NEPOOL Participant’s Meeting

Boston, MA

May 7, 2004

Stephen G. WhitleySenior Vice President & COO

2

• System Operations• Market Operations• Day-ahead Market – April 19, 2004• Electric and Gas Wholesale

Initiative• Summer Capacity• Back-Up Detail

Agenda

3

System Operations

4

Operations Highlights

• Boston & Hartford Weather Pattern: – April 2004 had normal to above normal temperatures. The

precipitation was near record highs. Most areas doubled the amount of normal precipitation.

• Peak load of 17,884 MW at 20:00 hours on April 1, 2004.• During April:

– NPCC Shared Activation of Reserve Events:• April 6 L/O Bruce G8 @821 MW• April 11 L/O Mystic #9 @600

MW

5

Market Operations

6

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

7

Day-Ahead–LMP Average by Zone & Hub:

April 1, 2004 to April 23, 2004

NOTE: Corrected Day-Ahead LMPs for April 19 have been used.

(-9.84)

(-2.61)(1.27) (0.52) (-1.30)

(-2.88)(0.15)

(-1.86)

8

97.4%

Real-Time-LMP Average by Zone & Hub:

April 1, 2004 to April 23, 2004

(-6.66)(-2.00) (0.08)

(0.80)(-1.12)

(-2.80)(0.13) (-1.63)

(-7.88)(-2.41)

(0.60) (0.88)(-2.93)(-1.20) (0.10)

(-1.95)

9

Day - Ahead Market vs. Forecast Load

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

98 100 101

020406080

100120

February March April

Feb & March represent data for full month. April data represents April 1-23, 2004

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

979793

0

20

40

60

80

100

February March April

Feb & March represent data for full month. April data represents April 1-23, 2004

10

Day - Ahead LMPDAM LMP Through April 23, 2004 Revised

20

30

40

50

60

70

80

90

100

04/0

1/20

04 0

1

04/0

3/20

04 0

1

04/0

5/20

04 0

2

04/0

7/20

04 0

2

04/0

9/20

04 0

2

04/11

/200

4 02

04/1

3/20

04 0

2

04/1

5/20

04 0

2

04/1

7/20

04 0

2

04/1

9/20

04 0

2

04/2

1/20

04 0

2

04/2

3/20

04 0

2

Day

$/M

Wh

INTERNAL_HUB CONNECTICUT MAINE NEMASSBOST NEWHAMPSHIRE RHODEISLAND SEMASS VERMONT WCMASS

CONSTRAINT DUE TO PV20 SCHEDULED OOS FOR MAINTENANCE.

CONSTRAINT DUE TO LOAD AND GENERATION PATTERN WITH 379 TERMINAL OOS FROM 4/8/04-4/10/04.

CONSTRAINT DUE TO LOAD AND GENERATION PATTERN.

CONSTRAINT DUE TO LOAD AND GENERATION PATTERN WITH LINE OOS FROM 4/19/04-4/21/04.

K22 LINE CONSTRAINED DUE TO LOSS

OF K21 LINE. ADDITONALLY, A UNIT

WAS OFF LINE AND 381 LINE OUT OF

SERVICE.

11

Real - Time LMP

Real-Time LMP Through April 23, 2004

0

20

40

60

80

100

120

04/0

1/20

04 0

1

04/0

3/20

04 0

1

04/0

5/20

04 0

2

04/0

7/20

04 0

2

04/0

9/20

04 0

2

04/11

/200

4 02

04/1

3/20

04 0

2

04/1

5/20

04 0

2

04/1

7/20

04 0

2

04/1

9/20

04 0

2

04/2

1/20

04 0

2

04/2

3/20

04 0

2

Day

$/M

Wh

INTERNAL_HUB CONNECTICUT MAINE NEMASSBOST NEWHAMPSHIRE RHODEISLAND SEMASS VERMONT WCMASS

TIGHT CAPACITY CONDITIONS IN HE

08 DURING MORNING LOAD

PICKUP

TIGHT CAPACITY CONDITIONS

DURING PEAK LOAD PERIOD. LOADS

RAN OVER FORECAST BY 800

MW FOR HE 20.

TIGHT CAPACITY CONDITIONS DURING THE

PEAK LOAD PERIOD.

APPROACHING MINIMUM GENERATION EMERGENCY

CONDITIONS IN HE 04.

12

Settlement Data – Real - Time & Balancing Market

Percentage of Real-Time Load Fully Hedged Through ISO-NE

Settlement System*

73%

75%77%

75%75%

71%71%71%71%

73%

73%

71%72%

73%72%

66%

70%

73%73%

50%

55%

60%

65%

70%

75%

80%

Nov-0

1 - O

ct-0

2

Nov-0

2

Dec-0

2

Jan-

03

Feb-0

3

Mar

-03

Apr-0

3

May

-03

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

Month

% R

T L

oad

Fu

lly

Hed

ged

NOTE: REPRESENTS APRIL 1 - 24, 2004 DATA

* Post-SMD data ignores intra-pool LMP differences

13

Day-ahead Market – April 19, 2004

14

Summary of Event

• The Day-Ahead (DA) Energy Market for Monday, April 19 incorrectly modeled two transmission outages in the VT/NH area leading to incorrect results affecting NH, VT and West Central MA.

• The DA Market team detected unusual results and delayed the closing to investigate: DA Market and System Operations outage scheduling

personnel did not detect the problem in the allotted timeframe.

• Data Problems were identified the following day: Database included two specific outages modeled to

occursimultaneously due to delay in completing one of them: and,

Incorrect breaker numbers for scheduled outage at a substation.

15

Timeline of Actions to Correct Errors

Advised Market Participants of Problem April 19 & 21

Advised State and Federal Regulators April 20 & 21

Met with NEPOOL Markets Committee April 22

Notice of Intent to Correct the Results April 27 and Rule Changes Proposed

Teleconference Seeking Input to April 29 Proposed Rule Changes

Filed an Explanation of Problem and April 30 Proposed Rule Changes with FERC

Published Corrected Results May 3

16

• Modify internal and external business processes to improve outage scheduler program.

• Add on-site management/senior engineer coverage for the weekend.

• Modify protocols to ensure more timely internal and external communications of potential problems.

Summary of Recommendations

17

Electric and Gas Wholesale Initiative

18

• Timeline– Define problem & key issues -

Complete– Publish Interim ISO-NE Cold Snap Report - May

7– Prioritize issues & brainstorm solution sets

- May– Present range of solutions w/stakeholders - June – Finalize set of recommendations - June– 30 day public comment period - July– Publish final ISO-NE Cold Snap Report -

August– FERC Filings - August– Implement changes - Fall 2004

Electric and Gas Wholesale Initiative

19

Summer Capacity

20

Summer 2004 Capacity Assessment

Conditions for Week of Lowest Operable Capacity MarginWeek beginning June 5th

MW

Projected Peak (50/50) 25,735

Operating Reserve Required 1,700

Total Operable Cap. Required 27,435

Projected Capacity 31,430

Assumed Outages 4,000

Total Capacity 27,430

Operable Capacity Margin - 5

21

Summer 2004 Capacity

AssessmentWe e k Be gin n in g, S atu rd ay

Year M onth Day

Installed Seasonal Claimed

C apability (SCC)

[Note 1]

Interchange (NY PP, NB, HQ, Highgate,

Block Load)

Note

N ew Generat ion

[N ote 2]

De-listed ICAP

Resources [Note 3]

Net Capac ity [Note 4]

Peak Load Exposure [Note 5]

Operat ing Reserve

R equirem ent [Note 6]

Total Known Maintenance

Allowance for

Unpl anned Outages [Note 7]

Total Capac ity

Operable Capac ity

Margin (+ /-)

Extent of OP 4 Act ions That May b e Necessary (OP 4 Ac t ions up to and

inc luding) [Note 8](M W ) (M W ) (M W ) (M W ) (MW ) (M W ) (M W ) (MW ) (M W ) (M W ) (MW )

2004 June 5 30,675 450 300 - 31,430 25,735 1,700 1,200 2,800 27,430 (10) Action 5 12 30,675 450 300 - 31,430 25,735 1,700 700 2,800 27,930 500 19 30,675 450 300 - 31,430 25,735 1,700 500 2,800 28,130 700 26 30,675 450 300 - 31,430 25,735 1,700 500 2,800 28,130 700

2004 July 3 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760 10 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760 17 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760 24 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760 31 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760

2004 August 7 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760 14 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760 21 30,638 450 300 - 31,390 25,735 1,700 100 2,100 29,190 1,760 28 30,638 450 300 - 31,390 25,735 1,700 400 2,100 28,890 1,460

2004 September 4 30,638 450 300 - 31,390 23,666 1,700 400 2,100 28,890 3,520 11 30,638 450 300 - 31,390 22,387 1,700 1,000 2,100 28,290 4,200 18 30,638 450 300 - 31,390 22,047 1,700 1,900 2,100 27,390 3,640 25 30,638 450 300 - 31,390 21,962 1,700 1,300 2,100 27,990 4,330

Notes : Please note that the inform ation contained within the C apacity Analysis is a determ inis tic pro jection of s ystem conditions which could m aterialize during any giv en week of the year.1 . Ins ta lled C apability per May 1, 2004 SC C Repor t. The O perable Capability does not reflect possib le transm iss ion cons train ts w ith in the NEPOOL system .2. New Generation information inc ludes 1) generation recently com mercia l but not yet reflec ted in the NEPOO L SC C Report totals used in the Ins ta lled C apability Column,

and 2) future generation as as sum ed by ISO-NE Planning D epartm ent. Th is value is rounded to the nearest hundred.3. De-lis ted ICAP quantities are on ly known w ith c er ta inty in the c urrent m onth. This num ber is ad justed when a de listed generator is out on maintenanc e to avoid double counting.4. Net Capacity = (SC C) + (In terc hange) + (New Generation) - (D e- listed IC AP R esourc es ). In this equation, the SCC , Interchange and De- listed IC AP values are rounded to

the nearest ten and New Generation is rounded to the nearest hundred.5. Peak Load Expos ure reflec ts va lues published in the April 2004 C ELT R eport. 6. Operating Reserve Requirem ent based on the firs t contingenc y (Generator at 1160 MW ) plus 1/2 the second contingenc y (Generator at 1145 MW ).7. Allow ance for Unplanned O utages inc ludes: forced outages and m aintenance outages s cheduled less than 14 days in advance.8. Relief from cer ta in OP 4 Actions varies , depending on s ystem c onditions.

This analys is is a tabulation of w eekly ass es sm ents s hown in one single tab le. The in form ation s how s the operable capac ity situation under assum ed conditions for each week. It is not expected that the system peak w ill occ ur every w eek during June, July a

ISO-NE Sum m er 2004 OPERABLE CAPACITY ANALYSISM ay 3, 2004 - W IT H KNOWN EXTERNAL CO NTRACT S - 50/50 FORECAST

22

Summer 2004 Capacity Assessment

NEPOO L Operating Capac ity M argins W IT H KN OW N EXT ER N AL T R ANSAC T IO N S - 5 0 /5 0 FO R ECAST

(1 ,000)

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

10,000

11,000

12,000

June - Septem ber 2004, W /B Saturday

Ope

ratin

g C

apa

city

Mar

gin

(MW

)

O P 4 Ac tio n 5

23

Summer 2004 Capacity Assessment

We e k Be gin n in g, S atu rd ay

Year M onth Day

Ins talled Seasonal Claimed

Capability (SCC)

[Note 1]

Interchange (N YPP, NB, HQ, Highgate,

Block Load)

Note

New Generat ion

[N ote 2]

De-lis ted ICAP

Resources [Note 3]

Net Capac ity [Note 4]

Peak Load Exposure [Note 5]

Operat ing Reserve

Requirem ent [Note 6]

Total Know n M aintenance

Allowance for

Unplanned Outages [N ote 7]

Total Capac ity

Operable C apacity

M argin (+/-)

Extent of OP 4 Ac t ions That May b e Necessary (OP

4 Ac tions up to and inc luding) [Note 8]

(M W ) (M W ) (M W ) (M W ) (M W ) (M W ) (MW ) (M W ) (M W ) (M W ) (M W )2004 June 5 30,675 450 300 - 31,430 27,305 1,700 1,200 2,800 27,430 (1,580) Actions 11 - 12

12 30,675 450 300 - 31,430 27,305 1,700 700 2,800 27,930 (1,080) Ac tions 7 - 11 19 30,675 450 300 - 31,430 27,305 1,700 500 2,800 28,130 (880) Ac tions 6 - 11 26 30,675 450 300 - 31,430 27,305 1,700 500 2,800 28,130 (880) Ac tions 6 - 11

2004 July 3 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190 10 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190 17 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190 24 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190 31 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190

2004 August 7 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190 14 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190 21 30,638 450 300 - 31,390 27,305 1,700 100 2,100 29,190 190 28 30,638 450 300 - 31,390 27,305 1,700 400 2,100 28,890 (120) Ac tion 6

2004 September 4 30,638 450 300 - 31,390 25,111 1,700 400 2,100 28,890 2,080 11 30,638 450 300 - 31,390 23,754 1,700 1,000 2,100 28,290 2,840 18 30,638 450 300 - 31,390 23,393 1,700 1,900 2,100 27,390 2,300 25 30,638 450 300 - 31,390 23,303 1,700 1,300 2,100 27,990 2,990

Notes : P lease note that the inform ation contained within the C apacity Analysis is a determ inis tic pro jection o f s ystem conditions which could m aterialize during any giv en week of the year.1 . Ins ta lled C apability per May 1, 2004 SC C Repor t. The O perable Capability does not re flect possib le transm iss ion cons train ts w ith in the NEPOOL system .2. New Generation information inc ludes 1) generation recently com mercia l but not yet reflec ted in the NEPOO L SC C Repor t totals used in the Ins ta lled C apability Column,

and 2) future generation as as sum ed by ISO-NE Planning D epartm ent. Th is value is rounded to the nearest hundred.3. De-lis ted ICAP quantities are on ly known w ith c er ta inty in the c ur rent m onth. This num ber is ad justed when a de listed generator is out on maintenanc e to avoid double counting.4. Net Capacity = (SC C) + (In terc hange) + (New Generation) - (D e- listed IC AP R esourc es ). In this equation, the SCC , Interchange and De- listed IC AP values are rounded to

the nearest ten and New Generation is rounded to the nearest hundred.5. Peak Load Expos ure reflec ts va lues published in the April 2004 C ELT R eport. 6. Operating Reserve Requirem ent based on the firs t contingenc y (Generator at 1160 MW ) plus 1/2 the second contingenc y (Generator at 1145 MW ).7. Allow ance for Unplanned O utages inc ludes: forced outages and m aintenance outages s cheduled less than 14 days in advance.8. Relief from cer ta in OP 4 Actions varies , depending on s ystem c onditions.

This analys is is a tabulation of w eekly ass es sm ents s hown in one single tab le. The in form ation s how s the operable capac ity situation under assum ed conditions for each week. It is not expected that the system peak w ill occ ur every w eek during June, July a

ISO-NE Summ er 2004 OPERABLE CAPACITY ANALYSISM ay 3, 2004 - WITH K NOW N EXTER NAL CONTRACTS - 90/10 FO RECAST

24

Summer 2004 Capacity Assessment

Conditions for Week of Lowest Operable Capacity MarginWeek beginning June 5th

MW

Projected Peak (90/10) 27,305

Operating Reserve Required 1,700

Total Operable Cap. Required 29,005

Projected Capacity 31,430

Assumed Outages 4,000

Total Capacity 27,430

Operable Capacity Margin - 1,575

25

Summer 2004 Capacity Assessment

NEPOO L Operating Capac ity M argins W IT H KN OW N EXT ER N AL T R ANSAC T IO N S - 9 0 /1 0 FO R ECAST

(3 ,000)

(2 ,000)

(1 ,000)

0

1,000

2,000

3,000

4,000

5,000

6,000

7,000

8,000

9,000

10,000

11,000

12,000

June - Septem ber 2004, W /B Saturday

Ope

ratin

g C

apa

city

Mar

gin

(MW

)

OP 4 Act io n s 6-11 OP 4 Act io n 6

OP 4 A ction s 11-12

26

Back-Up Detail

27

CT/SWCT

28

SWCT Transmission

• Phase I– Received conditional approval from

Connecticut Siting Council 2/11/04• Phase II

– Town hearings completed– “Need” hearings completed– “Overhead” segments and “East Shore” –

May– “Underground Technology” segments – June

29

Demand Response

30

Demand Response(as of April 30, 2004)

Active: Pending:Zone Assets Total Assets Total

CT 102 129.2 2 12.5ME 5 78.5NEMA 116 68.9 1 0.3NH 2 0.6RI 11 2.0SEMA 77 8.4VT 15 13.1WCMA 87 24.8

Total 415 325.5 3 12.8

31

Demand Response(as of April 30, 2004)

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

Active: 415 Assets 325.5 MW Pending: 3 Assets 12.8 MWZone Assets RT Price RT 30-Min RT 2-Hour Profiled Assets RT Price RT 30-Min RT 2-Hour Profiled

CT 102 16.9 53.4 1.1 57.8 2 12.1 0.4 0.0 0.0

SWCT* 45 5.4 18.0 1.1 0.2 1 0.0 0.4 0.0 0.0

ME 5 1.5 0.0 1.0 76.0 0 0.0 0.0 0.0 0.0

NEMA 116 62.7 3.3 1.5 1.4 1 0.3 0.0 0.0 0.0

NH 2 0.2 0.4 0.0 0.0 0 0.0 0.0 0.0 0.0

RI 11 2.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0

SEMA 77 7.9 0.5 0.0 0.0 0 0.0 0.0 0.0 0.0

VT 15 7.1 0.1 0.0 5.9 0 0.0 0.0 0.0 0.0

WCMA 87 8.8 4.5 9.6 1.9 0 0.0 0.0 0.0 0.0

Total 415 107.0 62.3 13.3 142.9 3 12.4 0.4 0.0 0.0

32

Northwest Vermont

33

NWVT Reliability Project Update

• State hearing process continues– Technical Hearings complete– Discovery on 115kV line relocations

underway, hearings by mid-June– Rebuttal phase delayed until end of July – Decision expected by mid October

34

New Generation

35

New Generation Update

• No new resources were added in April.

• Approximately 350 MW expected on line by the end of the year.

• Status of Generation Projects as of April 28, 2004:

No. MW

In Construction 4 364with 18.4 approval

Not in Construction 6 1,439with 18.4 Approval

36

RTEP

37

RTEP Update

• TEAC21 held on Thursday, May 6, at the Sheraton Hotel in Springfield, MA

• Discussion Topics– Load Response Program 2004– Load Response Penetration Study– SWCT RFP Results– Resource Adequacy Results– Interregional Planning Update– Economic Assessment

• Review methodology• Results

• TEAC22 tentatively scheduled for June 2• TEAC23 tentatively scheduled for June 25

38

RTEP Projects Update - NEMA

Status as of 5/3/2004

UpgradeExpected In-

serviceOriginal In-

servicePresent Stage

NEMA Boston Stages

1 Planning and Prep148-522XY Jun-01 Jun-01 4 2 Pre-construction (ordering, scheduling, etc.)282-507 Mar-03 Jun-01 4 3 Construction240-510 Nov-01 Nov-01 4 4 CompletedMystic 106 Breaker Jun-01 Jun-01 4

NEMA UpgradesFramingham Auto Jun-02 Jun-02 4Merrimack Auto Jun-04 Jun-02 3240-601 Jun-02 Jun-02 4Walpole Auto Jun-02 Dec-02 4 3800 3400Waltham Auto Nov-02 Jun-03 4282-602 Jul-03 Jun-03 4433-507 Jul-03 Jun-03 4Waltham PAR Jun-03 Dec-03 4274-509 Jun-02 Dec-03 4342-507 Jun-03 Dec-03 4

Notes:Merrimack work continuing.

36004000

NEMA UPGRADE STATUS SHEET

3500

3700

3900

Import (MW)

3100

3300

3500

39

RTEP Projects Update - SWCT

Status as of 5/3/2004

UpgradeExpected In-

serviceOriginal In-

servicePresent Stage

SWCT Import (MW)

Stages

1 Planning and PrepExisting 1700 2 Pre-construction (ordering, scheduling, etc.)Long Mountain Brkrs May-01 May-01 4 3 ConstructionRocky River Caps Jun-02 May-02 4 4 CompletedStony Hill Caps Jun-02 May-02 41880 Upgrade Aug-02 May-02 41890 Upgrade Jun-02 May-02 4BtsRk/StyHl DVARs Jun-03 Jun-03 4 2000Glenbrook StatCom May-04 May-04 31977 Line Tap-Glnbrk May-04 May-04 3

Phase I - 345kV Nov-05 Dec-04 2 2550

Phase II - 345kV Dec-07 Jan-06 1 3400

Notes:Glenbrook STATCOM work continuing. In-service date moved from April to May.1977 Line Tap work continuing.

SWCT UPGRADE STATUS SHEET

1850

2000

40

Compliance

41

Compliance Update

• A4: Maintenance for Bulk Power System Protection– Required response to 2004 ISO-NE survey by

1/5/04– Level 2 sanctions will apply to 3 Participants

for failure to respond on time. – 4 Participants that have not completed their

2003 required maintenance must become compliant by May 31, 2004.

42

Compliance Update (cont.)

• A3: Generator Underfrequency Tripping– All Participants responded to the 2003 ISO-NE

Survey by 12/1/03• 6 Participants are non-compliant

– 2 are exempt– 2 have plans for compliance– 2 will require that ISO-NE enforce

compliance– 2004 Surveys on UFLS and UF generator trip

settings were sent out on March 15 and are due May 10, which includes a 10-day grace period.• Failure to comply will result in sanctions

43

Sanctions

• Level 1 – Letter from Director SP to the relevant functional head (operations, planning) of the Industry Participant with copy to NCWG

• Level 2 – Letter from COO to the Chief Executive of the Industry Participant with copy to the relevant functional head, other NEPOOL Participants (the NEPOOL Task Forces, RC, NPC) and NPCC

• Level 3 – Letter from the CEO to the Board of Directors of the Industry Participant with copies to Level recipients. Post on the ISO-NE Compliance Website.

• Level 4 – same as Level 3 with copies to the appropriate State/Provincial regulatory agencies, FERC, DOE, State Governor and Legislators.