Transmission Outage Coordination Process

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MARCH 25, 2013
Maine 2013 Outage Coordination
Agenda
•
Welcome, Introductions and Safety
•
Expectations and Goals for Meeting
•
ISO Info Policy
•
Minimum Interconnection Consequences
•
MPRP Video
•
MPRP Project Overview
•
Other CMP/BHE Projects
•
General discussion, outage coordination process
– Relationships and responsibilities of CMP and ISO-NE
– ISO-NE policies and procedures must meet all NERC/FERC requirements
– 2012 Outage Statistics for Maine and ISO-NE
•
Specific Outage Discussion, Key 2013 outages
– Interfaces
– Specific long term outages
•
Questions
2
Expectations/Goals
• Communicate outage coordination process
• Communicate significant planned 2013 Maine transmission
equipment outages that could impact generation constraints
• Communicate specific outage coordination changes to limit
impact on potential generation constraints
• Respond to outage coordination questions from the audience
3
Operational Responsibilities and Authorities
• ISO
– Central Dispatch and Day-to-day operation of the New England system
• Transmission facilities over which it has operational control
• Generators, Dispatchable, Asset Related Demand, Real-Time Demand
Response Resource, Real-Time Emergency Generator Resource
• Includes decisions, instructions and orders issued to an Local Control
Center (LCC) or Market Participant
• LCC
– Assist ISO to meet the Central Dispatch objectives
• Responsible for security of transmission facilities
• SCADA functions, security of lower voltage facilities, switching and tagging
• Market Participants
– Will contribute to Central Dispatch objectives in accordance to
• ISO Operating Procedures, Market Rules, Procedures and Manuals, and
Transmission Operating Guides
4
ISO Information Policy
• Limits type of information that can be communicated with
participants
– Market sensitive information
• Specific transmission equipment outage information
• Specific impacts on generators and system transfer capabilities
– Currently revising what information can be communicated
•
•
•
•
Will allow potentially limiting interfaces to be identified
Will allow communicating a range of typical limits
Will not allow communicating generator specific impacts
Will not allow communicating discrete dependences on changes to
interface limits
5
Minimum Interconnection Standard
Operational Considerations
• New England generators interconnect per the Minimum
Interconnection Standard (MIS) contained in the ISO Tariff
– Upgrades are required to preserve existing all-lines-in transfer
capability
– Potentially results in generation export constraints
• MIS Planning Studies may not identify magnitude of generation
constraints
• Facility out conditions may result in larger generation export constraints
– ISO/CMP/BHE Operations determines actual transfer limits
– When generation restrictions occur ISO Market Rules dictate
commitment and dispatch
6
MPRP VIDEO
7
MPRP Project Statistics
•
452 miles of new or rebuilt 345kV and
115kV Transmission
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•
•
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5 new Greenfield Substations
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183 miles of new 345kV Transmission
105 miles of new 115kV Transmission
5 miles of Rebuilt 345kV Transmission
140 miles of rebuilt 115kV Transmission
8 miles of rebuilt 34.5kV Sub Transmission
11 miles of 345kV and 115kV line terminations
Albion, Coopers, Monmouth, Larrabee, Raven
6 Major Substation expansions
•
Maguire, South Gorham, Surowiec, Gulf Island, Belfast,
Livermore Falls
•
50 Remote end substation expansions or
modifications
•
60 - Transmission line crossings
8
CMP/BHE Capital and Maintenance Work
• Other Non-MPRP CMP Capital and Maintenance Work that
affects the transmission system
– Transmission Line Structure Replacements both Capital and
Maintenance
– System Planning related Substation rebuilds or expansions to support
future reliability needs
– Substation equipment replacements or upgrades to address
maintenance concerns
– Transmission Line re-rates or rebuilds to increase capacity
– Substation maintenance equipment inspections and relay testing
– Regulatory required relay and equipment trip checks
9
MPRP Construction Challenges
• New Transmission construction is in close proximity to existing lines
• The MPRP was designed to utilize the existing CMP corridors to the
maximum extent practicable
• Extensive construction sequence planning to allow for new and
upgraded Transmission Lines to be terminated into new Substations
• Temporary construction is required on existing facilities to allow for the
construction of new substations and transmission lines
• Modifications to existing substations to allow for new Transmission
Lines
• Reconfiguration of existing transmission lines
• Construction restrictions such as time of year restrictions on outages,
environmental restrictions and weather
• Impact of unplanned outages
• Impact on neighboring Area outages
10
MPRP Cross Sections
11
OUTAGE COORDINATION PROCESS
Relationships and Responsibilities
FERC
(Federal Energy Regulatory Commission)
United States federal agency with
jurisdiction over interstate electricity
sales, wholesale electric rates,
hydroelectric licensing, natural gas
pricing, and oil pipeline rates.
FERC is an independent regulatory
agency within the United States
Department of Energy (DOE).
ISO-NE
(Independent System OperatorNew England)
Ensure reliable operation of
New England's bulk power generation
and transmission systems.
Created and regulated by the (FERC)
(Balancing Authority)
and
(Reliability Coordinator)
NERC
(North American Electric Reliability Corporation )
Ensure the reliability of the bulk power system
in North America. Develop and enforce
reliability standards.
NERC is a self-regulatory organization,
subject to oversight by (FERC )
Non-Compliance Reporting
Transmission Operating Agreement
Policies/Procedures
Compliance Audits
Real-Time Power System Data
Compliance Self
Reporting
NPCC
(Northeast Power Coordinating Council )
Not-for-profit corporation responsible for
promoting and improving the reliability
of the international, Interconnected
bulk power system (BPS) in
Northeastern North America
NPCC’s operates under a delegation
agreement with (NERC).
Maine Local Control Center
Ensure safe and reliable
operation of CMP Transmission and
Sub-Transmission systems.
115 & 345 kV Transmission (HV)
And
34.5 kV Sub-Transmission (MV)
(Transmission Operator)
Non BPS not subject to FERC oversight.
CMP Communication Center
Dispatch outage and trouble calls,
Dispatch distribution and revenue
based reconnects, Distribution Switching
and Tagging, Field calls from police/fire
departments and customers, Interface with
Service Centers
19.9kV, 12.5 kV, 11kV, 4kV (MV)
13
Outage Coordination Background
• ISO New England has the responsibility and authority to
accept, review and approve/deny transmission and
generation outage applications in the region
• Outage coordination is done jointly by the ISO and the
Local Control Centers (LCCs)
• Outage coordination is highly complex in current environment
of wholesale energy markets and significant construction
build-out of the Maine transmission and generation systems
• Over 11,000 New England transmission and generation
outages requests completed in 2012
14
Outage Coordination Timelines
Number of Days
730
21
5
0
Long-Term Planned
Short-Term Planned
Transmission
Unplanned
Number of Days
730
0
15
Planned Outage (PO)
Maintenance Outage (MO)
Generation
Forced Outage (FO)
Overrun Planned Outage (OPO)
15
Transmission Outage Coordination Process
• Transmission outage plans are submitted to the Maine LCC
by the Transmission Owner (TO)
– The TO transmission outage plan considers
•
•
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•
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Work can be completed safely
Work can be completed timely (crews/materials/environmental)
Minimize equipment outage durations
Combine equipment outages on common facilities
Minimize disruptions to the transmission system and maintain reliability
16
Transmission Outage Coordination Process
• The Maine LCC:
– Conforms to ISO Operational Procedures
– Conducts preliminary reliability assessment and must approve the
request prior to ISO review
– Identifies scheduling conflicts between generation and transmission
– Explores opportunities to reposition outages to minimize reliability,
economic and capacity impacts
• Approved transmission outage requests are then
Submitted to ISO
17
Transmission Outage Coordination Process
(cont.)
• ISO outage coordinators will:
– Review each outage request specifically looking at three critical aspects
• Does the outage have an adverse impact on system reliability either locally or systemwide?
• Does the outage cause significant congestion on the system resulting in a substantial
economic penalty?
• Is there an opportunity to reposition the outage to minimize reliability, economic, or
generator impacts?
– Perform a detailed reliability study on each request
– For those that have Inter-Area Impact, coordinate efforts with adjacent Areas
– Review each new outage request and determine if it contains market sensitive
information
• A transmission outage that removes a generating unit from providing energy to the
transmission system is considered “market sensitive”
• Based on the ISO Info Policy these types of outages are not published to the stakeholders
• Those outage requests which are not market sensitive are uploaded to the Long-Term
Outage Report (updated every day)
• Those outage requests which are not market sensitive are uploaded to the Short-Term
Outage Report (updated every 15 minutes)
18
Generator Outage Coordination Process
• Generator outage plans are submitted to the Maine LCC by
the Generator Owner (GO). The outage request is assigned an
outage ID and a priority.
• The Maine LCC conducts preliminary reliability assessment
and must approve the request prior to ISO review
• Approved generator outage requests are then submitted to
ISO
• ISO Short- and Long-Term outage coordinators will:
– Perform similar analyses as described previously for the transmission
outage coordination process
19
CMP Outage Coordination
Two teams are working on outage planning and coordination
Construction Sequence Team
• Consists of representatives from CMP and Burns & McDonnell
•
•
CMP – System Planning, System Operations and Engineer
BMcD – Project Management, Design Engineering, Construction Management and Outage
Coordination
Outage Coordination Team
• Consists of representatives from CMP and Burns & McDonnell
•
•
CMP – System Operations
BMcD – Project Management and Outage Coordination
20
CMP Construction Sequence Team
• Develops step by step sequencing of construction activities
required to construct and energize each substation or line
section
• Detailed plans were developed at each substation and
transmission line corridor
• Plans are reviewed with the appropriate contractors and altered if
necessary
• Facilitates and coordinates the development of contractor
schedules
• Ensures contractors’ schedules match the outage schedule
• Coordinates materials to ensure all major materials are on
hand prior to outages
21
Construction Sequence Plan
22
Construction Sequence Plan
23
Construction Sequence Plan
24
CMP Outage Coordination Team
• Develops and maintains comprehensive outage schedule
• To integrate substations, communications networks, and
transmission lines
• Initiate and monitor all Outage Request Applications
• Ensure contractors can support the outage start date
• Based on outage constraints, system reliability, and constructability
• Ensures that all documentation requirements are in
accordance with ISO procedures
• Communicate with ISO to identify and mitigate outages
that may not be allowed due to a system impact
25
Requirements of Specific Outages
• Specific outages may have special requirements that are
out of the ordinary
• The MPRP team has used a number of special
requirements to minimize the impacts of specific outages,
including:
• Install Temporary Protection Systems, including temporary Special
Protection System
• Modifications to existing Protection Systems
• Construction of Temporary Work Around
• Implementation of Special Operating Configurations
• Live Line efforts
26
CMP Outage Applications
• Central Maine Power had a total of 1,200 outage applications
in 2012
• The MPRP Project has submitted 463 outage applications for
the project through February 15, 2013
• The outages range in duration from a few hours to six months
in length
• The MPRP team anticipates that there will be an additional
500 – 600 outages needed to finish the program
27
Maine 2013 Transmission Outages
• Changes to plan typically result in increased construction cost
– Costs include overtime, additional contractor resources, expedited
material, additional engineering and outage coordination resources,
environmental mitigation, schedule and remobilization costs,
permitting, etc.
• Outages that have the potential for significant impact to
generators in 2013 will be discussed
– Long (greater than one week) duration outages
– Significant potential generation constraints
28
TRANSMISSION SYSTEM LIMITATIONS
All facility in and single facility out conditions
Transmission System Limits Impact On
Generation Constraints
• Two categories of transmission system interface limits
• Wide Area – 13 Interfaces
– Typically Include 345 kV and 115 kV facilities
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New Brunswick to New England Interface
New England to New Brunswick Interface
New England to New Brunswick + Keene Road Export Interface
Orrington South Interface
Orrington North Interface
Orrington Import Interface
Maine Yankee South Interface
Surowiec South Interface
Maine to New Hampshire Interface
New Hampshire to Maine Interface
Seabrook South Interface
Northern New England Scobie & 394 Interface
North to South Interface
– All lines in limits typically range from ~1000 MW to ~4000 MW
– Single Line Out Limits typically reduce limits by ~500 MW to 800 MW
30
Transmission System Limits Impact On
Generation Constraints
• Local Area - 7 Interfaces
– Typically include 115 kV facilities
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Keene Road Export Interface
Bangor Hydro Export Interface
Keene Road + Bangor Hydro Export Interface
Wyman Hydro Export Interface
Inner Rumford Export Interface
Outer Rumford Export Interface
Western Maine Export Interface
– All lines in limits typically range from ~150 MW to ~500 MW
– Single Line Out Limits typically reduce limits by ~50 MW to 100 MW
– Most significant recent generations constraints have been from local
area constraints
31
Local Area - Low Network Strength
• A weak transmission network is limited in its ability to
transmit power
• Real power (MW) transfer beyond Surge Impedance Loading
(SIL) requires reactive power (MVAr) supply
• SIL is the loading of a line where the reactive losses equal the
reactive charging of the line
• Typical limits for 115 kV interfaces
– Thermal limits about 200 to 250 MW per line
– Voltage / stability limits may be 50 to 200 MW per line
• The longer the line the lower the limit
32
Low Network Strength – Technical Issues
Typical SIL
Voltage Level (kV)
Typical Surge Impedance Loading (MW)
34.5
5
46
6
69
14
115
50
230
130
345
400
33
MPRP Project Geographic Overview
34
2013 Maine Major Outages
• 115 kV Outage Condition A Western Maine
– 4th Qtr 2012 – 2nd Qtr 2013 ~ 6 month duration
• 115 kV Outage Condition B Western Maine
– 3rd Qtr 2013 – 4th Qtr 2013 ~ 3 month duration
• 115 kV Outage Condition C Western Maine
– 3rd Qtr 2013 ~ 3 week duration
• 115 kV Outage Condition D Central Maine
– 2nd Qtr 2013 – 3rd Qtr 2013 ~ 6 week duration
• 345 kV Outage Condition E Northern Maine
– 2nd Qtr 2013 ~ 3 weeks duration
35
2013 Maine Major Outages (cont.)
• 345/115 kV Outage Condition F Northern Maine Area
– 2nd Qtr 2013 ~ 1 week
• 345 kV Outage Condition G Northern Maine Area
– 3rd Qtr 2013 ~ 2 weeks
• 345 kV Outage Condition H Northern Maine Area
– 4th Qtr 2013 ~ 2 weeks
• 345 kV Outage Condition I Northern Maine Area
– 4th Qtr 2013 ~ 3 weeks
• 345/115 kV Outages Condition J Southern Maine Area
– 3rd Qtr 2013 – 4th Qtr 2013 ~ 2.5 months
36
115 kV Outage Conditions A & B Western
Maine – Original Plan
• 115 kV Outage Conditions A & B Western Maine originally
planned to go on outage sequentially over 11 months in 2011
– Interface limits
•
•
•
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Inner Rumford Export Interface (Outage A) 75 MW – 75 MW
Outer Rumford Export Interface (Outage B) 75 MW – 125 MW
Wyman Hydro Export Interface (Outages A & B) 200 MW – 260 MW
Western Maine Export Interface (Outages A & B) 300 MW – 400 MW
– Rumford Power Associates (RPA) generation would not have been able
to operate
– Determined to be too large of an impact to generation, alternatives
needed to be pursued
37
115 kV Outage Conditions A & B Western
Maine – Alternatives
• Purchase additional ROW to eliminate/reduce duration of outages
– Too expensive for project
– Siting and permitting delays
• Utilize more expensive construction techniques to reduce duration of
Outage Condition B by 2 months
– Implemented
• Utilization of a temporary SPS to increase limits for both outages
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–
–
–
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Eliminated Western Maine Export Interface limit
Increased Inner Rumford Export Interface limit
Increased Outer Rumford Export Interface limit
RPA could operate
Implemented
• RPA installed a Power System Stabilizer
– Increases interface limits that are a limited by damping
• Do not take outages during the summer months
– System operational capacity needs
• Re-sequence work in order to implement alternatives
– Outage was delayed 12 months
38
115 kV Outage Conditions A & B Western
Maine – Current Plan
• 115 kV Outage Conditions A & B Western Maine planned to go non
sequentially
– Reduced outage duration from 11 months to 9 months
– Interface limits
• Inner Rumford Export Interface (Outage Condition A)
– Was 75 MW
– Now 75 MW – 215 MW
• Outer Rumford Export Interface(Outage Condition B)
– Was 75 MW – 125 MW
– Now TBD – Updated generator model(s)
• Wyman Hydro Export Interface(Outage Condition A & Outage Condition B)
– Was 200 MW – 260 MW
– Evolves with parts of MPRP I/S
– Was 200 MW – 260 MW
– Now 230 MW – 290 MW (generation DNE limit removed)
– Expect increases for Summer 2013
• Western Maine Export Interface (Outage Condition A & Outage Condition B)
– Was 300 – 400 MW
– Now N/A
– Rumford Power Associates generation is now able to operate
• Do not take outages during the summer months
– System operational capacity needs
39
115 kV Outage Condition C Western Maine
• Was originally planned coincident with the 115 kV Outage
Condition D Northern Maine in 2nd Qtr 2013
– Duration of ~ 3 weeks
– Removes
• 2 paths from the Wyman Hydro Export Interface
– Moved to reduce generation impacts
• Wyman Hydro Export Interface would have been 150 MW – 210 MW
• Inner Rumford Export Interface TBD (expect 75 MW )
• Not scheduled yet, could be 3rd Qtr 2013
– Will be after Outage Condition D Northern Maine outages
– Reduced duration
– Preliminary studies indicate that once additional MPRP construction is
completed, the Wyman Hydro Export Interface limits may increase
from the current 230 MW- 290 MW range.
• Estimated increase of 20 MW – 50 MW
• Inner Rumford Export Interface TBD (expect 75 MW )
40
115 kV Outage Condition D Central Maine –
Original Plan
• Original plan coincident with the 115 kV Outage Condition A
Western Maine in 2nd Qtr 2013
– Duration of ~ 6 weeks
– Removes 2 paths from the Wyman Hydro Export Interface
• Wyman Hydro Export Interface 150 MW – 210 MW
– ~ 3 week subset of outages
• Removes 1.5 paths from the Inner Rumford Export Interface
• Inner Rumford Export Interface estimated to be less than 75 MW
41
115 kV Outage Condition D Central Maine –
Current Plan
• Current plan is to delay until 115 kV Outage Condition A
Western Maine is completed in 2nd Qtr 2013 and continue
through 3rd Qtr 2013
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–
–
–
Wyman Hydro Export Interface impacts
Exception granted for summer outage, not a reliability concern
Considers reduced wind and hydro conditions
Prioritize most critical outage to complete first
• Modified plan to reduce outage to 2 days (Original plan was significantly
longer)
• Wyman Hydro Export Interface 200 MW
– Once this outage is complete the limits will increase for remainder of
outages
• Wyman Hydro Export Interface 245 MW
42
115 kV Outage Condition D Central Maine –
Current Plan
• Current plan is to move this subset of outages until 2014
– ~3 week outage
– Inner Rumford Export Interface impacts
• TBD
• Will be significantly improved, new Section 243A will be in service
43
345 kV Outage Condition E Northern Maine Original Plan
• Original plan 2nd Qtr 2013
– Duration of ~ 3 weeks
– Requires that a number of generators cannot operate
– Interface Limits
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•
•
•
•
•
•
New Brunswick to New England Interface 200 MW – 300 MW
New England to New Brunswick Interface 250 MW
Orrington Import Interface 250 MW – 300 MW
Keene Road Export Interface 100 MW – 120 MW
Bangor Hydro Export + Keene Road Export Interface - 580 MW
Orrington South Interface 550 MW – 675 MW
Orrington North Interface 300 MW
44
345 kV Outage Condition E Northern Maine Current Plan
– A temporary transmission configuration will be used
• All generators allowed to operate
• Single sources of supply for area load
– Interface Limits
• New Brunswick to New England Interface
– Was 200 MW – 300 MW
– Now 500 MW
• New England to New Brunswick Interface
– Was 250 MW
– Now 400 MW
• Orrington Import Interface
– Was 250 MW – 300 MW
– Now 700 MW
• Keene Road Export Interface
– Was 100 MW – 120 MW
– Now 110 MW – 130 MW
• Bangor Hydro Export + Keene Road Export Interface unchanged - 580 MW
• Orrington South Interface unchanged - 550 MW – 675 MW
• Orrington North Interface unchanged – 300 MW
45
345/115 kV Outage Condition F Northern
Maine
• Original plan 2nd Qtr 2013
– Duration of ~ 1 week
– Requires that a number of generators cannot operate
– Interface Limits using
• Bangor Hydro Export Interface - 150 MW – 250 MW
• Keene Road Export Interface 70 MW - 100 MW
• Orrington South Interface 650 MW – 1200 MW
– Ongoing coordination efforts still evaluating options
46
345 kV Outage Condition G Northern Maine
Area - Original Plan
• Original plan 3rd Qtr 2013
– Duration of ~ 2 weeks
– Preliminary Interface Limits
•
•
•
•
•
New Brunswick to New England Interface 225 MW – 450 MW
New England to New Brunswick Interface 250 MW
Orrington Import Interface 250 MW
Orrington South Interface 1000 MW
Keene Road Export Interface 0 MW
– Ongoing coordination efforts still evaluating options
• Temporary transmission reconfiguration
47
345 kV Outage Condition H Northern Maine Current Plan
• Original plan 4th Qtr 2013
– Duration of ~ 2 weeks
– Interface Limits
• Bangor Hydro Export Interface 425 MW – 500 MW
• Keene Road Export Interface 100 MW – 120 MW
• Orrington South Interface 650 MW – 1200 MW
48
345 kV Outage Condition I Northern Maine
• 4th Qtr 2013
– 1st sequence duration of ~ 1.5 weeks
• Will be restored at night
– 2nd sequence duration of ~ 1.5 weeks
• Continuous outage
– Requires that a number of generators cannot operate
• Evaluating temporary transmission configuration options
– Interface Limits
• Bangor Hydro Export Interface 410 MW – 440 MW
• Keene Road Export Interface 100 MW
• Orrington South Interface 700 MW – 1200 MW
49
345/115 kV Outage Condition J Southern Maine
• 3rd Qtr 2013 – 4th Qtr 2013
– Duration of ~ 2.5 months
– A number of evolving outages over this period
– Outage plan limits have not been assessed in detail
• Need to assess impact of partial MPRP equipment in-service
• Estimate of interface limits
– Maine Yankee South Interface 400 MW – 450 MW
– Surowiec South Interface 380 MW – 650 MW
– MPRP outages and NERC Alert outages combined to minimize total
duration of equipment outages
50
51
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