nepool participants committee meeting boston, ma december 3, 2004

NEPOOL Participants Committee Meeting

Boston, MA

December 3, 2004

Stephen G. WhitleySenior Vice President & COO

2

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

Agenda

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:

Note: Natural Gas source is Algonquin Citygates Price.

Daily Natural Gas Price $7.50/MMBtu Daily Natural Gas Price $5.76/MMBtu

8

Day-Ahead–LMP Average by Zone & Hub:

(-7.33%)

(-2.65%)

(1.65%)(0.37%)

(-1.54%)

(-2.21%)

(0.48%)

(4.30%)

LMP Marginal Loss Component Congestion Component

November 1, 2004 to November 22, 2004 : Day-Ahead LMPs

9

97.4%

Real-Time-LMP Average by Zone & Hub:

LMP Marginal Loss Component Congestion Component

November 1, 2004 to November 22, 2004: Real Time LMPs

(-7.00%)

(-2.82%)

(1.16%) (1.06%)(-1.74%)

(-2.23%)

(0.17%)

(-1.70%)

10

Day - Ahead Market vs. Forecast Load

Day Ahead Market Demand Cleared vs. Forecast Load (%)

103 102 102

020406080

100120

September October November

November data represents November 1-November 22

Day Ahead Market Generation Cleared vs. Forecast Load (%)

93 91 93

0

20

40

60

80

100

September October November

November data represents November 1-November 22

11

Day - Ahead LMPDAM LMP October 26, 2004 Through November 23, 2004

20

30

40

50

60

70

80

90

100

110

10/2

6/20

04 0

1

10/2

8/20

04 0

1

10/3

0/20

04 0

1

10/3

1/20

04 2

4

11/0

2/20

04 2

4

11/0

4/20

04 2

4

11/0

6/20

04 2

4

11/0

8/20

04 2

4

11/1

0/20

04 2

4

11/1

2/20

04 2

4

11/1

4/20

04 2

4

11/1

6/20

04 2

4

11/1

8/20

04 2

4

11/2

0/20

04 2

4

11/2

2/20

04 2

4

Day

$/M

Wh

INTERNAL_HUB CONNECTICUT MAINE NEMASSBOST NEWHAMPSHIRE RHODEISLAND SEMASS VERMONT WCMASS

197 LINE (QUAKER HILL-THREE RIVERS) CONSTRAINED FOR LOSS OF 385 LINE (BUXTON-DEERFIELD) WITH 391 LINE (BUXTON-SCOBIE)

Out of ServiceBOSTON INTERFACE CONSTRAINED DUE TO 339 LINE Out of Service

BOSTON INTERFACE CONSTRAINED DUE TO THE

B154, S145, 329-512, AND 211-504 LINES Out of Service

BOSTON INTERFACE CONSTRAINED DUE TO 346 LINE

Out of Service

BOSTON INTERFACE CONSTRAINED DUE TO 282-

602, T146, 211-503, AND C155 LINES Out of Service.

12

Real - Time LMPReal-Time LMP October 26, 2004 Through November 23, 2004

0

20

40

60

80

100

120

140

160

10/2

6/20

04 0

1

10/2

8/20

04 0

1

10/3

0/20

04 0

1

10/3

1/20

04 2

4

11/0

2/20

04 2

4

11/0

4/20

04 2

4

11/0

6/20

04 2

4

11/0

8/20

04 2

4

11/1

0/20

04 2

4

11/1

2/20

04 2

4

11/1

4/20

04 2

4

11/1

6/20

04 2

4

11/1

8/20

04 2

4

11/2

0/20

04 2

4

11/2

2/20

04 2

4

Day

$/M

Wh

INTERNAL_HUB CONNECTICUT MAINE NEMASSBOST NEWHAMPSHIRE RHODEISLAND SEMASS VERMONT WCMASS

MINIMUM GENERATION EMERGENCY FROM 05:45 -

07:00.

1810-3 LINE (CHIPPEN HILL-LAKE AVE TAP) CONSTRAINED FOR LOSS OF

1191 LINE (FROST BRIDGE-CAMPVILLE) WITH 1784 LINE (NORTH BLOOM-NORTH SIMSBURY-CANTON)

Out of Service

EVENING LOAD PICKUP

13

Settlement Data – Real Time & Balancing Market

Minimum % of Real-Time Load Fully Hedged Through ISO-NE Settlement System

70% 71%71%

75%75%

75%73%

71%

71%

77%74%

72%

68%

71%

73%

71% 71%72%

70%

50%

55%

60%

65%

70%

75%

80%

Jun

02 -

May

03 A

vera

ge

Jun-

03

Jul-0

3

Aug-0

3

Sep-0

3

Oct-0

3

Nov-0

3

Dec-0

3

Jan-

04

Feb-0

4

Mar

-04

Apr-0

4

May

-04

Jun-

04

Jul-0

4

Aug-0

4

Sep-0

4

Oct-0

4

Nov-0

4

Month

% R

T L

oad

Fu

lly

Hed

ged

14

RMR and Economic Operating Reserve Payments

RMR & Economic Operating Reserve Payments

$0

$2,500,000

$5,000,000

$7,500,000

$10,000,000

$12,500,000

$15,000,000

$17,500,000

$20,000,000

Jan-0

4

Feb-0

4

Mar

-04

Apr-04

May

-04

Jun-0

4

Jul-0

4

Aug-04

Sep-0

4

Oct

-04

DA RMR DA Economic RT RMR RT EconomicNote: July-October subject to 90-Day Resettlement

15

Monthly VAR Support and SCR PaymentsMonthly VAR Support and SCR Payments

$0

$2,000,000

$4,000,000

$6,000,000

$8,000,000

$10,000,000

$12,000,000

$14,000,000

$16,000,000

$18,000,000

Jan-

04*

Feb-

04*

Mar

-04*

Apr-0

4*

May

-04*

Jun-

04*

Jul-0

4

Aug-0

4

Sep-

04

Oct-0

4

DA VAR RT VAR RT SCR * - denotes 90-Day Resettlement values reflected

16

Winter Outlook

17

Winter 2004-05 Capacity Assessment 50/50 Forecast

December ’04 through March ’05Conditions for Week of Lowest Operable Capacity Margin

Week beginning January 15th

MWProjected Peak (50/50) 22,370 Operating Reserve Required 1,700Total Operable Cap. Required 24,070Projected Capacity 32,710Assumed Outages 6,500Total Capacity 26,210Operable Capacity Margin 2,140

18

Winter 2004-05 Capacity

AssessmentWeek Beginning, Saturday

Year Month Day

Installed Seasonal Claimed

Capability (SCC)

[Note 1]

Interchange (NYPP, NB, HQ, Highgate, Block Load)

No

te

New Generation

[Note 2]

De-listed ICAP

Resources [Note 3]

Net Capacity [Note 4]

Peak Load Exposure [Note 5]

Operating Reserve

Requirement [Note 6]

Total Known Maintenance

Allowance for Unplanned

Outages [Note 7]

Generation at Risk Due

to Gas Supply [Note 8]

Total Capacity

Operable Capacity

Margin (+/-)

Extent of OP 4 Actions That May be Necessary (OP 4

Actions up to and including) [Note 9]

(MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW)2004 December 4 33,220 360 0 2,660 30,920 21,263 1,700 700 3,200 0 27,020 4,060

11 33,220 360 0 2,660 30,920 21,554 1,700 400 3,200 0 27,320 4,070 18 33,220 360 0 2,660 30,920 21,565 1,700 100 3,200 0 27,620 4,360 25 33,220 360 0 2,660 30,920 21,627 1,700 100 3,200 0 27,620 4,290

2005 January 1 33,206 450 0 950 32,710 21,902 1,700 100 2,800 2,250 27,560 3,960 8 33,206 450 0 950 32,710 22,370 1,700 700 2,800 2,800 26,410 2,340 15 33,206 450 0 950 32,710 22,370 1,700 900 2,800 2,800 26,210 2,140 22 33,206 450 0 950 32,710 22,370 1,700 600 2,800 2,800 26,510 2,440 29 33,217 450 0 950 32,720 22,146 1,700 700 3,100 2,250 26,670 2,820

2005 February 5 33,217 450 0 950 32,720 21,878 1,700 600 3,100 2,250 26,770 3,190 12 33,217 450 0 950 32,720 21,849 1,700 1,100 3,100 2,250 26,270 2,720 19 33,217 450 0 950 32,720 21,585 1,700 1,800 3,100 0 27,820 4,540 26 33,229 450 0 950 32,730 20,592 1,700 2,300 2,200 0 28,230 5,940

2005 March 5 33,229 450 0 950 32,730 20,240 1,700 2,400 2,200 0 28,130 6,190 12 33,229 450 0 950 32,730 20,044 1,700 2,900 2,200 0 27,630 5,890 19 33,229 450 0 950 32,730 19,677 1,700 3,200 2,200 0 27,330 5,950 26 33,229 450 0 950 32,730 19,108 1,700 2,400 2,200 0 28,130 7,320

Notes: Please note that the information contained within the Capacity Analysis is a deterministic projection of system conditions which could materialize during any given week of the year.1. Installed Capability per November 1, 2004 SCC Report, less recent retirements or deactivations that have not yet been reflected in the SCC Report. The Operable Capability does not reflect possible

transmission constraints within the NEPOOL system.2. New Generation information includes 1) generation recently commercial but not yet reflected in the NEPOOL SCC Report totals used in the Installed Capability Column, and 2) future generation

as assumed by ISO-NE Planning Department. This value is rounded to the nearest hundred.3. De-listed ICAP quantities are only known with certainty in the current month, however when contract sales are known the de-listed ICAP quantitiy is extended through the contract period.

This number is adjusted when a delisted generator is out on maintenance to avoid double counting.4. Net Capacity = (SCC) + (Interchange) + (New Generation) - (De-listed ICAP Resources). In this equation, the SCC, Interchange and De-listed ICAP values are rounded to the nearest ten

and New Generation is rounded to the nearest hundred.5. Peak Load Exposure reflects values published in the April 2004 CELT Report. 6. Operating Reserve Requirement based on the first contingency (Generator at 1160 MW) plus 1/2 the second contingency (Generator at 1155 MW).7. Allowance for Unplanned Outages includes: forced outages and maintenance outages scheduled less than 14 days in advance.8. Assumed values based on ISO-NE study. 9. Relief from certain OP 4 Actions varies, depending on system conditions.

This analysis is a tabulation of weekly assessments shown in one single table. The information shows the operable capacity situation under assumed conditions for each week. It is not expected that the system peak will occur every week during June, July and August.

ISO-NE 2004 OPERABLE CAPACITY ANALYSISNovember 30, 2004 - WITH KNOWN EXTERNAL CONTRACTS - 50/50 FORECAST

19


AssessmentNEPOOL Operating Capacity Margins WITH KNOWN EXTERNAL TRANSACTIONS - 50/50 FORECAST

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

10,000

11,000

12,0004-

Dec

11-D

ec

18-D

ec

25-D

ec

1-Ja

n

8-Ja

n

15-J

an

22-J

an

29-J

an

5-F

eb

12-F

eb

19-F

eb

26-F

eb

5-M

ar

12-M

ar

19-M

ar

26-M

ar

December 2004 - March 2005, W/B Saturday

Ope

ratin

g C

apac

ity M

argi

n (M

W)

20

Winter 2004-05 Capacity Assessment 90/10 Forecast December ’04 through March ’05Conditions for Week of Lowest Operable Capacity Margin

Weeks beginning January 8th – 22nd

MWProjected Peak (90/10) 23,255 Operating Reserve Required 1,700Total Operable Cap. Required 24,955Projected Capacity 32,710 Assumed Outages 7,000Total Capacity 25,710Operable Capacity Margin 755Assumed 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


AssessmentWeek Beginning, Saturday

Year Month Day

Installed Seasonal Claimed

Capability (SCC)

[Note 1]

Interchange (NYPP, NB, HQ, Highgate, Block Load)

No

te

New Generation

[Note 2]

De-listed ICAP

Resources [Note 3]

Net Capacity [Note 4]

Peak Load Exposure [Note 5]

Operating Reserve

Requirement [Note 6]

Total Known Maintenance

Allowance for Unplanned

Outages [Note 7]

Generation at Risk Due

to Gas Supply [Note 8]

Total Capacity

Operable Capacity

Margin (+/-)

Extent of OP 4 Actions That May be Necessary (OP 4

Actions up to and including) [Note 9]

(MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW) (MW)2004 December 4 33,220 360 0 2,660 30,920 22,105 1,700 700 3,200 0 27,020 3,220

11 33,220 360 0 2,660 30,920 22,407 1,700 400 3,200 0 27,320 3,210 18 33,220 360 0 2,660 30,920 22,419 1,700 100 3,200 0 27,620 3,500 25 33,220 360 0 2,660 30,920 22,484 1,700 100 3,200 0 27,620 3,440

2005 January 1 33,206 450 0 950 32,710 22,769 1,700 100 2,800 4,100 25,710 1,240 8 33,206 450 0 950 32,710 23,255 1,700 700 2,800 3,500 25,710 760 15 33,206 450 0 950 32,710 23,255 1,700 900 2,800 3,300 25,710 760 22 33,206 450 0 950 32,710 23,255 1,700 600 2,800 3,600 25,710 760 29 33,217 450 0 950 32,720 23,022 1,700 700 3,100 3,200 25,720 1,000

2005 February 5 33,217 450 0 950 32,720 22,743 1,700 600 3,100 3,300 25,720 1,280 12 33,217 450 0 950 32,720 22,713 1,700 1,100 3,100 2,800 25,720 1,310 19 33,217 450 0 950 32,720 22,439 1,700 1,800 3,100 0 27,820 3,680 26 33,229 450 0 950 32,730 21,406 1,700 2,300 2,200 0 28,230 5,120

2005 March 5 33,229 450 0 950 32,730 21,041 1,700 2,400 2,200 0 28,130 5,390 12 33,229 450 0 950 32,730 20,836 1,700 2,900 2,200 0 27,630 5,090 19 33,229 450 0 950 32,730 20,455 1,700 3,200 2,200 0 27,330 5,180 26 33,229 450 0 950 32,730 19,864 1,700 2,400 2,200 0 28,130 6,570

Notes: Please note that the information contained within the Capacity Analysis is a deterministic projection of system conditions which could materialize during any given week of the year.1. Installed Capability per November 1, 2004 SCC Report, less recent retirements or deactivations that have not yet been reflected in the SCC Report. The Operable Capability does not reflect possible

transmission constraints within the NEPOOL system.2. New Generation information includes 1) generation recently commercial but not yet reflected in the NEPOOL SCC Report totals used in the Installed Capability Column, and 2) future generation

as assumed by ISO-NE Planning Department. This value is rounded to the nearest hundred.3. De-listed ICAP quantities are only known with certainty in the current month, however when contract sales are known the de-listed ICAP quantitiy is extended through the contract period.

This number is adjusted when a delisted generator is out on maintenance to avoid double counting.4. Net Capacity = (SCC) + (Interchange) + (New Generation) - (De-listed ICAP Resources). In this equation, the SCC, Interchange and De-listed ICAP values are rounded to the nearest ten

and New Generation is rounded to the nearest hundred.5. Peak Load Exposure reflects values published in the April 2004 CELT Report. 6. Operating Reserve Requirement based on the first contingency (Generator at 1160 MW) plus 1/2 the second contingency (Generator at 1155 MW).7. Allowance for Unplanned Outages includes: forced outages and maintenance outages scheduled less than 14 days in advance.8. Assumed values based on ISO-NE study. 9. Relief from certain OP 4 Actions varies, depending on system conditions.

This analysis is a tabulation of weekly assessments shown in one single table. The information shows the operable capacity situation under assumed conditions for each week. It is not expected that the system peak will occur every week during June, July and August.

ISO-NE 2004 OPERABLE CAPACITY ANALYSISNovember 30, 2004 - WITH KNOWN EXTERNAL CONTRACTS - 90/10 FORECAST

22


AssessmentNEPOOL Operating Capacity Margins WITH KNOWN EXTERNAL TRANSACTIONS - 90/10 FORECAST

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

10,000

11,000

12,0004-

Dec

11-D

ec

18-D

ec

25-D

ec

1-Ja

n

8-Ja

n

15-J

an

22-J

an

29-J

an

5-F

eb

12-F

eb

19-F

eb

26-F

eb

5-M

ar

12-M

ar

19-M

ar

26-M

ar

December 2004 - March 2005, W/B Saturday

Ope

ratin

g C

apac

ity M

argi

n (M

W)

23

Back-Up Detail

24

Demand Response

25

Demand Response(as of November 30, 2004)

ReadyTo Respond: Approved:Zone Assets Total MW Assets Total MW

CT 161 125.9 16 21.9ME 8 104.5 0 0.0NEMA 114 45.1 1 24.0NH 5 11.1 0 0.0RI 11 2.8 0 0.0SEMA 81 8.8 1 0.1VT 17 13.5 0 0.0WCMA 96 24.2 1 0.3

Total 493 335.8 19 46.3

26

Demand Response, Con’t. (as of November 30, 2004)

* SWCT assets are included in CT values and are not included in Total

493 Assets 335.8 MW 19 Assets 46.3 MWZone Assets RT Price RT 30-Min RT 2-Hour Profiled Assets RT Price RT 30-Min RT 2-Hour Profiled

CT 161 31.8 93.7 0.4 0.0 16 9.0 12.9 0.0 0.0

SWCT* 108 5.2 68.4 0.4 0.0 14 0.0 12.9 0.0 0.0

ME 8 27.5 0.0 1.0 76.0 0 0.0 0.0 0.0 0.0

NEMA 114 38.9 3.3 1.5 1.4 1 0.0 24.0 0.0 0.0

NH 5 10.7 0.4 0.0 0.0 0 0.0 0.0 0.0 0.0

RI 11 2.8 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0

SEMA 81 8.3 0.5 0.0 0.0 1 0.1 0.0 0.0 0.0

VT 17 7.5 0.1 0.0 5.9 0 0.0 0.0 0.0 0.0

WCMA 96 12.6 2.3 9.3 0.0 1 0.0 0.3 0.0 0.0

Total 493 140.0 100.4 12.3 83.2 19.0 9.1 37.2 0.0 0.0

Ready To Respond: Approved:

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. MWIn Construction 1 8.4with 18.4 approval

Not in Construction 5 1,271with 18.4 Approval

Not in Construction 4 213Nuclear 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

RTEP Project Stage Descriptions

Stage Description

1 Planning and Preparation of Project Configuration

2 Pre-construction (e.g., material ordering, project scheduling)

3 Construction in Progress

4 Completed

33

NSTAR 345 kV Transmission Reliability ProjectStatus as of 11/30/04Project Benefit: Improves New England reliability by

addressing Boston Area concerns and increasing Boston Import Limit from 3,600 MW to approximately 4,500 MW.

UpgradeExpectedIn-service

OriginalIn-service

Present Stage

Stoughton 345 kV Substation Jun-06 Jun-06 1Stoughton - Hyde Park 345 kV Jun-06 Jun-06 1Stoughton - K Street 345 kV #1 Jun-06 Jun-06 1

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.

Phase 2

Phase 1

- Received RC recommendation for 18.4 (conditional) and 12C approval 7-29-04.

34

North Shore UpgradesStatus as of 11/30/04

Project Benefit: Maintains system reliability for the North Shore area independent of Salem Harbor generation.


OriginalIn-service

Present Stage

Add 3 transformers at Ward Hill Jun-06 Jun-06 1Reconductor several 115kV lines Jun-06 Jun-06 1Salem Harbor capacitor banks Jun-06 Jun-06 1

New Wakefield Junction SS Jun-08 1

Notes:- MA DTE review in progress; ruling due 4th quarter 2004

Wakefield Junction

Ward Hill Upgrades

- 18.4 application for Ward Hill upgrades expected in 4th quarter 2004

Jun-08

35

SWCT 345 kV Transmission Reliability ProjectStatus as of 11/30/04Project Benefit: Improves New England reliability by

addressing SWCT concerns. Increases SWCT Import Limit from 2,000 MW to approximately 3,400 MW.


OriginalIn-service

Present Stage

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

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

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.

Phase 2

Phase 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.

36

Northeast Reliability Interconnect ProjectStatus as of 11/30/04

Project Benefit: Improves New England reliability by improving inter-area transfer capability and eliminating various protection/stability concerns.


OriginalIn-service

Present 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 ProjectStatus as of 11/30/04

Project Benefit: Improves New England reliability by addressing NWVT concerns, bringing another source into the Burlington area.


OriginalIn-service

Present Stage

New Haven 345 kV Substation May-06 Oct-05 1West Rutland - New Haven 345 kV May-06 Nov-05 1New Haven - Queen City 115 kV Oct-06 Oct-06 1Granite 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 ProjectStatus as of 11/30/04

Project Benefit: Improves New England reliability by increasing transfer limits of three critical interfaces, including Connecticut Import Limit


OriginalIn-service

Present Stage

Millbury - Sherman Rd. 345 kV Dec-08 Dec-08 1Sherman 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

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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

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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:

[email protected]

mailto:[email protected]

nepool participants committee meeting boston, ma december 3, 2004

Documents