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Title: October 04 April 05 Update Issue Date: March 30, 2005 Project Data Received as of February 9, 2005


1
October 04 - April 05 Update Issue Date
March 30, 2005 Project Data Received as of
February 9, 2005
2
Contents
Page
  • Introduction / Background
  • The Interim Update Process
  • Requested Review Actions
  • April 05 Change Highlights
  • Selected Program Profiles
  • Updated Project Listing

3 5 6 7 24 44
3
Introduction Background
  • It is our objective in 2005 to formalize interim
    planning activity in order to improve the
    communication of progress, provide a process for
    interim approvals (should this be necessary), and
    maintain visibility of system needs.
  • We are pursuing an improvement to the quality of
    update information, enhancing the management of
    change associated with the Plan, and publishing
    updated information more frequently as a service
    to our stakeholders.
  • To facilitate the internal and external review of
    our April 05 Update, we have highlighted changes
    to the Project Listing, provided an analysis of
    changes since the October 04 Update, and
    included progress summaries on high-profile
    projects.

4
Introduction Background (contd)
  • We will update and publish the system plan and
    associated project listing on a periodic basis in
    2005 (shown below). This document represents our
    April 05 Update.

RSP-05 Board Draft
RSP-05 PAC Draft
RSP-05 Approval Period
11/09/05
September Public Mtg 09/09/05
Apr 05
Jul 05
Oct 05
Apr 06
1st Update
2nd Update
3rd Update
1st 06 Update
2005
2006
J
F
M
A
M
J
J
A
S
O
N
D
5
The Interim Update Process
Update Request Guideline to TOs
Introduce Process To TOs
ISO-NE Inte- grates Informa- tion
Analyzes Changes
TOs Update Project Listing
PAC RC Review
01/20/05
01/20/05
ISO-NE Conducts Follow-up
PAC RC Forward any Major Issues to ISO-NE
prior to meeting
Draft Provided to PAC/RC
ISO-NE Prepares Draft Update Report
System Operator Approval
PAC RC Review Draft Update Report
02/28/05
02/18/05
Responses to PAC RC
Present at PAC RC Mtgs
ISO-NE Revises the Update as Necessary
ISO-NE Prepares Responses
Joint TO/ISO-NE Update
Prior to meeting
03/02/05
Submit
April 05
6
Requested Review Actions
TOs Verify project information previously
provided to ISO-NE staff. PAC
RC Review this interim plan. Recognize system
needs, and where applicable, identify market
responses and/or transmission
alternatives. System Operator Gather feedback,
revise as necessary, and publish.
7
April 05 Change Highlights
8
April 05 Change Highlights
  • Summary of changes of Reliability Projects
    between the October 04 Update and this April 05
    Update

Quantity
23 10 11 39 8 689.9 million
New Projects (total projects now in the Plan
276) Cancelled Projects Projects
Advancing to Planned Status (I.3.9-Approved)
Projects Commencing Construction Projects
Placed In Service System Plan Cost Estimate
Change (RTEP04 total estimate 2.3 billion)
 
9
April 05 Change Highlights (contd)
Project count update and reconciliation between
the July 04 Update publication and this April
05 Update (contd)
July 04 to October 04
October 04 to April 05
  • 246
  • 4
  • 7
  • 20
  • 277
  • 4
  • -3
  • -1
  • 269
  • 269
  • 3
  • 0
  • 23
  • 295
  • 8
  • 10
  • -1
  • 276

Reliability projects July 04 Update Reclassifi
cation Projects added as a result of further
study and scope definition of previously
identified projects New projects Projects
placed in service Projects cancelled Local
(non-PTF) project removed Projects as of October
04 Update
Reliability projects October 04
Update Reclassification Projects added as a
result of further study and scope definition of
previously identified projects New
projects Projects placed in
service Projects cancelled Local (non-PTF)
projects removed Projects as of April 05 Update
 
10
April 05 Change Highlights (contd)
PROJECT STATUS CHANGES BETWEEN THE OCTOBER 04
PUBLICATION AND THIS APRIL 05 UPDATE
 
11
April 05 Change Highlights (contd)
RELIABILITY PROJECT STATUS April 05 UPDATE
April 05 Update of All Active Projects in the
Plan
Note (1) 50 projects are in advanced stages of
studies. (Southwest CT Phase II, Boston 115 kV
Enhancements, North Shore, and Monadnock projects)
 
12
April 05 Change Highlights (contd)
COST ESTIMATE COMPARISONS OF RELIABILITY PROJECTS
OCTOBER 04 vs APRIL 05 1
Notes (1) All costs provided by Transmission
Owners. (2) Not included here are the costs of
88 reliability projects for which no estimates
have been provided. Estimates for these projects
are noted as TBD in the Project Listing. Given
the uncertainty of costs associated with these
TBD projects, and the various stages of scope
definition for identified projects, the combined
cost estimate should be considered to be in the
range of 2.2 to 4.0 billion. (3) One project
(Temp. ID 03-61013) will likely contain no PTF
costs. Thus, it has been re-categorized as a
Local Project.
 
13
April 05 Change Highlights (contd)
Make-up of the aggregate cost estimate change of
Reliability Projects between the October 04
publication and this April 05 progress update 1
Change ( millions)
October 04 ( millions)
Cause of Change
Project
Better defined cost estimates Better defined
cost estimates Better defined cost
estimates Better defined cost estimates Better
defined cost estimates New to the
Plan Re-categorized to Local Project Better
defined cost estimates
Southwest Connecticut Reliability
Project Norwalk-Glenbrook Cable Project (3
projects) Central MA Reinforcements (12
projects) NSTAR 345 kV Transmission Reliability
Project (15 projects) North Shore Upgrades (6
projects) New projects (9 projects) Ellsworth
Area Reliability Improvement (1 project) Other
(aggregate) (39 projects)
457.0 120.0 17.8 17.2 8.3 14.4 -8.8 64
.0
890.0 TBD 36.9 217.0 50.2 N/A 8.8 132.
4
change
689.9 Million
1 All costs provided by Transmission Owners.
 
14
April 05 Change Highlights (contd)
AGGEGRATED COST ESTIMATES AND COUNTS BY PROJECT
STAGE 1
For Reliability Projects . . .
Notes (1) All costs provided by Transmission
Owners. (2) Not included here are the costs of
88 reliability projects for which no estimates
have been provided. Estimates for these projects
are noted as TBD in the Project Listing. Given
the uncertainty of costs associated with these
TBD projects, and the various stages of scope
definition for identified projects, the combined
cost estimate should be considered to be in the
range of 2.2 to 4.0 billion. (3) One project
(Temp. ID 03-61013) will likely contain no PTF
costs. Thus, it has been re-categorized as a
Local Project.
 
15
April 05 Change Highlights (contd)
AGGEGRATED COST ESTIMATES BY PROJECT STAGE WITH
APPLIED ACCURACY RANGES 1
For Reliability Projects . . .
Notes (1) All costs provided by Transmission
Owners. (2) Not included here is the cost of 88
reliability projects for which no estimates have
been provided. Estimates for these projects are
noted as TBD in the Project Listing. (3) One
project (Temp. ID 03-61013) will likely contain
no PTF costs. Thus, it has been re-categorized
as a Local Project.
 
16
April 05 Change Highlights (contd)
Twenty-three (23) New Projects and Corresponding
Needs ()
New Transmission Lines
Need
Install 115 kV line from Long Hill to
Reliability need provide South
Milford. capacity to supply load (New
Hampshire) Install 115 kV line from Jackman to
Reliability need provide Petersborough. ca
pacity to supply load (New Hampshire) Install
115 kV line from Petersborough to Reliability
need provide Fitzwilliam. capacity to supply
load (New Hampshire) Build new 115 kV circuit
from Kendall to Reliability need
provide Somerville. capacity to supply load
(Boston)
Transmission System Upgrades
Need
Add 345 kV regulating shunt reactor in Boston
Reliability need provide area. capacity
to supply load (Boston)
() Projects may have some non-PTF components
 
17
April 05 Change Highlights (contd)
Twenty-three (23) New Projects and Corresponding
Needs ()
Transmission System Upgrades
Need
Separate the 115 kV line from Windsor Locks
Reliability need provide to Enfield (1300
line). capacity to supply load (Connecticut)
Add a 345 kV breaker at North
Bloomfield. Reliability need provide (Connecticu
t) capacity to supply load Upgrade bus
work at Somerset Substation. Reliability need
provide (Southeast MA) capacity to supply
load Install Tremont 115 kV bus tie circuit
breaker. Reliability need provide (Southeast
MA) capacity to supply load. Install new 115
kV circuit breaker at Sandwich Reliability need
provide Substation. capacity to supply
load. (Southeast MA)
() Projects may have some non-PTF components
 
18
April 05 Change Highlights (contd)
Twenty-three (23) New Projects and Corresponding
Needs ()
Transmission System Upgrades (contd)
Need
Install new 115 kV circuit breaker at Hatchville
Reliability need provide Substation. capacit
y to supply load. (Southeast MA) Upgrade 115 kV
circuit breakers at W. Farnum Reliability need
provide Substation and add four new 115 kV
circuit capacity to supply load. breakers at
Woonsocket Substation. (Rhode Island)
Reconductor 69 kV Y-25S line from Harriman
Reliability need provide to Deerfield
5. capacity to supply load (Western MA
) Additional 345/115 kV transformation in the
Reliability need provide Berkshire/Pittsfield
area. capacity to supply load (Western MA)
() Projects may have some non-PTF components
 
19
April 05 Change Highlights (contd)
Twenty-three (23) New Projects and Corresponding
Needs ()
Transmission System Upgrades (contd)
Need
Additional 345/115 kV transformation in the
Reliability need provide Springfield
area. capacity to supply load. (Western
MA) Build new Springfield area transmission
circuits Reliability need provide (OH or UG)
in the area. capacity to supply load. (Western
MA) Additional uprating or rebuilding of
the existing Reliability need provide 115 kV
OH lines in the Springfield area. capacity to
supply load (Western MA ) Additional capacitors
in the Springfield area Reliability need
provide substations. capacity to supply
load (Western MA) Install 115 kV capacitors at
Montague Substation. Reliability need
provide (Western MA) capacity to supply load
() Projects may have some non-PTF components
 
20
April 05 Change Highlights (contd)
Twenty-three (23) New Projects and Corresponding
Needs ()
Distribution Substation Work
Need
Expand Chelsea 115 kV Sub. to include four
Reliability need provide circuit breakers and
install 3rd 115/13.8 kV capacity to supply
load distribution transformer. (Boston) Replace
115 kV fuses at Ashfield Substation. Reliability
need provide (Western MA) capacity to
supply load Install third distribution
transformer at Pleasant Reliability need
provide Substation and ring bus. capacity to
supply load (Western MA) Install a 115/13.8 kV
substation at Jacks Hill. Reliability need
provide (Connecticut) capacity to supply load
() Projects may have some non-PTF components
 
21
April 05 Change Highlights (contd)
Eight (8) Projects Placed In-Service and
Corresponding Needs ()
Cost Estimate (in million)
Transmission System Upgrades
Improvement/Need
Re-tension C2 115 kV line from Auburn St. to
TBD Improve thermal limitations.
Dupont. (Southeast MA ) Upgrade A94 115
kV line from Auburn St. to TBD Improve
thermal limitations. Parkview. (Southeast MA
) WMECO 115 kV circuit breaker replacements.
2.2 Overdutied breakers. (Western MA
) Taft Corners Substation 1.9
Increase capacity and (Vermont)
reliability to supply load.
() Projects may have some non-PTF components
 
22
April 05 Change Highlights (contd)
Eight (8) Projects Placed In-Service and
Corresponding Needs ()
Cost Estimate (in million)
Transmission System Upgrades
Improvement/Need
Add a second Rochester to Rochester Tap 4.2
Improve reliability to supply 115 kV
line. load. (New Hampshire) Relocate OH/UG
115 kV 345 kV transmission 1.6
Interstate Highway relocation Facilities in I-95
Highway Quinnipiac Bridge area. project
and needed (Connecticut) maintenance. CLP
115 kV circuit breaker replacements. 5.4
Overdutied breakers. (Connecticut )
Hanover Substation add new distribution
1.1 Increase capacity and transformer and
115 kV improvements. reliability to supply
load. (Connecticut)
() Projects may have some non-PTF components
 
23
Selected Program Profiles
Page
  • Northeast Reliability Interconnection Project
    24
  • Northern New England Transfer Capability
    27
  • Northwest Vermont Reliability Project 30
  • Monadnock Area Reliability 32
  • NSTAR 345 kV Transmission Reliability Project
    34
  • North Shore Upgrades 36
  • Central Massachusetts Reinforcements 38
  • Southern New England Reinforcement Project
    40
  • Southwest Connecticut Reliability Project
    42

24
Northeast Reliability Interconnection Project
PROBLEM STATEMENT / ASSESSMENT The Maritimes
area of Canada is synchronously connected with
the Eastern Interconnect by a radial 345 kV line
originating in Maine at the Maine Yankee
Substation and ending in New Brunswick Canada at
the Keswick Substation. This line has two load
taps on it, one at Orrington Substation in the
Bangor Hydro Electric (BHE) service territory
and the other at Maxcys Substation outside of
Augusta in Central Maine Power (CMP) service
territory. This 1970-vintage wood pole line has
a total distance of around 231 miles with 150
miles being the length from Orrington to Keswick.
Due to this electrically weak corridor, the
transmission system is subject to a number of
anomalies including separation of the two control
areas. The corridor requires a number of Special
Protection Systems (SPS) to allow the two control
areas to operate in a reliable and secure manner.
To help support the area there is also a Static
Var Compensator (SVC) located in Chester Maine
as a tap on the line. This SVC is necessary to
allow the system to survive swings related to
significant source loss in southern New England.
The Keswick to Orrington section of the line is
limited in its ability to transfer energy by the
system stability response. This firm transfer
limit is presently 700 MW. The existing system
is not capable of providing firm transfer
capability from New England to New Brunswick.
The line sections south of the Orrington
substation have parallel 115 kV paths that tend
to serve local load but do allow for additional
transfers. (contd)
25
Northeast Reliability Interconnection
Project(contd)
  • PROBLEM STATEMENT / ASSESSMENT (contd)
  • The combined ability of the system (parallel 345
    and 115 kV lines) to transfer energy south of
    Orrington is limited to approximately 1,050 MW.
    This also creates an operating concern that if
    the MEPCO 345 kV facility trips, the underlying
    lines will be immediately overloaded
    necessitating action to prevent their damage.
    The primary specific goals are to address Keswick
    GCX SPS inadvertent operation and inter-Area
    impact violation, islanding of the Maritimes for
    the loss of the Keswick to Orrington line,
    economic benefits of increased New Brunswick to
    New England and Orrington South transfer
    capabilities, and reduction of system losses. In
    addition to these there are other lesser issues
    that are addressed as well.
  • PROJECT DESCRIPTION ()
  • The Northeast Reliability Interconnect Project
    primarily consists of an approximately 144 mile,
    345 kV transmission line from the Point LePreau
    Substation to the Orrington Substation, two
    additional 345 kV circuit breakers at the
    Orrington Substation, a 25 ohm series capacitor
    in the Orrington to Maxcys to Maine Yankee 345 kV
    line, 60 MVAr of shunt capacitors in western
    Maine. This project allows for the disarming of
    the Keswick GCX SPS for all lines in conditions,
    prevents the islanding of the Maritimes for the
    loss of the Keswick to Orrington line, increases
    the New Brunswick to New England and Orrington
    South transfer capabilities to 1,000 MW and 1,200
    MW respectively. (contd)

() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifier 02-52002.
26
Northeast Reliability Interconnection
Project(contd)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Presently in technical sessions.
  • Seeking Certificate of Public Convenience and
    Necessity (CPCN) following hearings with the
    Maine PUC. Approval expected in 2nd Qtr. of
    2005.
  • Other permits sought after
  • MDEP anticipating acquisition of permit in 3rd
    Qtr. of 2005.
  • DOE/Presidential Permit - anticipating
    acquisition of permit in 3rd Qtr. of 2005.
  • Engineering and procurement will begin in late
    4th Qtr. contingent upon successful acquisition
    of permits.
  • ISSUE
  • Some NEPOOL Participant concerns regarding OATT
    treatment of project related upgrades on MEPCO
    facilities.

27
Northern New England Transfer Capability
  • PROBLEM STATEMENT / ASSESSMENT
  • The Maine-New Hampshire Interface can be
    restricted by voltage, thermal or stability
    limits. Usually the voltage limit for the
    interface is most constraining, followed by the
    thermal limit, and lastly the stability limit.
    The Maine-New Hampshire Interface transfer
    capability is very dependent on local generation
    dispatch. The criteria loss of both a
    transmission facility and a critical generating
    unit can result in an adverse reliability impact.
    The objectives of this study were to examine
    short term system enhancements that
  • Reduce must-run generation requirements under
    normal operating conditions including units
    required for voltage regulation.
  • Evaluate the improvements in reliability
    performance of the Northern New England power
    system resulting from these upgrades and
    modifications.
  • PROJECT DESCRIPTION ()
  • The study assessed the thermal, voltage and
    stability limits for the Northern New England
    bulk power system to benchmark the existing
    system reliability performance and evaluated the
    impact of three transmission system upgrade
    alternatives. (contd)

() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers 02-62003a and
02-62003b.
28
Northern New England Transfer Capability(contd)
  • PROJECT DESCRIPTION (contd)
  • The three alternatives were
  • Alternative 1 - Add a dynamic voltage control
    system at Deerfield with a 500-600 MVAR
    capability.
  • Alternative 2 - Interconnect Section 391
    (Buxton-Scobie) at Deerfield and add three
    breakers at Buxton for the re-termination of
    Section 386 (Buxton-South Gorham).
  • Alternative 3 - Add a dynamic voltage control
    system at Deerfield with a 500-600 MVAR
    capability, interconnect Section 391 at Deerfield
    and add three breakers at Buxton for the
    re-termination of Section 386.
  • The Maine-New Hampshire Interface limits are
    shown in the table below for the existing system
    and the three alternatives

29
Northern New England Transfer Capability(contd)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Study work continuing.
  • ISSUES
  • Sensitivity analysis to other proposed projects
    in the region.
  • Identify the aggregate impact of projects.

30
Northwest Vermont Reliability Project
PROBLEM STATEMENT / ASSESSMENT Two 115 kV
lines, a 115 kV interconnection with New York,
and a back-to-back HVdc interconnection with
TransEnergie, supply the northwestern portion of
Vermont, which includes the city of Burlington.
There are no major generating stations in the
area and no extra high voltage transmission
lines. The 115 kV transmission facilities
connecting this area are long, old and have low
capacity, resulting in a number of voltage and
thermal loading concerns. The interconnection
with New York has been unreliable due mostly to
phase angle regulator (PAR) issues. Possible
problems with the back-to-back converter station
at Highgate could lead to an extended outage of
the interconnection with Hydro-Quebec. Load
levels have been identified where a long term
outage of a critical facility would create a
major reliability problem. PROJECT DESCRIPTION
() The solution includes a number of system
reinforcements, centered on a new 345 kV line
from West Rutland to New Haven (35.5 mi.) and a
new 115 kV line from New Haven to Queen City
(28.4 mi.). Additional autotransformers, phase
angle regulating transformers, and dynamic and
static VAR compensatory devices are also part of
the plan.
() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers 02-64006b through
02-64006i.
31
Northwest Vermont Reliability Project (contd)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Vermont Public Service Board approved modified
    version of project on January 28, 2005.
  • Certificate of Public Good has been acquired
    pursuant to VT PSB decision.
  • VELCO reviewing order to determine required
    I.3.9/TCA changes.
  • ISSUE
  • None
  • CONDITIONS
  • Required use of low reflective wire.
  • Re-location of many poles.
  • Reducing height of many poles.
  • Increase vegetative screening.
  • Use of low-noise equipment in some substations.
  • Placement of approximately 1.4 mi. of 115 kV
    transmission underground in area close to shore
    of Lake Champlain.

32
Monadnock Area Reliability
PROBLEM STATEMENT / ASSESSMENT The Monadnock
Region encompasses a three-state area of
southeastern Vermont, southwestern New Hampshire,
and north central Massachusetts. In addition to
supplying this localized load, the transmission
facilities in this region are critical for
supplying a much wider area, including most of
Vermont and northern New Hampshire. The area is
served by long, low capacity 115 kV facilities
supplied by the Pratts Junction, Greggs, Webster,
Hartford, Vermont Yankee and Coolidge
Substations. The Flagg Pond to Pratts Junction
115 kV lines supplying this area are constructed
on a double-circuit-tower. Testing has been
performed at the 27,800 MW NEPOOL load level.
The study consists of both thermal and voltage
analyses. Specific goals are to improve
post-contingency voltage performance for the loss
of the double-circuit-tower lines between Flagg
Pond and Pratts Junction eliminate under-voltage
automatic load shedding schemes at Vermont
Yankee, Ashburnham and Flagg Pond and improve
thermal/voltage performance for loss of the
Vermont Yankee T-4 autotransformer, the Vermont
Yankee to Chestnut Hill 115 kV K-186 line, and
the Coolidge to Vermont Yankee 345 kV 340 line.
Contingency loss of the Coolidge to West Rutland
345 kV 350 line, or the Vermont Yankee to Amherst
345 kV 379 line, is also a problem at future,
near-term load levels. PROJECT DESCRIPTION ()
The study assessed the thermal and voltage
impact of a base line system that included some
related 115 kV upgrades and five different
Upgrade Plans. (contd)
() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers 02-65001a through
02-65001i and 02-65001n.
33
Monadnock Area Reliability(contd)
  • PROJECT DESCRIPTION (contd)
  • Of the five upgrade options analyzed, Upgrade
    Plan 1, which primarily consists of, but is not
    limited to, building a new 345/115 kV Substation
    at Fitzwilliam, NH, and re-conductoring the I-135
    115 kV line from Bellows Falls to Flagg Pond (52
    miles), appears to provide the best overall
    (performance, cost and constructability) solution
    to the Monadnock Region problems. (Bellows Falls
    to Ascutney Tap 115 kV 15 mi re-conductor
    Garvins to Webster 115 kV 23.4 mi re-conductor
    Jackman to Greggs 115 kV 20.4 mi re-conductor
    Keene to Swansey 115 kV 4.6 mi)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Steady-state and sensitivity analyses have been
    completed and will be reviewed by TTF in February
    2005.
  • Stability analysis on hold until March 2005.
  • Goal is to receive I.3.9 approval in the second
    quarter of 2005.
  • ISSUES
  • None

34
NSTAR 345 kV Transmission Reliability Project
  • PROBLEM STATEMENT / ASSESSMENT
  • The limited number of supply resources, proposed
    generation retirements, changing load and
    generation patterns, and continued load growth
    combine to create reliability problems for the
    system, including the Boston Import Area. The
    assessments included examinations of resource
    adequacy and operating reserve adequacy for the
    Boston Import Area as well as a detailed network
    analyses to examine potential line loadings and
    voltage performance for the Downtown Boston 115kV
    sub-area. These studies show the need for
    resources in the Boston area.
  • PROJECT DESCRIPTION ()
  • Short-Term (present 2006) Retain the New
    Boston Unit 1 and the Salem Harbor plant to
    ensure the operating Reserve Adequacy of the
    Boston Import and ensure meeting first
    contingency coverage in the Downtown Boston 115kV
    sub-area.  
  • Intermediate Term (2006) This project
    maintains the Boston Import Areas reliability by
    increasing the Areas import capability and
    eliminates the dependency on all generation
    requesting retirement by making the following
    upgrades
  • Build a new 345kV substation (Stoughton) along
    the 316 Line corridor between West Walpole and
    Holbrook.
  • Install one pipe-type 345kV cable from Stoughton
    to Hyde Park (11.2 mi.).
  • Install a 345/115kV autotransformer at Hyde Park.
  • Install heat exchangers on the cables between
    Hyde Park and Baker St.  
  • Install two pipe-type 345kV cables between
    Stoughton and K St (2x15.4 mi.).
  • Install two 345/115kV autotransformers at K St.
  • Install 4-160MVAr shunt reactors at Stoughton and
    2-160MVAr reactors at K St.

() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers 02-71034a through
02-71034o.
35
NSTAR 345 kV Transmission Reliability
Project(contd)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • EMTP Study has been completed, which was
    recommended by RC on December 13, 2004.
  • EMTP Study concluded that a Type III SPS was
    needed to mitigate transient over voltages for
    line out conditions.
  • MA EFSB approval on January 14, 2005.
  • ISO-NE I.3.9 approval on February 10, 2005.
  • ISSUES
  • Initial analysis resulted in 2010 operating
    reserves need, but the retirement of generation
    advances the need for the proposed transmission
    facilities. Transmission need timing is between
    2003 and 2010 depending on the amount of
    generation that retires. The Boston Import Area
    becomes deficient beyond 2007 (if Kendall does
    not re-activate) given the combination of
    proposed generation retirements and transmission
    upgrades.
  • Detailed Transmission Analysis has revealed
    thermal and voltage reliability criteria
    violations for the Downtown Boston Transmission
    System in 2006. Delaying the project
    implementation would result in dependence on
    Quick Start Generation to meet N-1 reliability
    criteria.
  • Any delays in the project completion would
    require longer retention of New Boston 1 and the
    Salem Harbor plant.
  • Integrating the project while concurrently
    maintaining the ability to operate large amounts
    of generation at the New Boston site is a
    significant technical challenge and will require
    115 kV transmission upgrades within the Boston
    area.

36
North Shore Upgrades Projects
  • PROBLEM STATEMENT / ASSESSMENT
  • The impact of the proposed retirement of the
    Salem Harbor units was evaluated for the existing
    transmission system for operating reserve
    adequacy, the potential for un-served energy, and
    a detailed network analysis to examine potential
    line loadings and voltage performance. The
    assessments showed dependency on the Salem Harbor
    units particularly the North Shore area.
  • PROJECT DESCRIPTION ()
  • Short-Term (present 2006) Retain the Salem
    Harbor plant to ensure the operating Reserve
    Adequacy and to ensure meeting first contingency
    coverage in the North Shore sub-area.
  • Intermediate Term (2006) This project maintains
    the systems reliability by increasing the North
    Shore areas import capability, and eliminating
    the dependency on Salem Harbor generation, by
    making the following upgrades
  • Re-conductor the 115 kV overhead lines B-154N and
    C-155N from Ward Hill to the King Street tap (5.6
    mi.).
  • G-133 circuit upgrade (8.2 mi.).
  • Expand 345 kV at Ward Hill to a breaker and one
    half bus and split the 394 Line (Seabrook to
    Tewksbury) into two sections from Seabrook to
    Ward Hill (394N) and Ward Hill to Tewksbury
    (394S).
  • Install three additional 345-115 kV transformers
    (T4, T5, and T6) at Ward Hill.
  • Install two 115 kV 63 MVAR capacitors at Salem
    Harbor station.

() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers 02-71028a through
02-71028f.
37
North Shore Upgrades Projects (contd)
  • PROJECT DESCRIPTION (contd)
  • Long Term (Beyond 2006)
  • The North Shore import capability will need to be
    strengthened beyond 2006. At the 2006 load level
    and with maximum generation in the Downtown
    Boston sub-area, the Golden Hills transformers
    become overloaded. The long-term solution of
    creating a parallel path to the Golden Hills
    transformer requires the following upgrades
  • Creation of a new 345-115kV substation at
    Wakefield Junction, connecting the 345 kV 339
    line and the 115 kV S-145 and T-146 lines.
  • Modification and expansion of the 345 kV Golden
    Hills substation.
  • or
  • A preferred alternative may be to retire the
    aging Golden Hills 345 kV gas-insulated
    substation and combine functionality into the new
    Wakefield Junction station.
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Massachusetts regulatory authorities continue to
    review applications for exemptions from local
    zoning requirements..
  • ISSUES

38
Central Massachusetts Reinforcements
  • PROBLEM STATEMENT / ASSESSMENT
  • The existing transmission system in Central
    Massachusetts has several reliability problems.
    When tested for the 2003 summer peak load case
    with a NEPOOL load of 25200 MW, the existing
    transmission system in Central MA showed many
    thermal and voltage criteria violations.
    Specifically, the two 115-69 kV transformers at
    Millbury substation, the two 115-69 kV
    transformers at Ayer substation and the two
    345-115 kV transformers at Sandy Pond substation
    show thermal overloads. The 230 kV substation at
    Pratts Jct, the 115 kV substations at Flagg Pd,
    Barre, Paxton, Webster St and some other 69 kV
    substations show voltage violations.
  • PROJECT DESCRIPTION ()
  • The following upgrades are proposed to address
    the identified problems
  • Develop 345,115 kV GIS substation at Wachusett.
  • Install two new 345-115 kV (448 MVA) transformers
    at Wachusett.
  • Reconductor 115 kV lines (O141, O141N, W175, V174
    total 32.1 mi.)
  • Replace two 115-69 kV autotransformers at
    Millbury with 56 MVA autotransformers by 2004.
  • Transfer half of Prospect St load form V-22E to
    U-21S and add two 115-69 kV autotransformers at
    Pratts Jct.
  • Install second 115-69 kV autotransformer at
    Wachusett.
  • Other 69 kV work (11 mi.).

() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers 02-71026,
02-71027a through 02-71027k.
39
Central Massachusetts Reinforcements(contd)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Received TCA recommended approval from the RC on
    January 18, 2005.
  • The construction schedule remains unchanged.
  • ISSUE
  • None

40
Southern New England Reinforcement Project
PROBLEM STATEMENT / ASSESSMENT Connecticut is
at risk of operating deficiencies at its planned
2004 summer peak, from a load adequacy
standpoint. There is also difficulty
transferring supply from the Massachusetts
generation bordering Rhode-Island to the rest of
Western Massachusetts, Rhode-Island and
Connecticut. Finally, there is an
interrelationship of the transmission interface
limits between East/West, SEMA, SEMA/RI,
NEMA/Boston and CT. The most practical upgrade to
alleviate these issues would be the construction
of a 345-kV transmission line, which would tie
all three states Massachusetts, Rhode Island and
Connecticut. PROJECT DESCRIPTION () A number
of alternative configurations are still being
explored in order to most effectively address the
combined reliability needs of Rhode Island,
Massachusetts, and Connecticut. The currently
preferred solution is the construction of a
345-kV AC overhead line, which would ultimately
tie the four 345-kV substations of Millbury,
Sherman Road, Lake Road and Card St. Depending
on the findings from the transmission planning
analysis, in terms of cost and transmission
reliability, this enhancement would be composed
of at least three different line segments. One
segment would tie Card St. to Lake Road (about 29
mi.). A second segment would tie Lake Road to
Sherman (about 16 mi.). A third segment would
tie Sherman to Millbury (as long as 31 mi.,
depending on route taken). Besides addressing
resource adequacy in Southern New England, the
entire project would improve the areas
reliability from a transient/voltage performance
perspective and from a transient stability
perspective. It would also provide for better
East to West transfers of power within New
England .
() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers 02-73001a,
02-73001b, and 02-74036.
41
Southern New England Reinforcement Project
(contd)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Extensive planning analysis has been performed
    during which additional study metrics and
    possible transmission upgrades have been
    identified and investigated.
  • An integrated and cross-functional team with
    representatives from National Grid and Northeast
    Utilities has been created.
  • Ranking of alternatives in terms of benefits to
    the transmission system is expected in the
  • 2nd Qtr. of 2005.
  • ISSUES
  • Additional planning analysis needed for gathering
    comprehensive set of data for final evaluation of
    alternatives.

42
Southwestern Connecticut Reliability Project
PROBLEM STATEMENT / ASSESSMENT The
transmission system in southwest Connecticut,
when tested at both the 25,800 and 27,700 MW New
England load levels, proved to be inadequate.
The results showed widespread thermal and voltage
criteria violations for the existing SWCT system.
This situation is compounded by the lack of
infrastructure necessary to interconnect new
generation and an uncertainty of existing local
generation remaining available in light of
environmental and economic factors. PROJECT
DESCRIPTION () The recommended solution is a
two-phase approach. Phase I consists of a new
Plumtree to Norwalk 345kV line, half overhead and
half underground, coupled with other related 115
kV projects. Phase II ties this new Norwalk
345kV Substation via underground cable to the new
Singer (Pequonnock) Substation and on to the new
East Devon (Devon) Substation. A new overhead
345kV line connects East Devon through to a new
Beseck Substation that will be constructed at the
intersection of existing 345kV lines in
Middletown. Other related 115 kV projects are
also included.  
() Related projects can be referenced on the
attached ISO-New England Project Listing with the
following project identifiers For Phase 1
02-74015a - 02-74015e and 02-74015g - 02-74015j.
For Phase 2 02-74017a through 02-74017ab.
43
Southwestern Connecticut Reliability Project
(contd)
  • PROGRESS SINCE OCTOBER 04 UPDATE
  • Phase I Plumtree Norwalk 345 kV (OH 8.6 mi.,
    UG 11.8 mi.)
  • Detailed engineering/procurement in progress.
  • TCA application filed January 12, 2005.
  • Consultant doing final review of
    transient/harmonic analyses.
  • Phase II Beseck - East Devon (33.4 mi.) Oxbow
    Junction - Beseck Junction (7 mi.) East Devon -
    Singer (7.8 mi.) Singer - Norwalk (15.5 mi.)
    Norwalk - Glenbrook 115 kV (2x8.1 mi.) Glenbrook
    - Norwalk Harbor 115 kV (9.2 mi.) Scovill Rock -
    Chestnut Junction (2.6 mi.) Black Pond - Beseck
    Junction (2x2.8 mi.).
  • Siting review in progress with ruling due in
    April 2005.
  • Final ROC Report complete recommended proceeding
    with 24 miles of XLPE UG cable - considered to be
    the maximum technologically feasible, provided
    certain system improvements are made.
  • January 11th and 13th hearings on ROC Report
    completed.
  • Technical meeting before the Connecticut Siting
    Council (CSC) held February 14th.
  • CSC consultant (KEMA) supported 24 miles as the
    maximum underground.

44
Updated Project Listing (as of 02/09/05)
  • Column Definitions
  • Project Listing
  • Reliability Projects
  • Interconnection Projects
  • Economic Projects
  • Elective Projects
  • Projects In-Service
  • Cancelled Projects
  • Local Projects

45
April 05 Project Listing Column Definitions
  • Part Number (Part ) The Part s designate the
    need category of the project. Original
    categories are not changed when a project is
    placed In-Service or Cancelled.
  • Part 1 These projects are reliability upgrades.
  • 1a Planned or Under Construction
  • 1b Conceptual or Proposed
  • Part 2 These projects are generator
    interconnection upgrades.
  • 2a Proposed (I.3.9 approval but without
    Generator Interconnection Agreement), Planned
    (I.3.9 approval with Generator Interconnection
    Agreement), or Under Construction
  • 2b Conceptual or Proposed
  • Part 3 These projects are economic upgrades.
  • 3a Planned or Under Construction
  • 3b Conceptual or Proposed
  • Part 4 These projects may be promoted by any
    entity electing to support the cost of
    transmission changes. The entity sponsoring
    the changes will have their own justification for
    their actions.
  • 4a Planned or Under Construction
  • 4b Conceptual or Proposed
  • Part 5 These projects are reliability upgrades
    with minimal or no associated PTF costs.
  • 5a Planned or Under Construction
  • 5b Conceptual or Proposed
  • Temporary ID
  • The first 2 digits indicate whether the project
    is an RTEP02, an RTEP03, or an RTEP04 project.

46
April 05 Project Listing Column Definitions
(contd)
Equipment Owner The company listed here is the
responsible equipment owner / provider designated
to design and implement the project. Projected
Month/Year of In-Service The month/year entered
is the date the project is expected to be placed
in service. Major Project Name given to a
project that consists of smaller
subprojects. Project Description A brief,
high-level description of the project is entered
here. It will either include major pieces of
substation equipment and/or types of line work to
be performed. Status (October 04 or April
05) In Service The project has been placed in
operation. Under Construction The project has
received necessary approvals and a significant
level of engineering or construction is underway.
Siting The project requires ISO-NE involvement
in the siting process. This entry is in addition
to the actual status of the project. Planned
The project has received I.3.9 approval (if
required), but may or may not have received TCA
approval. The TCA approval may be applied for at
a later date at the project owners risk.
(Generator Interconnection projects are
considered planned when they have
interconnection agreements filed with and
accepted by FERC.) Proposed A significant
degree of analysis is available to show potential
need for the project, but I.3.9 approval has not
been received yet. ISO New England has been
provided with a copy of the analysis associated
with the project.
47
April 05 Project Listing Column Definitions
(contd)
Concept There is little or no analysis
available to support a specific project, but
there is sufficient information to suggest a
pending need for future study work and a remedial
project. Cancelled Project has been
cancelled. I.3.9 Approval A date in this column
signifies when the project received approval
pursuant to Section I.3.9 of the NEPOOL
agreement. This approval indicates that the
project will have no adverse impact on the
stability, reliability, or operating
characteristics of the system. A no indicates
that an approval is required, but has not been
received yet. An NR indicates that an I.3.9
approval is not required. An N/A indicates
that an I.3.9 approval is not applicable because
the project has been cancelled. ROW Required A
yes in this column indicates that either new
Right of Way (ROW) has to be obtained, or
existing ROW widened. It might also indicate
that substation property has to be obtained. A
no indicates that no additional ROW or property
is required. An N/A indicates that ROW needs
are moot because the project has been
cancelled. TCA (15.5 / 12C) Approval A date in
this column signifies when the project PTF costs
were reviewed and approved. This approval
indicates that it has been agreed whether, and by
how much, the scope of the project and associated
costs exceed regional needs. An N/A indicates
that a TCA approval is not applicable either
because the project has been cancelled or because
PTF costs are not involved.
48
April 05 Project Listing Column Definitions
(contd)
TCA Category (Transmission Cost Allocation
Category) This entry represents the most likely
category for cost allocation, prior to TCA
approval, and the actual category, post TCA
approval. GI Generator Interconnection
Related Upgrade EL Elective Transmission
Upgrade NM NEMA Upgrade 02 RTEP02
Upgrade RBU Regional Benefit
Upgrade LBU Local Benefit
Upgrade Estimated Costs The pool-supported
project cost estimate presented here should be
the best estimate available. It is understood
that the estimate accuracy may vary dependent on
the maturity of the project. Accuracy tolerances
for these estimates are targeted as follows
Concept Project (-50, 200), Proposed
Project that has been reviewed and approved by
ISO-NE (-25, 50), I.3.9-Approved Project
(/-25), and TCA-Approved Project (/-10)
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