NPCC Summer 2012 Reliability Assessment Overview

Adequate Summer Electricity Supplies Projected

The comprehensive reliability assessment conducted by the Northeast Power Coordinating Council, Inc. (NPCC) projects that the region will have an adequate supply of electricity this summer.

A wide range of assumptions were analyzed, including extreme weather conditions derived through over 40 years of experience, unexpected plant outages, transmission constraints between and within regions, implementation of operating procedures and estimated impact of demand response programs.

The assessments indicate that the NPCC geographic area (consisting of the six New England states, the State of New York, Ontario, Québec and the Canadian Maritime Provinces of New Brunswick and Nova Scotia) will have a sufficient supply of electricity even during periods of extreme weather or severe system conditions.

Extreme weather conditions are considered to be wide-spread and prolonged heat waves with high humidity and near record temperatures.

Severe system conditions considered in this assessment included in-service delays of planned units and transmission facilities, extended unit maintenance, higher than expected unit outages, reductions in the success of demand-response programs and operating limitations assumed in neighboring regions.

Only under the unusual situation where this severe set of system conditions occur coincidently with extreme weather conditions would the implementation of a limited number of operating procedures and programs be anticipated to keep electricity supplies and demand in balance.

Summary of Key Findings

2,466 MW of new capacity 1 has been installed since last summer, plus another 1,799 MW is scheduled to be in service over the course of the summer period, for a total of 4,265 MW. No delays to the in-service dates of new generating capacity are anticipated. Considering retirements of 3,132 MW, the resultant net change in NPCC generation (from 2011 summer to 2012 summer) is +1,133 MW.

For New York City and throughout New York State, an adequate supply of electricity is forecast this summer. Since the summer of 2011, Bayonne Energy Center (500 MW) Upton Solar (32 MW), Howard Wind (57 MW) and other wind and landfill gas projects have been added to the New York system for a total of 612 MW. There were thirteen retirements in New York since summer 2011; Astoria Units 2 and 4 (180 and 380 MW respectively), Gowanus Barge Units 1 and 4 (160 MW each), Ravenswood GT 3-4 (43 MW) and Astoria GTs 10 and 11 (32 MW each) are in protective layup, while Barrett Unit #7 (20 MW), Binghamton Cogen (48 MW), Beebee CT 13 (18 MW), Far Rockaway (105 MW), and Glenwood units 4 and 5 (114 MW each) are retired. Total nameplate retirements are ~1,403 MW. The resultant net change in New York generation (from 2011 summer to 2012 summer) is -791 MW.

Ontario is projected to have a sufficient supply of electricity this summer. Since the summer of 2011, York Energy (393 MW), Comer Wind (165 MW) and Point Aux

Roches Wind (49 MW) have been added for a total of 607 MW; additions for the summer of 2012 include Bruce G1 (750 MW) and Bruce G2 (750 MW) for an additional 1,500 MW. Two coal units at Nanticoke were retired, representing a total of 980 MW. The resultant net change in Ontario generation (from 2011 summer to 2012 summer) is +1, 127 MW.

While potential local reliability challenges have been identified, New England still expects to have a sufficient supply of electricity this summer. Since the summer of 2011, 222 MW of new wind (nameplate) generating capacity has been added to the New England system. 138 MW of additional generation, New Haven Harbor 2-4 CT (for 130 MW) and the Milford DFC fuel cell (for 8 MW) is expected during this summer, for a total of 360 MW. With no retirements, the net change in New England generation from 2011 summer to 2012 summer is +360 MW.

Québec and the Canadian Maritime Provinces have more than an adequate supply of electricity forecast for the summer period. Both of these areas are winter peaking. Normal hydro conditions are expected for the 2012 summer period.

Since the summer of 2011, Hydro-Québec Production has added Eastmain 1A-A12 (256 MW), Eastmain 1A-A13 (256 MW), the Mount-Louis (101 MW) the Montagne-Seche (59 MW), Gros-Morne Phase 1 (101 MW), and the LePlateau (139 MW) wind projects and small hydro projects (23 MW) for a total of 935 MW. Generation additions for the summer of 2012 include the St. Robert-Bellarmin Wind (80 MW) and LaSaccelle Hydro (50 MW) projects total 130 MW. With the retirements of the Tracy units (450 MW) since the summer of 2011, the resultant net change in Québec generation (from 2011 summer to 2012 summer) is +615 MW.

Since 2011 summer, the Maritimes have added 49 MW of natural gas generation and 41 MW of wind generation; an additional 31 MW of wind generation is expected during the summer of 2012 for a total of 121 MW. With the retirements of the Dalhousie units (299 MW), the resultant net change in the Maritimes generation (from 2011 summer to 2012 summer) is -178 MW. The Pt. Lepreau nuclear unit’s expected return to service date is October 2012.

Projected NPCC Load

The non-coincident (sum of the individual NPCC area) forecast peak demand for NPCC during the summer of 2012 is 110,977 MW (May – September period). The forecast coincident peak demand for NPCC for the summer of 2012 of 107,052 MW is expected to occur during July. This forecast is 1,394 MW (~1.3%) lower than last year’s forecast coincident NPCC peak demand of 108,446 MW. Several factors drive this year’s summer peak demand forecast. The forecast reflects the slower than anticipated economic recovery that is underway combined with the increasing benefits of conservation, efficiency and demand response programs.

Nevertheless, ambient weather conditions remain the dominant variable in forecasting peak demand during the summer months. Historically, the peak loads and temperatures between New England and New York have a high correlation due to the relative locations of their respective load centers. Depending upon the extent and duration of a summer weather system, there is a potential for the Ontario summer peak demand to be coincident with New England and New York.

New England

The Independent System Operator of New England’s (ISO-NE’s) forecast summer 2012 peak demand is 26,462 MW, assuming historically-based expected summer peak weather conditions. This forecast takes into account a reduction of 978 MW for passive demand resources (energy efficiency). The 2012 forecast of peak demand is 314 MW (~1.2 %) lower than the corresponding 2011 forecast of 26,776 MW.

New York

The forecast peak load for summer 2012 by the New York Independent System Operator (NYISO) is 33,295 MW, which is 583 MW (~1.8%) higher than the forecast of 32,712 MW of summer 2011.

Ontario

The 2012 summer peak Ontario demand forecast by the Ontario Independent Electricity System Operator (the IESO) for ‘weather normal’ conditions is 23,409 MW, and includes the reductions due to conservation initiatives, growth in embedded generation, time of use rates, and slow economic recovery. The forecast is 152 MW (~0.6%) lower that last summer’s forecast ‘weather normal’ peak demand of 23,561 MW.

Québec

The forecast 2012 summer peak load for Québec is 20,988 MW for the week beginning August 12, 2012. The Québec overall June to September 2011 forecast is approximately 295 MW (~1.4 %) lower than the corresponding summer 2011 forecast of 21,283 MW. It should be noted, however, that Hydro-Québec’s system is winter peaking. Since some heating load remains on the system in early May and picks up again in late September, the summer peak for Québec may occur around those times.

Maritime Provinces

A 2012 summer peak load of 3,392 MW is forecast for the Maritime Provinces for the week beginning September 30, 2012. The 2012 forecast peak is 161 MW (~4.5 %) lower than last year’s corresponding (June to September) forecast summer peak of 3,553 MW. The Maritime Provinces are a winter-peaking area; forecast peaks for the shoulder months are normally higher than the summer period.

Transmission and Resource Adequacy Summary

NPCC 2012 Summary

During the NPCC forecast coincident peak load week (beginning July 8, 2012), the overall spare operable capacity (capacity over and above reserve requirements) for NPCC is estimated to be 19,576 MW. A portion of this spare operable capacity is in the Québec and Maritime Provinces. The transfer capability between the Québec and the Maritimes Provinces to the remainder of NPCC will not permit the usage of all this forecast spare operable capacity. As a result, the spare operable capacity is reduced by 3,754 MW resulting in an adjusted spare operable capacity of 15,823 MW.

The week beginning July 15th represents the week with the lowest forecast operable capacity margin (spare operable capacity less transfer capability limitations); 15,810 MW is estimated to be available. This is not the same week of the forecasted NPCC coincident peak demand. By comparison, in last year’s assessment, the corresponding amount for the week with the lowest forecast operable capacity margin was 15,455 MW.

The margins forecast for NPCC this summer tend to counteract any negative impacts that delays to the facilities described below could have to the overall NPCC reliability assessment.

New England

Based on the 2012 load forecast (50% chance of being exceeded) and projected available capacity for the summer 2012 period, weekly operable capacity margins ranging from 3,023 MW to 8,414 MW are projected. These margins do not include the short-term capacity and energy purchases from neighboring systems that are anticipated to be available. Reduced and uncertain fuel supplies to Northeast Massachusetts/Boston resources will cause local capacity margins to be tight under high load conditions.

Under the extreme demand forecast (10% chance of being exceeded), projected operable capacity margins could be as low as 843 MW for the months of July and August. During periods when the operable capacity margins are negative, ISO-NE will have to implement ISO New England Operating Procedure No. 4 – Action during a Capacity Deficiency (OP-4). OP4 actions can provide up to an estimated 4,895 MW of load relief.

Supply-Side Resources

Two new generation projects totaling 138 MW are expected to be available in New England before or during the 2012 summer period. That total includes 130 MW from three new combustion turbines at New Haven Harbor and an 8 MW fuel cell. If this generation is not operational in time for the peak demand period, it will not have an effect on Net Margins because the obligation to supply capacity will be taken on by other suppliers in a reconfiguration auction or through a bilateral contract prior to the beginning of the Forward Capacity Market (FCM) commitment period on June 1st.

ISO New England’s total nameplate wind capacity is 566 MW, with 97 MW of that amount counted toward installed capacity.

Demand Response Resources

New England includes 1,127 MW of active demand resources during the peak demand period of June through August. Active Demand Resources include Real-Time Demand Response and Real-Time Emergency Generation. These resources reduce load when ISO-NE forecasts and/or implements certain actions of ISO New England Operating Procedure No. 4 − Action during a Capacity Deficiency.

ISO New England also has 978 MW of Passive Resources that have FCM obligations. Passive DR is reflected as a reduction in the demand forecast. It includes On-Peak and Seasonal Peak Demand Resources, both of which reduce energy demand during peak

hours, are non-dispatchable, and include on-peak and seasonal peak resources. On-Peak Demand Resources provide their load reduction during pre-defined peak weekday hours, and consist of measures that may not be weather sensitive such as reductions in lighting and motors. Seasonal Peak Demand Resources must reduce load during weekdays when the load is at least 90 percent of the 50/50 peak load forecast. They consist of nondispatchable, weather-sensitive measures such as energy-efficient HVAC systems.

In addition to the reliability-based programs, ISO-NE also administers a Real-Time Price Response program. At the time of the 2011 peak demand, about 59 MW was enrolled in that program, and 30 MW responded. Due to its voluntary nature, this program was not included in this assessment.

Transmission

New bulk power transmission facilities that have been placed in service in New England since the 2011 summer period include three new 345/115 kV autotransformers. In New Hampshire, a second 345/115 kV autotransformer was installed at the Deerfield Substation in November 2011. In Massachusetts, a third 345/115 kV autotransformer

was installed at the Wachusett Substation in March 2012. Lastly, in Rhode Island a new 345/115 kV substation, named Berry, was completed in December 2011. These facility additions were needed to address various thermal and voltage issues and are components of larger projects, noted below, that are in various stages of construction.

In June 2012, a new 345 kV 60 Mvar variable reactor will be in-service at the Coolidge Substation in Vermont. It will be available to address high voltage issues that may occur during light load levels in the 2012 summer period. This is one of three new 345 kV variable reactors that will be installed as part of the Vermont Reactors Project.

All significant transmission lines and transformers are expected to be in service through the 2012 summer season with the exception of scheduled transmission projects in Maine as part of the Maine Power Reliability Program (MPRP) construction. In the event of a major unplanned outage of a significant transmission facility and the scheduling of MPRP construction outages, operating procedures will be in place to maintain system reliability.

New York

The New York Independent System Operator (ISO) forecasts installed capacity of 39,583 MW for the peak week demand forecast of 33,295 MW. Accounting for purchases, sales, required operating reserve, planned and unplanned outages results in an operable capacity margin of 1,337 MW for the peak week.

These resources represent all generation capability located physically within the New York geographic area that is able to participate in the New York ISO installed capacity market.

Supply-Side Resources

Since summer 2011, additions of 612 MW of additional resources have been added or are scheduled to be added to the New York system. There are approximately 496 MW of new generation since last summer. There were thirteen retirements in New York since summer 2011; Astoria Units 2 and 4 (180 and 380 MW respectively), Gowanus Barge Units 1 and 4 (160 MW each), Ravenswood GT 3-4 (43 MW) and Astoria GTs 10 and 11 (32 MW each) are in protective layup, while Barrett Unit #7 (20 MW), Binghamton Cogen (48 MW), Beebee CT 13 (18 MW), Far Rockaway (105 MW), and Glenwood units 4 and 5 (114 MW each) are retired. Total nameplate retirements are 1,403 MW.

New York currently has 1,383 MW of installed nameplate wind capacity, of which 252 MW is assumed available during the summer peak demand period.

Demand Response Resources

The New York ISO has had two load response programs for the New York Market in place since May 2001. The Special Case Resources (SCR) and Emergency Demand

Response Program (EDRP) are programs in which customers are paid to reduce their consumption by either interrupting load or switching to emergency standby generation when requested by the New York ISO.

EDRP participants voluntarily curtail load when requested by the New York ISO. SCR participants must, as part of their agreement, curtail power usage, usually by reducing load when asked by the New York ISO.

Participation in the Emergency Demand Response Program (EDRP) and Special Case Resources (SCR) programs represents an additional 1,912 MW from SCR and 24 MW of EDRP load relief available under peak conditions.

Transmission

The Consolidated Edison Gowanus Ring Bus project and Astoria East-Astoria Annex project will be in-service for the summer 2012 operating period. The Gowanus Ring Bus project consists of an upgrade to a ring bus configuration of the existing Gowanus straight bus to accommodate the interconnection of the Bayonne Energy Center. The Astoria East-Astoria Annex consists of a new line from the Astoria Annex 345 kV bus to the Astoria East 138 kV bus with 345/138 kV transformer and Phase Angle Regulator.

The Beck–Packard BP76 circuit is expected to be out-of-service through the summer operating period. The effects of the continuing outage of the New York (Niagara) to Ontario (Beck 2) 230 kV tie line have been taken into account in this assessment.

Ontario

The Independent Electricity System Operator (IESO) of Ontario is anticipating an operable capacity margin of 4,895 MW on the peak week based on the forecast weather normal demands. The lowest operable capacity margin forecast is 4,872 MW for the week beginning July 15, 2012.

Even though the net margins are all positive for the Summer Operating Period, there are risks associated with this analysis. Actual demands may be heavier than expected due to extreme weather, generators on outage that may not return to service as scheduled, or new generations may be delayed coming in service. The IESO will monitor the capacity margin and take appropriate actions to support the reliability of the grid.

This estimate of the operable capacity margin does not consider all the additional offmarket control actions available to the IESO. For example, the IESO can institute a 3% or 5% voltage reduction. These control actions can have the effect of reducing the demand by approximately 350 MW to 610 MW.

Supply-Side Resources

Since the summer of 2011, Ontario has decommissioned 980 MW of coal at Nanticoke G.S. and registered 314 MW of new renewable energy. As well, during the second

quarter of 2012, the IESO anticipates to begin commissioning an additional 750 MW of nuclear with the return of the Bruce Unit 2. As a result, the IESO begins the Summer Operating Period with an installed generating capacity of 35,436 MW. By the end of the assessment period, the installed capacity will increase by 750 MW to 36,186 MW. This increase is due to the return of 750 MW from Bruce Unit 1. The installed capacity number includes the nameplate rating of the various wind farms.

Ontario presently has 1,727 MW of wind capacity of which 7.2% is assumed available during the June, July and August period.

Demand Response Resources

Ontario utilizes demand respond initiatives that consist of reliability and real-time price demand response programs. These include the Demand Response 3 program and the Peaksaver program.

The Demand Response 3 (DR3) program was developed in 2008 by the Ontario Power Authority to provide an incentive for participants to lower consumption. DR3 is a contract based program where participants are required to reduce load when activated to receive an availability payment and utilization payment. Load reduction activation notices are sent to participants when a price threshold is exceeded and when the supply cushion falls below another threshold. DR-3 activation may not coincide with forecasted adequacy shortfalls. Currently, this program represents 286 MW of available load relief.

Peaksaver is an economic based demand response program created by the Ontario Power Authority to provide customers with an ability to manage demand during the predetermined scheduled periods noted for high demand and tight supply. It is a voluntary program and does not involve any financial settlements. The program provides for up to 40 hours of Load Control Events (activations) annually for specific hours on business days between May 1 and September 30. Activations last up to four hours but can be longer to address reliability concerns. The program is triggered when the IESO declares any level of Energy Emergency Alert (EEA1, EEA2 or EEA3) and communicates it using the System Status Report. If required, the program can also be triggered by primary demands or temperatures above pre-determined levels, or at the IESO’s discretion to deal with emergencies.

Transmission

For this Summer Operating Period, Ontario’s transmission system is expected to be adequate with planned transmission system enhancements and scheduled transmissions outages. Two new 500 kV circuits from Bruce to Milton are expected to be placed in service in May. Work at the Bruce switchyards to extend a 500 kV bus and complete the addition of terminal breakers for the two new Bruce − Milton circuits should be completed by the end of the 2012 summer assessment period.

The new 230 kV Hurontario switching station and expanded 230 kV lines are now in service helping to alleviate loadings in the Greater Toronto Area.

A new Static Var Compensator (SVC) at Porcupine Transformer Station (TS) and series capacitors on the two Essa−Hanmer 500 kV circuits have been installed. The Porcupine SVC will improve the ability to maintain an acceptable voltage profile in the North-east sub-area of Ontario. The increase in transfer capability between northern and southern Ontario attributed to the new series capacitors is waiting for finalized operating instructions.

As previously mentioned, the effects of the continuing outage of the New York (Niagara) to Ontario (Beck) 230 kV tie line have been taken into account in this assessment.

Phase angle regulators (PARs) are installed on the Ontario–Michigan interconnection at Lambton TS (L4D and L51D) and Keith (J5D) on the Ontario side and at Bunce Creek TS (B3N) in Michigan, representing the four interconnections with Michigan. Final regulatory approvals have been received, permitting operation of these facilities. Three PARS were placed in service prior to summer 2012 and are being used to manage circulation power flows around Lake Erie, as well as contingencies.

Québec

The Province of Québec is winter peaking. Adequate resources are forecast to be available to serve summer peak demand and meet operating reserve requirements. Québec is projecting weekly operable capacity margins in the range of 8,212 MW to 10,681 MW for the summer of 2012.

Supply-Side Resources

For the 2012 summer, total Installed Capacity for the Québec decreased slightly to 42,888 MW (August) from last summer’s capacity. Part of the decrease in installed capacity is due to the retirement of the Tracy oil-fired G.S. Last year, one unit had been retired and Hydro-Québec Production has now proceeded with the complete retirement of the G.S. for 2012. This retirement reduces installed capacity by 450 MW. Moreover, contractual capacity to Hydro- Québec Production has been reduced by 150 MW.

Since last summer, however, four new wind generating stations have been commissioned totaling 398 MW. In June, the St-Robert-Bellarmin wind project will be placed in service (80 MW) and in July, one unit of the La Sarcelle hydro G.S. (James Bay system) will be in service (50 MW). The last two La Sarcelle units are expected on-line later on after the Summer Operating Period.

Last summer’s assessment showed the three Eastmain-1-A units in service by September 2011; the last two units were placed in service in January and February 2012.

All of the 212 MW of wind capacity in Québec is under contract with Hydro-Québec Production. This is entirely situated in the Matapédia region of the system ─ around the Gaspésia peninsula near the Gulf of St-Lawrence. For this summer assessment, Québec assumed that the entire wind generation capacity is 100% derated.

Demand Response Resources

The two interruptible load programs in Québec are available only during the winter period.

Transmission

No new significant transmission is being placed in service for the 2012 summer period, but a 102 km (63 mile) 315 kV single-circuit line to integrate the La Sarcelle hydro generating station (150 MW) will be in-service for the summer period. However, only 50 MW at La Sarcelle will be in service during the 2012 summer period. Also, a number of wind generation integration projects are presently ongoing for in-service dates around the end of 2012.

Maritimes

The Maritime Provinces are also winter peaking. Adequate resources are forecast to be available to serve summer peak demand and meet operating reserve requirements. The Maritimes forecast net weekly operable capacity margins ranging from between 24% to 49% (representing 734 MW to 1,515 MW) over the period May through September 2012.

Supply-Side Resources

The Maritimes experienced a net increase of 72 MW of nameplate installed wind generation since the summer of 2011. Since the last summer assessment, the Dalhousie

thermal plant (96 MW + 203 MW) is scheduled to be retired on May 31, 2012. The Point Lepreau nuclear station is scheduled back on line by October 2012. This plant has been out of service since April 2008 for refurbishment.

The Maritimes Area currently has approximately 846 MW of nameplate installed wind capacity. Since the summer 2011 period, there has been an additional 72 MW of new wind generation. After applying derates, the current installed wind capacity is 138 MW.

Demand Response Resources

Interruptible and dispatchable loads are forecast on a weekly basis and range between 207 MW and 250 MW, and are available for use when corrective action is required.

Transmission

The Maritimes transmission system is projected to be adequate to supply the demand requirements for the 2012 summer period. No major transmission additions are planned for the 2012 summer period.

Estimated Need for Operating Procedures

A wide range of assumptions were analyzed, including extreme weather conditions derived through over 40 years of experience, unexpected plant outages, transmission constraints between and within regions, implementation of operating procedures and estimated impact of demand response programs.

In the probabilistic assessment, chronological system histories were developed by combining randomly generated operating histories of the generating units with the interarea transfer limits and the hourly chronological loads. Consequently, the system was modeled in great detail with accurate recognition of random events, such as equipment failures, peak load forecast uncertainty, as well as the deterministic rules and policies that govern system operation.

Figure 1 shows the expected use of the indicated operating procedures under the Base Case assumptions and the expected load level. The expected load level is based upon the probability-weighted average of the seven load levels simulated;

See the attachment for Figure 1.

Use of operating procedures designed to mitigate resource shortages (reducing 30-minute reserve, voltage reduction, and reducing 10-minute reserve) is not anticipated during the 2012 summer period under expected conditions. Slower economic growth than anticipated, coupled with the continuing impacts of conservation initiatives has resulted in a lower overall NPCC demand forecast compared to last year. Furthermore, new resources and transmission capacity resulting from transmission projects planned to be available by this summer are additional factors that act to minimize the expected need for the use of these operating procedures in 2012.

Operating procedures are available to maintain reliability for the unlikely simultaneous combination of severe system conditions (such as reductions in anticipated resources, delay of expected transmission projects and/or additional constraints) materializing coincident with higher than expected loads (such as caused by a wide spread, prolonged heat wave with high humidity and near record temperatures).

Operational Readiness

The Resource and Transmission Reliability Adequacy Assessments are key elements in determining NPCC’s ability to meet the forecast demands of the summer period. To be prepared to deal with the constantly changing operating conditions on the power system, as well as contingencies, NPCC routinely conducts daily and week-ahead planning calls between system operators and neighboring regions to coordinate short-term system operations.

NPCC continues to refine and expand its situational awareness capability to include wide-area visual displays of NPCC and its adjacent Regional Entities to further enable NPCC system operators and neighboring regions communicate current operating conditions and facilitate the procurement of assistance under emergency conditions.

Geomagnetic Storms

Solar activity is continuing to slowly increase towards what will eventually become a maximum in sunspot numbers sometime next year. However, the maximum of the sunspot cycle does not correlate with the maximum in geomagnetic activity to which the power grids are susceptible. The maximum in geomagnetic activity lags the sunspot cycle maximum by about 2 to 4 years. As a result, the potential for geomagnetically induced currents (GICs) will continue to slowly increase until the year 2015 to 2017 where a peak should be observed in geomagnetic and GIC activity.

Past experiences have shown the serious effect that geomagnetic disturbances can have on the NPCC bulk power system. These effects can include transformer failures, and unintentional tripping of transmission lines (outages) due to geomagnetically induced currents (GICs).

NPCC has operating procedures in-place to mitigate the effects of GICs resulting from geomagnetic storms. NPCC system operators receive, on a continual twenty-four hour by seven day basis, the status of solar activity and geomagnetic storm alerts.

After reviewing the available data, the system operator evaluates the situation and enacts appropriate measures designed to protect system elements such as transformers, transmission lines, generators, and other critical facilities.

NPCC

NPCC is one of eight Regional Entities located throughout the United States, Canada and portions of Mexico. NPCC’s geographic area includes the State of New York, the six New England states, Ontario, Québec, and the Canadian Maritime Provinces of New Brunswick and Nova Scotia.² NPCC coordinates international electric power grid reliability for Northeastern North America. NPCC annually performs comprehensive seasonal assessments of electricity supply and demand reliability for eastern Canada, New England and the City and State of New York. These assessments require months of detailed preparation and are performed with the participation of regional electricity power grid operators and planners.

Additional information regarding NPCC is available at: www.npcc.org.

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¹ Based on summer nameplate ratings.

² Includes the connected part of northern and eastern Maine.

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