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MARCH 25, 2013

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

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MARCH 25, 2013

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  1. MARCH 25, 2013 Maine 2013 Outage Coordination

  2. 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

  3. 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

  4. 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

  5. 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

  6. 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

  7. MPRP Video

  8. MPRP Project Statistics • 452 miles of new or rebuilt 345kV and 115kV Transmission • 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 • 5 new Greenfield Substations • 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

  9. 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

  10. 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

  11. MPRP Cross Sections

  12. Outage coordination Process

  13. 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). Relationships and Responsibilities 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 ) 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). ISO-NE (Independent System Operator- New 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) Non-Compliance Reporting Transmission Operating Agreement Policies/Procedures Compliance Audits Real-Time Power System Data Compliance Self Reporting 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)

  14. 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

  15. 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)

  16. Transmission Outage Coordination Process • Transmission outage plans are submitted to the Maine LCC by the Transmission Owner (TO) • The TO transmission outage plan considers • 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

  17. 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

  18. 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 system-wide? • 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)

  19. 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

  20. 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

  21. 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

  22. Construction Sequence Plan

  23. Construction Sequence Plan

  24. Construction Sequence Plan

  25. 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

  26. 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

  27. 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

  28. 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

  29. Transmission system limitations All facility in and single facility out conditions

  30. 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 • 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

  31. Transmission System Limits Impact On Generation Constraints • Local Area - 7 Interfaces • Typically include 115 kV facilities • 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

  32. 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

  33. Low Network Strength – Technical Issues

  34. MPRP Project Geographic Overview

  35. 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

  36. 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 

  37. 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 • 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

  38. 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 • 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

  39. 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

  40. 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 )

  41. 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

  42. 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 • 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

  43. 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

  44. 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 • 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

  45. 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

  46. 345/115 kV Outage ConditionF 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

  47. 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

  48. 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

  49. 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

  50. 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

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