and procedures shall address the execution and
coordination of activities that impact inter- and intra-Regional
reliability, including:
• R 6.1.
• R 6.2.
Equipment ratings.
Monitoring and controlling voltage levels and real
and reactive power flows.
• R 6.3. Switching transmission elements.
• R 6.4. Planned outages of transmission elements.
• R 6.5. Development of IROLs and SOLs.
• R.6.6. Responding to IROL and SOL violations.
Effective Dates – (Compliance)
Assumes BOT Adopts November 1, 2005
 Methodologies
• 6 months after BOT adoption 
May 1, 2006
Ratings, Limits and Transfer Capabilities
• 2 months after methodologies – July 1, 2006
Questions