NEPOOL Participants Committee Meeting Boston, MA December 3, 2004

1. NEPOOL Participants Committee Meeting Boston, MA December 3, 2004 Stephen G. Whitley Senior Vice President & COO

2. Agenda • System Operations • Market Operations • Winter 2004/2005 Outlook • Back-Up Detail

3. System Operations

4. Operations Highlights • Boston & Hartford Weather Pattern: • Temperatures were slightly higher than normal with below normal precipitation in November. • Peak load of 18,985 MW at 18:00 hours on November 9, 2004. • During November: • NPCC Shared Activation of Reserve Events: • November 7 PJM – SMD K9 @500 Mw • November 8 Lennox #1 @500 Mw • November 10 Bruce #8 @800 Mw • November 21 Granite Ridge @702 Mw • November 22 Bruce #3 @800Mw • November 23 Mystic #9 @504 & 704 Mw • November 26 Indian Point #2 @950 Mw • November 28 Darlington #4 @950 Mw

5. Operations Highlights, Con’t. • Minimum Generation: • November 21 0545 – 0700 hours • November 26 0200 – 0500 hours • November 28 0300 – 0500 hours • November 29 0100 – 0300 hours • MS 2 Implemented • November 7 – 8 2115 hours (11/7) thorough 0930 hours (11/8) due to SMD K9 Activity • November 9 – 10 1445 hours (11/09) through 0930 hours (11/10) due to SMD K9 Activity

6. Market Operations

7. Day–Ahead & Real-Time Prices, ISO Hub:

8. Congestion Component LMP Marginal Loss Component Day-Ahead–LMP Average by Zone & Hub: November 1, 2004 to November 22, 2004 : Day-Ahead LMPs (4.30%) (1.65%) (-2.65%) (0.37%) (0.48%) (-1.54%) (-2.21%) (-7.33%)

9. Congestion Component LMP Marginal Loss Component Real-Time-LMP Average by Zone & Hub: November 1, 2004 to November 22, 2004: Real Time LMPs 97.4% (1.06%) (1.16%) (0.17%) (-1.70%) (-1.74%) (-2.23%) (-2.82%) (-7.00%)

10. Day - Ahead Market vs. Forecast Load

11. Day - Ahead LMP

12. Real - Time LMP

13. Settlement Data – Real Time & Balancing Market

14. RMR and Economic Operating Reserve Payments

15. Monthly VAR Support and SCR Payments

16. Winter Outlook

17. Winter 2004-05 Capacity Assessment 50/50 Forecast December ’04 through March ’05 Conditions for Week of Lowest Operable Capacity Margin Week beginning January 15th MW Projected Peak (50/50) 22,370 Operating Reserve Required 1,700 Total Operable Cap. Required 24,070 Projected Capacity 32,710 Assumed Outages 6,500 Total Capacity 26,210 Operable Capacity Margin 2,140

18. Winter 2004-05 Capacity Assessment

19. Winter 2004-05 Capacity Assessment

20. Winter 2004-05 Capacity Assessment 90/10 Forecast December ’04 through March ’05 Conditions for Week of Lowest Operable Capacity Margin Weeks beginning January 8th –22nd MW Projected Peak (90/10) 23,255 Operating Reserve Required 1,700 Total Operable Cap. Required 24,955 Projected Capacity 32,710 Assumed Outages 7,000 Total Capacity 25,710 Operable Capacity Margin 755 Assumed outages are based on Jan. 2004 Cold Snap experience (9,000 MW of total outage) adjusted for 2,000 MW of capacity expected to be available as result of preliminary Cold Snap Initiatives.

21. Winter 2004-05 Capacity Assessment

22. Winter 2004-05 Capacity Assessment

23. Back-Up Detail

24. Demand Response

25. Demand Response(as of November 30, 2004)

26. Demand Response, Con’t. (as of November 30, 2004) * SWCT assets are included in CT values and are not included in Total

27. New Generation

28. New Generation Update • No new resources were added in November. • No additional capacity expected on line by the end of the year. • Status of Generation Projects as of November 30, 2004: No.MW In Construction 1 8.4 with 18.4 approval Not in Construction 5 1,271 with 18.4 Approval Not in Construction 4 213 Nuclear Uprates with 18.4 approval

29. RTEP

30. RTEP Update • RTEP05 • Draft load forecast under review • Scope of work under development • RTO and related transitional issues to the Regional System Expansion Plan (RSEP) have been identified • Working towards better coordination of TEAC/Planning Advisory Committee (PAC) meetings with the RC

31. Inter-ISO Update • Northeastern ISO/RTO Planning Coordination Protocol • Signed by PJM and NYISO • Signature by ISO-NE anticipated very soon • Next Steps • Initial joint draft consolidated plan under development • Form Joint ISO/RTO Planning Committee • Exchange system plans and SIS queues • Initiate Inter-area Planning Stakeholder Advisory Committee • Develop joint website • Filing to FERC on the Second Amended and Restated Interregional Coordination and Seams Issue Resolution Agreement due 12/3 • NERC Blackout issues being addressed through NPCC

32. Stage Description 1 Planning and Preparation of Project Configuration 2 Pre-construction (e.g., material ordering, project scheduling) 3 Construction in Progress 4 Completed RTEP Project Stage Descriptions

33. NSTAR 345 kV Transmission Reliability Project Status as of 11/30/04 Project Benefit: Improves New England reliability by addressing Boston Area concerns and increasing Boston Import Limit from 3,600 MW to approximately 4,500 MW. Expected Original Present Upgrade In-service In-service Stage Phase 1 Stoughton 345 kV Substation Jun-06 Jun-06 1 Stoughton - Hyde Park 345 kV Jun-06 Jun-06 1 Stoughton - K Street 345 kV #1 Jun-06 Jun-06 1 Phase 2 Stoughton - K Street 345 kV #2 Dec-07 Dec-07 1 Notes: - Siting review in progress; ruling due 4th quarter 2004. - Detailed engineering in progress. - Received RC recommendation for 18.4 (conditional) and 12C approval 7-29-04.

34. North Shore Upgrades Status as of 11/30/04 Project Benefit: Maintains system reliability for the North Shore area independent of Salem Harbor generation. Expected Original Present Upgrade In-service In-service Stage Ward Hill Upgrades Add 3 transformers at Ward Hill Jun-06 Jun-06 1 Reconductor several 115kV lines Jun-06 Jun-06 1 Salem Harbor capacitor banks Jun-06 Jun-06 1 Wakefield Junction New Wakefield Junction SS Jun-08 1 Jun-08 Notes: - MA DTE review in progress; ruling due 4th quarter 2004 - 18.4 application for Ward Hill upgrades expected in 4th quarter 2004

35. SWCT 345 kV Transmission Reliability Project Status as of 11/30/04 Project Benefit: Improves New England reliability by addressing SWCT concerns. Increases SWCT Import Limit from 2,000 MW to approximately 3,400 MW. Expected Original Present Upgrade In-service In-service Stage Phase 1 Norwalk 345 kV Substation Nov-05 Dec-04 2 Plumtree 345 kV Substation Nov-05 Dec-04 2 Norwalk - Plumtree 345 kV Nov-05 Dec-04 2 Associated 115 kV Line Work Nov-05 Dec-04 2 Phase 2 Beseck 345 kV Substation Dec-07 Jan-06 1 East Devon 345 kV Substation Dec-07 Jan-06 1 Singer 345 kV Substation Dec-07 Jan-06 1 Beseck - East Devon 345 kV Dec-07 Jan-06 1 East Devon - Singer 345 kV Dec-07 Jan-06 1 Singer - Norwalk 345 kV Dec-07 Jan-06 1 Associated 115 kV Line Work Dec-07 Jan-06 1 Note: - “Expected In-service” dates differ from those listed on the NU website (Phase I is listed as May-06 and Phase II is listed as May-09); however, no official notice has been given to ISO-NE as to the slip in timing. Notes Phase 1: - Siting review complete; appeal denied. - Detailed engineering in progress. - Modification may become necessary to mitigate harmonic resonance/transient overvoltage concerns. Notes Phase 2: - Siting review in progress, ruling due April 2005. - Modification may become necessary to mitigate harmonic resonance/transient overvoltage concerns.

36. Northeast Reliability Interconnect Project Status as of 11/30/04 Project Benefit: Improves New England reliability by improving inter-area transfer capability and eliminating various protection/stability concerns. Expected Original Present Upgrade In-service In-service Stage Orrington, ME - Pt. Lepreau, NB 345 kV Dec-07 Dec-08 1 Notes: - Siting approved for Canadian section of line. - DOE & Maine DEP review processes (approx. 1 year) have started.

37. NWVT 345 kV Transmission Reliability Project Status as of 11/30/04 Project Benefit: Improves New England reliability by addressing NWVT concerns, bringing another source into the Burlington area. Expected Original Present Upgrade In-service In-service Stage New Haven 345 kV Substation May-06 Oct-05 1 West Rutland - New Haven 345 kV May-06 Nov-05 1 New Haven - Queen City 115 kV Oct-06 Oct-06 1 Granite STATCOM/Upgrades Oct-07 Oct-07 1 Notes: - Siting review in progress, ruling due January 2005. - Sandbar Phase Angle Regulator in service.

38. Southern New England Reliability Project Status as of 11/30/04 Project Benefit: Improves New England reliability by increasing transfer limits of three critical interfaces, including Connecticut Import Limit Expected Original Present Upgrade In-service In-service Stage Millbury - Sherman Rd. 345 kV Dec-08 Dec-08 1 Sherman Rd. - Lake Rd. 345 kV Dec-08 Dec-08 1 Lake Rd. - Card St. 345 kV Dec-08 Dec-08 1 345 kV Substation Modifications Dec-08 Dec-08 1 Notes: - Planning studies in progress; estimated completion summer 2005. - Project specifics may change; alternatives still under review.

39. Transmission Siting Update • SWCT • Phase I • Received conditional approval from Connecticut Siting Council 2/11/04. • Phase II • ISO, NU and UI submitted the second Reliability and Operating Committee (ROC) harmonics/overvoltage report on October 8. Study work continues and the next report is scheduled for completion December 22. • Next hearing dates likely to be the week of December 13. Topics are KEMA and ABB proposals/studies. • BOSTON • New Boston 1 needed until NSTAR completes 345 kV Reliability Project from Stoughton to Hyde Park and K Street (2006 earliest) • Received RC recommendation for 18.4 (conditional) and 12C approval on 7/29/04. • Additional analysis of harmonics/transient overvoltage expected 4Q 2004. • Salem Harbor needed at least until NGRID North Shore upgrades (2006 earliest) • These units provide operating reserves for the current system as well as insurance for delays in transmission projects. • Long-term solution is functioning Resource Adequacy market to incent generation to locate in the most appropriate areas, with the ability to do gap RFP’s to address timing issues. • NWVT • State hearing process continues • Surrebuttal hearings held late September • Decision expected by January 2005

40. Compliance

41. 2004/2005 Compliance Update • A4: Minimum Maintenance for Bulk Power System (BPS) Protection • Survey documents were transmitted to Lead Participants with responsibility for BPS facilities in 11/04 • Responses to ISO-NE survey are required by 1/7/05. • Effort to confirm that all intended recipients have received documents is set to begin

42. 2004/2005 Compliance Update • A3-4.9: Generator Underfrequency Tripping • 2004 Survey • 3 Participants currently maintain generators with non-compliant trip settings • 2 participants’ facilities (nuclear plants) are exempt • ISO-NE will need to take measures to enforce compliance by the third participant • 2005 Survey • Survey documents will be transmitted to participants in March 2005 • Document preparation is almost complete

43. 2004/2005 Compliance Update • A3-4.6: Under-frequency Load Shedding • 2004 Survey • All Participants surveyed responded to the ISO-NE Survey • ISO-NE reported full compliance with this Standard to NPCC • 2005 Survey • Survey documents will be transmitted to participants in March 2005 • Document preparation is almost complete

44. Ombudsman

45. Ombudsman Responsibilities • ISO’s Intermediary for Customers • The Ombudsman role does not replace the Customer Service & Training Call Tracking Process • Investigates High-level Inquiries • The Ombudsman is a contact for participant senior management • Acts to Resolve Inquiries • Reports on Findings • Logs and tracks issues as necessary

46. ISO’s Ombudsman • Richard Berryman (Rich) • Office 413.535.4315 • Fax 413.540.4530 • Email: rberryman@iso-ne.com