HomeMy WebLinkAbout2019-07-08 BOS Packet - Released SELECTMEN'S MEETING
Monday, July 8, 2019
Town Office Building, 1625 Massachusetts Avenue, Selectmen's Meeting Room
7:00 PM
AGENDA
PUBLIC COMMENTS
Public comments are allowed for up to 10 minutes at the beginning of each meeting. Each speaker is
limited to 3 minutes for comment. Members of the Board will neither comment nor respond, other than
to ask questions of clarification. Speakers are encouraged to notify the Selectmen's Office at 781-698-
4580 if they wish to speak during public comment to assist the Chairman in managing meeting times.
SELECTMAN CONCERNS AND LIAISON REPORTS
TOWN MANAGER REPORT
1. Introduction of Katharine Labrecque, Management Fellow
ITEMS FOR INDIVIDUAL CONSIDERATION
1. Public Hearing- Flammable Fuel Storage- 45-55 Hayden Avenue 7:05 p.m.
2. Update on Proposed New Police Station Design 7:10 p.m.
3. Grant of Location for National Grid - Massachusetts Avenue to Hastings 7:40 p.m.
Elementary School
4. Grant of Location for National Grid -Augustus Road 7:45 p.m.
5. Approve Acceptance of Donations Made to Recreation Department 7:50 p.m.
6. F Y 19 Year-End Budget Adjustments 7:55 p.m.
7. Craft'd Company- Middlesex County Beer Festival 8:05 p.m.
• One-Day Liquor License
• Entertainment Licenses
8. Approve Memorandum of Understanding- Lexington Municipal Management 8:20 p.m.
Association(LMMA)
9. Approve Acceptance of Gift- US S Lexington 8:25 p.m.
10.Town Office Building Hours of Operation Six-Month Review 8:30 p.m.
11. Town Manager Reappointments 8:40 p.m.
12.Reconsideration- Masslex, LLC Liquor License Transfer at 1666 Massachusetts 8:45 p.m.
Avenue
13.Entertainment License Renewal- Bertuc ci's Restaurant Corporation, 1777 8:50 p.m.
Massachusetts Avenue
14.Limousine License Application- D&O Limo LLC 8:55 p.m.
15. Selectmen Committee Appointments & Resignation 9:00 P.M.
16.Discuss Potential Special Fall Town Meeting and Goal Setting Dates 9:10 P.M.
17.Update Regarding Planning Department 9:20 p.m.
CONSENT AGENDA
1. Water and Sewer Commitments
2. Water and Sewer Adjustment
3. Approve One-Day Liquor License
ADJOURN
1. Anticipated Adjournment 9:30 p.m.
The next regularly scheduled meeting of the Board of Selectmen will be held on Monday, July 22,
2019 at 7:00 p.m. in the Selectmen's Meeting Room, Town Office Building, 1625 Massachusetts
Avenue.
Hearing Assistance Devices Available on Request
All agenda time and the order of items are approximate and LezVfeilads
subject to change. Recorded by LexMedia
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Introduction of Katharine Labrecque, Management Fellow
ITEM
PRESENTER: NUMBER:
T.1
SUMMARY:
Introduction of Katharine LaBrecque, the new Management Fellow in the Town Manager's Office.
SUGGESTED MOTION:
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Public Hearing- Flammable Fuel Storage - 45-55 Hayden Avenue
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
I.1
SUMMARY:
Brian Gris aru, King Street P roperties,will be at the meeting to answer any questions regarding the request for a
Flammable Fuel Storage License at 45-55 Hayden Ave, P arc el 17-21 A. The application was reviewed by Fire,
Building, Health and Conservation department staff who had no objections to the ap p lic aito n. A representative
from the Lexington Fire Department will be in attendance at the meeting to answer any questions regarding the
attached application.
SUGGESTED MOTION:
Motion to approve a Flammable Fuel Storage License for HCP/King Hayden Campus, LLC for the storage,
operation and maintenance of flammable and combustible storage at 45-55 Hayden Avenue, Map 17 Parcel
21A as presented.
FOLLOW-UP:
Selectmen's O ffic e
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 7:05 p.m.
ATTACHMENTS:
Description Type
D Flarrri'll el F`u, l l,.)pfi fafion.,,,,, al.)17,Rircc1.21 A 45 5` 1 layd en.Ave 1.3ac u.p lzat tial
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GIB► Coordinates
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License
LONG.
Massachusetts General Maw, Chapter 148 §13
FP-2 License Number
(Rev.05-2009) WNew License Ll Amended License
After notice and hearing,and in accordance with Chapter 148 of the Mass. General Laws,
a license is hereby granted to use the land herein described for the purposes described.
Location of Land: `S HAVOENI, Ave , Assessom's
Number,Street and Assessors Map and Parcel ID
Owner of Land:
�.;� � �Address of t,and Owner: t I �1r! �,� 8010 �
Av
Flammable and Combustible Liquids, Flammable Gases and Solids
Complete this section.for the storage of flammable and combustible liquids,solids, and gases. All tanks and containers are
convidered full for the purposes of'licensing and permitting. (Attach additional pages if necessary.)
PRODUCT NAME CLASS MAXIMUM UNITS CONTAINER.
QUANTITY gal.,lbs, UST,AST,IBC,
cubic feet drums
r
s �► �► l�t u� ,y r r► Zoo GAL.
.
LP- . s (Complete this section.for the.storage of*LP-gas or propane)
•`' Maximum quantity(in gallons)of LP-gas to be stored in aboveground containers:
List sizes and capacities of all aboveground containers used for storage
v* Maximum quantity(in gallons)of LP-,gas to be stored in underground containers:
List sizes and capacities of all underground containers used for storage
Total aggregate quantity of al l LP-gas to be stored: M R
•
reworks (Complete this section for the.storage of.fireworks)
Maximum amount(in pounds)of Class 1.3G:
*:• Maximum amount(in pounds)of Class 1.4G:
•'� Maximum amount(in pounds)of Class 1.4:
Total aggregate quantity of all classes of fireworks to be stored: ('
THIS LICENSE OR A CERTIFIED COPY THEREOF MUST BE CONSPICIOUSLY
POSTED ON THE LANs)FOR WHICH IT IS GRANTED.
Explosives (complete this section for the storage of explosives)
Maximum amount(in pounds)of Class 1.1: _N Number of magazines used for storage:
❖ Maximum amount(in pounds)of Class 1.2: Number of magazines used for storage:
• Maximum amount in pounds)of Class 1.3: Number of magazines used for storage:
• Maximum amount in pounds)of Class 1.4: Number of magazines used for storage:
❖ Maximum amount in pounds)of Class 1.5: Number of magazines used for storage:
• Maximum amount in pounds)of Class 1.6: ovi Number of magazines used for storage:
Licensint! Authority Use:
This license is granted upon the condition that the licensed activity will comply with all applicable laws,
codes, rules and regulations, including but not limited to Massachusetts General Law, Chapter 148, and the
Massachusetts Fire Code (527 CMR) as amended. The license holder may not store materials in an amount
exceeding the capacities herein specified unless and until any amended license has been granted.
ADDITIONAL RESTRICTIONS:
Signature of Licensing Authority Title Date
THIS LICENSE OR A CERTIFIED COPY THEREOF MUST BE CONSPICIOUSLY
POSTED ON THE LAND FOR WHICH IT IS GRANTED.
FP-2(Rev.05/2009) Page 2
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AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Update on Proposed New Police Station Design
PRESENTER:
ITEM
NUMBER:
Mark Barrett, Project Manager
I.2
SUMMARY:
Attached please find the current Police Station design which includes options with/without moving the IT
Department from the Town Office Building to the new Police Station. Due to the crowded situation in the
Town Office Building, it has been requested that the Dept. of Public Facilities include this as an option for
consideration as it's likely the least expensive avenue to create additional space in the Town Office Building
without a major renovation of this building.
However, in considering this option and potential alternative designs has taken some time. If you review the
attached schedule you'll see that 50% design cost estimates are in the Spring 2020 timeframe. Based upon this
timeframe, it would be difficult to place a question before voters for the debt exclusion and Town Meeting for
the debt authorization this Fall. This is more likely a Spring 2020 Annual Town Meeting question.
Finally, attached is a single sheet on the H o s mer House for discussion since the long-term re-use or relo c atio n
of the Hosmer House relates to the Police Station and the final design of the Police Station. The discussion
on this matter should be focused on whether the Board believes the Hosmer House should be part of the
design of the Police Station or relocated.
SUGGESTED MOTION:
No action required at this time, although consensus on the relocation of IT and the Hosmer House will assist in
providing clarity to the architect on finalizing designs.
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 7:10 p.m.
ATTACHMENTS:
Description Type
D Polk:.e Station.Presentation. (bveir Ullerno
D Police Station.Sch.edUlle (bver Ullerno
D .1.lo s rner 1.lo us e (Awer Mllenio
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AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Grant of Location for National Grid - Massachusetts Avenue to Hastings Elementary School
PRESENTER:
ITEM
NUMBER:
Mark Barrett, Project Manager
I.3
SUMMARY:
The National Grid hereby respectfully requests your consent to the locations of mains as hereinafter described
for the transmission and distribution of gas by installing and maintaining approximately 120 feet more or less of
6 inch gas main in Massachusetts Ave., Lexington. From the existing 6 inch gas main at house #2692, westerly to
the rear entrance of the new Hastings Elementary School, 7 Crosby Dr. In order to provide a new service to
the school.
SUGGESTED MOTION:
Move to approve petition from National Grid to install and maintain approximately 120 feet more or less of 6
inch gas main in Massachusetts Ave., Lexington. From the existing 6 inch gas main at house#2 692, westerly to
the rear entrance of the new Hastings Elementary School, 7 Crosby Dr.
FOLLOW-UP:
Engineering requires street opening permits
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 7:40 p.m.
ATTACHMENTS:
Description Type
PETITION of NATIONAL GRID FOR GAS MAIN LOCATIONS
Town of Lexington Board ofSelectmen:
The lationalgrid hereby respectfully requests your consent to the locations of mains as
hereinafter described for the transmission and distribution of gas in and under the following public
streets, lanes,highways and places of the'Town of Lexington and of the pipes, valves, governors
manholes and other structures, fixtures and appurtenances designed or intended to protect or operate said
mains and accomplish the objects of said Company; and the digging up and opening the ground to lay or
place same:
To install.and maintain approximately 120 feet more or less of 6 inch gas main in Massachusetts
Ave., Lexington. From the existing 6 inch gas main at house #2 92,westerly to the rear entrance
of the new Hastings Elementary School,7 Crosby Dr. In order to provide a new service to the
school.
Date: June 27, 2019
y,
&4� b&LIU.-
Barbara H. Kelleher
Permit Representative
Town of Lexington Board of Selectmen:
IT IS HEREBY ORDERED that the locations of the mains of the 1lationalgrid for the transmission and
distribution of gas in and under the public streets, lanes, highways and places of the Town of
Lexington substantially as described in the petition dated June 27,2019 attached hereto and hereby
made a part hereof, and of the pipes, valves, governors,manholes and other structures, fixtures and
appurtenances designed or intended to protect or operate said mains and/or accomplish the objects o
said Company, and the digging up and opening the ground to lay or place same, are hereby consented to
and approved.
The said 1 lationalgrid shall comply with all applicable provisions of law and ordinances of the
Town of Lexington applicable to the enjoyment of said locations and rights.
Date this day of , 20
I hereby certify that the foregoing order was duly adopted by the of
the Town of MA on the day of , 2 .
y.
Title
wo# 128241
RETURN ORIGINAL TO THE PERMIT SECTION
NATIONAL GRID
0 SYLVAN RD,WALTHAM, MA 02451
RETAIN DUPLICATE FOR YOUR RECORDS
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NOTICE TO ABUTTERS
June 28, 2019
In conformity with the requirements of Section 22 of Chapter 166 of the General Laws (Ter. Ed.),
you are hereby notified that a public hearing will be held in the Selectmen's Meeting Room,
Town Office Building, of the Town of Lexington, Massachusetts, on July 8t", 2019
at 7:00 p.m., upon the following petition of National Grid for permission to construct and location
for gas mains and the pipes, valves, governors, manholes and other structures, fixtures and
appurtenances designed or intended to protect or operate said mains and accomplish the
objects of said Company; and the digging up and opening the ground to lay or place same
under the following public way(s) of Lexington:
Massachusetts Ave:
• To install and maintain approximately 120 feet more or less of 6 inch gas main in
Massachusetts Ave., Lexington. From the existing 6 inch gas main at house #2692,
westerly to the rear entrance of the new Hastings Elementary School, 7 Crosby Dr. In
order to provide a new service to the school.
T ri c4,.a1 M cd ate4taz
Engineering
Department of Public Works
Please direct inquiries to Barbara Kelleher (617) 293-0480
CC:
Barbara Kelleher
Permit Representative
National Grid
40 Sylvan Road
Waltham, MA 02451
FLORES-SERRANO EFREN
2652 MASS AVE
Lexington, MA 02421
AHMEDSTEPHANIE
2663 MASS AVE
Lexington, MA 02421
ALTAF M RANA
2678 MASS AVE
Lexington, MA 02421
SH PI LN ER MARC Z
2685 MASS AVE
Lexington, MA 02421
BLUME TODD
2692 MASS AVE
Lexington, MA 02421
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Grant of Location for National Grid - Augustus Road
PRESENTER:
ITEM
NUMBER:
Barbara Kelleher, National Grid
I.4
SUMMARY:
National Grid hereby respectfully requests your consent to the locations of mains as hereinafter described for
the transmission and distribution of gas in and under the following public street:Augustus Road.
The goal is to install and maintain approximately 90 feet more or less of 6- inch gas main in Augustus Road,
Lexington from the existing 6-inch gas main at house# 5, northwesterly to house# 4 for a new gas service.
SUGGESTED MOTION:
Move to approve the installation and maintenence of approximately 90 feet more or less of 6- inch gas main in
Augustus Road, Lexington from the existing 6-inch gas main at house# 5, northwesterly to house# 4 for a
new gas service.
FOLLOW-UP:
Street opening permit required by Engineering
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 7:45 p.m.
ATTACHMENTS:
Description Type
PETITION of NATIONAL GRID FOR GAS MAIN LOCATIONS
Town of Lexington "Board of Selectmen:
The Iationalgrid hereby respectfully requests your consent to the locations of mains as
hereinafter described for the transmission and distribution of gas in and under the following public
streets, lanes, highways and places of the Town of Lexington and of the pipes, valves, governors,
manholes and other structures,, fixtures and appurtenances designed or intended to protect or operate said
mains and accomplish the objects of said Company; and the digging up and opening the ground to lay or
place sane:
To install and maintain approximately 90 feet more or less of 6 inch gas main in Augustus Rd.,
Lexington. From the existing 6 inch gas main at house## 5, northwesterly to house ## 4 for a new
gas service.
]ate: 1Iav 242019
I I
•
Barbara H. Kelleher
Permit Representative
Town of Lexington Board of Selectmen:
IT IS HEREBY ORDERED that the locations of the mains of the I ati n l rid for the transmission and
distribution of gas in and under the public streets, lanes, highways and places of the Town of
Lexington substantially as described in the petition dated May 21, 2019 attached hereto and hereby
made a part hereof, and of the pipes, valves, governors, manholes and other structures, fixtures and
appurtenances designed or intended to protect or operate said mains ardor accomplish the objects of
said Company, and the digging up and opening the ground to lay or place same, are hereby consented to
and approved.
The said I ationalgrid shall comply with all applicable provisions of lave and ordinances of the
Town of Lexington applicable to the enjoyment of said locations and rights.
Datethis,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, day of , 20
I hereby certify that the foregoing order was duly adopted by the of
theTown of , IAA on t ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,.,,,,,.,,,,,,,,,,,,,,,,,,,,,,,,,
e,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,, day of 2 ,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,•
By.
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Title
wo # 124942
RETURN ORIGINAL To THE PERMIT SECTION
NATIONAL GRID
40 SYLVAN RD, WALTHAM, MA 02451
RETAIN DUPLICATE FOR YOUR RECORDS
FORM# 1 ,Rev.90
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ABUTTERS LIST
AUGUSTUS RD.
RUEY NUNG CHUAG 2 AUGUSTUS RD LEXINGTON MA 02421
SOLOMON RHQNpA M (TE) 3 AUGUSTUS RD LEXINGTON MA 02421
STERNS FT 2000(TE) 4 AUGUSTUS RD LEXINGTON MA 02421
JEKEL DAN 5 AUGUSTUS RD LEXINGTON MA 02421
LUCIANI CLAUDIO 6 AUGUSTUS RD LEXINGTON MA 02421
M J BARRETT 7 AUGUSTUS RD LEXINGTON MA 02421
TAM WILLIAM 8 AUGUSTUS RD LEXINGTON MA 02421
REYNOLDS JOSfPH E 9 AUGUSTUS RD LEXINGTON MA 02421
iQ AUGUSTUS RD RT/TRUST 10 AUGUSTUS RD LEXINGTON MA 02421
DELGRECO PETER A it AUGUSTUS RD LEXINGTON MA 02421
MUSTO ARMAND E 12 AUGUSTUS RD LEXINGTON MA 02421
GE GUO 14 AUGUSTUS RD LEXINGTON MA 02421
HUANG JINYONG 15 AUGUSTUS RD LEXINGTON MA 02421
GREWAL GURMIT S 17 AUGUSTUS RD LEXINGTON MA 02421
MARTYNIAK ANTHONY 18 AUGUSTUS RD LEXINGTON MA 02421
ARAI KEN 19 AUGUSTUS RD LEXINGTON MA 02421
SHAW PL.
RADZ EDMUND J 3 SHAW PL LEXINGTON MA 02421
LIU HSI-CHING 4 SHAW PL LEXINGTON MA 02421
PL n c� 5 SAAW 5 SHAW PL, L6x 1&�,-roAl Ma 0414.lr
NOTICE TO ABUTTERS
May 21, 2019
In conformity with the requirements of Section 22 of Chapter 166 of the General Laws (Ter. Ed.),
you are hereby notified that a public hearing will be held in the Selectmen's Meeting Room,
Town Office Building, of the Town of Lexington, Massachusetts, on July 8t", 2019
at 7:00 p.m., upon the following petition of National Grid for permission to construct and location
for gas mains and the pipes, valves, governors, manholes and other structures, fixtures and
appurtenances designed or intended to protect or operate said mains and accomplish the
objects of said Company; and the digging up and opening the ground to lay or place same
under the following public way(s) of Lexington:
Augustus Road:
To install and maintain approximately 90 feet more or less of 6 inch gas main in Augustus
Rd, Lexington. From the existing 6 inch gas main at house # 5, northwesterly to house # 4
for a new gas service.
By: Trt c�,al Mato tet-al
Engineering
Department of Public Works
Please direct inquiries to Barbara Kelleher (617) 293-0480
CC: REYNOLDS JOSEPH E RADZ EDMUND J
Barbara Kelleher 9 Augustus Rd 3 Shaw PI
Permit Representative Lexington, MA 02421 Lexington, MA 02421
National Grid
40 Sylvan Road 10 AUGUSTUS RD RT/TRUST LIU HSI-CHING
Waltham, MA 02451 10 Augustus Rd 4 Shaw PI
Lexington, MA 02421 Lexington, MA 02421
RUEY NUNG CHUAG DELGRECO PETER A PLACE 5 SHAW
2 Augustus Rd 11 Augustus Rd 5 Shaw PI
Lexington, MA 02421 Lexington, MA 02421 Lexington, MA 02421
SOLOMON RHONDA M (TE) MUSTO ARMAND E
3 Augustus Rd 12 Augustus Rd
Lexington, MA 02421 Lexington, MA 02421
STERNE FT 2000 (TE) GE GUO
4 Augustus Rd 14 Augustus Rd
Lexington, MA 02421 Lexington, MA 02421
JEKEL DAN HUANG JINYONG
5 Augustus Rd 15 Augustus Rd
Lexington, MA 02421 Lexington, MA 02421
LUCIANI CLAUDIO GREWAL GURMIT S
6 Augustus Rd 17 Augustus Rd
Lexington, MA 02421 Lexington, MA 02421
MJ BARRETT MARTVNIAK ANTHONY
7 Augustus Rd 18 Augustus Rd
Lexington, MA 02421 Lexington, MA 02421
TAM WILLIAM ARAI KEN
8 Augustus Rd 19 Augustus Rd
Lexington, MA 02421 Lexington, MA 02421
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Approve Acceptance of Donations Made to Recreation Department
PRESENTER: ITEM
NUMBER:
Melissa Battite, Director of Recreation
& Community Programs I.5
SUMMARY:
The Board is being asked to accept donations of scoreboards and bleachers on Recreation facilities to benefit
the Lexington Community. There are three separate donations for consideration:
. Lexington Youth Lacrosse- 3 Scoreboards at Lincoln Park
• Lexington Public Schools - 1 Scoreboard at Dr. Harold Crumb Football Field
• Lexington High School Boosters/Boys Soccer- Bleacher System at Lincoln Park Field # 2
Attached is a copy of the request from the Recreation Department.
SUGGESTED MOTION:
Move to approve acceptance of donation from Lexington Youth Lacrosse (LYL) of three scoreboards at Lincoln
Park.
Move to approve acceptance of the donation from the Lexington Public Schools of the scoreboard at the Dr.
Harold Crumb Football Field.
Move to approve acceptance of the donation from the Lexington High School Soccer Boosters of the
bleachers at Lincoln Park Field #2.
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 7:50 p.m.
ATTACHMENTS:
Description Type
D Donations to Recrelatiorl. "Backup Material
t�
Lexington
'�I°°IIIIIII'III".III illl„iii IIII�ullllh,�w'�
MEMORANDUM
. Jim Malloy,
Town Manager
FROM: Melissa Battite, Director of� m
RecreationI
RecreationDATE- July 2, 2019
SUBJECT: Donation Requests
On behalf of the IRecreation Committee, request to be included on the Julyr
Selectmen agenda to present three proposed donations in accordance with the Board of
Selectmen Policy, Naming of Facilities .
CommitteeThe Recreation j
donations for installation on RecreationILexington Community. There
are three separate donation requests Included; Lexington , Lexington Public
LexingtonSchools and Lexington High School Boosters/Boys Soccer.
Thank you
Three Scoreboards- Ll*ncoln Park
install
placed at each of the synthetic fieldsIwill be solar powered
and will be according to the specificationswill available,
Lincolnby LYL as well as the many other sports and permit holders of I
will be placed on each fieldin coordinationI Idance from the Director of Recreation
& Community Programs and the Director of Public Works. The League recently concluded a
very successful fundraising campaign to fund the purchase of the three boards and has
requested to have installation take place during
During its May 2019 Recreation Committee I
The Recreation Committee r" Lexington
(LYL) of three r Lincoln Parkutilized Lexington Public
Lexingtonthe sports organizations. i
will t
and Communityt .. The Recreation Committee
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One Scoreboard- Center Recreation Complex Dr. Ha,,rry_Crumb Field
Lexington Public Schools has requested to remove and replace the scoreboard currently located
at the Center Recreation Complex/Dr. Harry Crumb Field. The scoreboard will be located in the
same location as the current board, wi •
ll be solar powered and include two extra sets of remote
controls for the community to use. The DPW will assist with the coordination of sandblasting
and painting of the existing stanchions. The anticipated schedule is to have the removal,
preparation and installation complete by the end of August. The first home football game is
September 6, 2019.
During its June 2019 Recreation Committee meeting.*
The Recreation Comm'ttee votes to accept the donation from the Lexington Public
Schools of the scoreboard at the Dr. Harold Crumb Football Field, in coordination with the
Recreation and Community Programs Department. The vote was 4-0.
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One bleacher s stye --Lir��c+al�► 'ark Meld�#�
Lexington High School Boosters-- Buys Soccer has requested to donate a bleacher system to be
placed at the Lincoln Field #2. The DPW will assist in preparing the landscape in order to
receive the bleachers upon delivery. The bleachers will be available for use by any spectators
visiting the Lincoln #2 field. The Boosters continue to fundraise and has requested to have the
bleacher installation take place by the end of August.
Curing its June 2019 meeting,the Commission can Disabilities voted to approve the bleacher
system located and product specifications.
Curing its June 2019 Recreation Committee meeting:
The Recreation committee rotes to accept the donation from the Lexington High School
Soccer Boosters of the bleachers at Lincoln #2 as depicted in the figure, in coordination with
DPW, the Recreation and Community Programs Department, and the Board of Selectmen. The
vote was -c .
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AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
FYI 9 Year-End Budget Adjustments
PRESENTER4.
: ITEM
Carolyn Ko sno ff Assistant Town NUMBER:
Manager for Finance/Comptroller;
Jennifer Hewitt Budget Officer
I.6
SUMMARY:
A vote is requested for this agenda item.
Staff will present the attached F Y 19 end-of-year budget adjustments.
SUGGESTED MOTION:
Move to approve and sign the end-o f-year budget transfer, salary adjustment account transfers, and Revolving
Fund increase.
FOLLOW-UP:
Finance department will process year-end transfers prior to the 2019 year-end close.
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 7:55 p.m.
ATTACHMENTS:
Description Type
w u
Town of L
11#
T : Board of Selectmen
SUBJECT: Request for Transfer from Salary Transfer Account
Request is hereby made for the following transfer from the Salary Transfer Account as
appropriated via vote of Annual Town Meeting:
1. Amount requested: $92,000.00
. To be transferred to:
Adult Libra - Regular Wages 1 1 1- 1110
Account Name Account Number
. Explanation for purpose of transfer:
The FY2019 budget was built using prior contract rates for the Librarian contract,
which was settled over the course of FY201 . This request adjusts the FY201
budget for the updated rates for both base salary and Sunday Premium Pay, and
also corers approximately$24,600 in retro pay for FY o1 .
Department Head
Action of Board of Selectmen:
Date
Approved Disapproved
Transfer voted in the sure of: $92,000.00
Chairman, Board of selectmen
Salary Transfer-Library
11 cif
m
,u. Town of L
AMR"
T : Board of Selectmen
SUBJECT: Request for Transfer from Salary Transfer Account
Request is hereby rude for the following transfer from the Salary Transfer Account as
appropriated via vote of Annual Town Meeting-,
1. Amount requested: $236,013.00
2. To be transferred to,,�
Police Administration Regular W 1 21 31-5111
Account Name Account Number
3. Explanation for purpose of transfer.,
The FY2019 budget was built using prwilor contract rates for several contracts within
the Police Department budget-Crossing Guardsp Dispatch, and the Patrolman's
Association, Alf,were settled over the course of FY2019. This request adjusts the
current year budget for the updated rates for both base salary and overtime,,
including $8,565 of retro paid to the crossing Guards for FY2017 and FY2018,
Department dead
Action of Board of Selectmen:
Date
Approved� Disapproved
Transfer voted In the sum of: $236,013.00
Chairman,,, Board of Selectmen
Salary Transfer- Police, non-IBP
A M"Wpm log
T : Board of Selectmen
SUBJECT: Request for Transfer from Salary Transfer Account
Request is hereby made for the following transfer from the Salary Transfer Account as
appropriated via Grote of Annual Ton Meeting:
1 Amount requested $420tOOO.00
2. To be transferred to,
Police Administration - regular Wag 100 1 1- 111
Account Name Account Number
. Explanation for purpose of transfer:
The FY2019 budget was built using prior contract rates for several contracts within
the Police Department budget, including the superior Officers which was settled
during FY01 . This request adjusts the current year budget for the updated rates
for both base salary and overtime, and also corers approximately$204,000 in retro
pay for FY2017 and FY 1 ,,
Department Dead
Action of Board of Selectmen:
Date
Approved Disapproved
Transfer voted in the sum of: $420,000.00
Chairman, Board of Selectmen
Salary Transfer-Police
Town of Lexington
°`# d
TO: Appropriation Committee& Board of Selectmen
SUBJECT""', Request for End of Year Transfer between Departmental Line-Items
Request est is hereby made for the following transfer between line-items as appropriated aria a
vote of Annual Torn Meeting, in accordance With I I,,,G..L,,. Chapter 44, Section 33B, paragraph
(b), as amended by the Municipal Modernization Act,
1. Amount requested., ,000.00
, To be transferred to�,R
Fire Administration -Vehicles 10022312-54707
Account dame Account Number
To be transferred from-,
Fire Administration-Other Comp 10022311-51120
— — w
Account Name Account Number
Present balance in Appropriation A 1 g, b.00
A, Explanation for purpose of transfer:
The Town recently appointed a new Fire Chief who does not comfortably fit
in the existing -1 command vehicle which was purchased during the tenure
of the previous Chief. This transfer would accelerate the replacement of the
current C-1 vehicle. The current D-1 vehichle will be repurposed to the Fire
Inspector, replacing vehicle - t which is nearing the end of its useful life.
Vehicle C-6 will be traded in to offset the cost of the new -1.
This expense will be funded by a transfer from the Fire Personal Service
budget, which has sufficient fronds remaining after all payroll obligations to
support this transfer.
Department Head
Action of Select Board:
Date
Approved Disapproved
Transfer voted in the sum of: $43,000.00
Chairman, Board of Selectmen
Action of Appropriation Committee:
Date
Approved� Disapproved
Transfer voted in the sum of:
Chairman,Appropriation Committee
Y Transfer-Fire
Revolving TownLexington
Fund
Increase
TO: Appropriation Committee & Board of Selectmen
SUBJECT Request uNest for Increase of Authorization of Departmental Devolving Funds
Request is hereby rude for are increase in the authorization of a Departmental Revolving
Fund authorized aria vote of Annual Town Meeting in accordance with NIGL, Chapter 44,
section 53E 1 .
1. Revolving ing Fund to be Increased: Regional Cache- Hartwell Ave.
2. Original Authorization $10,000
. Amount of Increase Requested $10,000
4. Revised Authorization $20,000
.o Explanation for purpose of authorization increase:
Lexington serves as the repository for a Regional nal Equipment resource.
Member communities "rent"the equipment,ent, and Lexington manages es the
upkeep and storage. Activity in FY 01 g has been at higher levels than in"
the past, which has had greater gear and tear on the equipment. More
than $22,000 in revenue has been received so far, this request merely
provides authorization for the DPW to spend that revenue on NERAC
Cache equipment repairs, as needed.
Action of Board of Selectmen.
Date
Approved� Disapproved
Authorization voted in the sum of: $20,000
Chairman, Board of Selectmen
Action of Appropriation Committee:
Date
Approved� Disapproved
Authorization rioted in the sum f: o,o o
Chairman,Appropriation Committee
Revolving Fund Increase FY2019 regional Cache
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Craft'd Company - Middlesex County Beer Festival
PRESENTER:
ITEM
NUMBER:
Christine Healy, Craft'd Company
I.7
SUMMARY:
Craft'd Company has submitted requests for approvals for a proposed beer festival to be held at Fletcher Park
on Saturday,August 24, 2019 (rain date Sunday, August 25, 2019) featuring breweries located in Middlesex
County. Also featured will be live music, artists and artisans, and food trucks.
C raft'd Company met with all Town Departments and Doug Luc ente as the Chair of the Board of Selectmen
on Monday, July 1, 2019 to review their proposal and address any concerns or issues of the various Town
departments. As part of the proposal, Craft'd Company was requested to develop a plan to include a donation
to a local organization(or Town), specifically we discussed a portion of the proceeds to go toward the
reconstruction of the Visitors Center. This should be part of the presentation to the Board of Selectmen.
The Board of Selectmen is being asked to approve a One-Day Liquor L is ens e and Entertainment lic ens e s for
this event.
Craft'd Company is working with the Town Managers Office, Health, DPW, Fire and P o lice Departments for
any other required permits/fees.
SUGGESTED MOTION:
Move to a One-Day liquor lic ens e and Entertainment licenses to be issued to C raft'd
Company, conditional on obtaining required approvals from Town Departments and providing for public
safety staffing as required by the Police Chief, for the Middlesex County Craft Beer Festival to be held at
F letc her Park on Saturday, August 24, 2019 from 1:00 PM to 5:00 PM with a rain date of Sunday,August 25,
2019.
FOLLOW-UP:
Selectmen's O ffic e
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:05 p.m.
ATTACHMENTS:
Description Type
D Application I day 1 1............. f,-Vd. brr P,any llacktip Material
TOWN OF LEXINGTON
SELECTMEN'S OFFICE
, RIL �
APPLICATION FOR
ONE-DAY LIQUOR LICENSE
The Board of Selectmen issues one-day liquor licenses to for-profit and non-profit organizations
that serve liquor and charge either a cover charge or for each drink. Please fill in this form
completely and return to the Selectmen's Office along with a check for $25.00 made payable to the
Town of Lexington.
BUSINESS/FUNDRAISING ORGANIZATION: Craft'd Company
CONTACT NAME AND NUMBER:
ADDRESS FOR MAILING: 207 Gold Street#2,Boston,MA 02127
EMAIL ADDRESS:
TITLE/PURPOSE OF EVENT: Middlesex County Beer Festival
LOCATION AND ADDRESS: Fletcher Park
DATE OF FUNCTION: Saturday,August 24,2019
TIMES OF FUNCTION: 1-2pm VIP Hour 2-5pm Main event
TYPE OF LIQUOR TO BE SERVED: Craft beer
DATE AND TIME WHEN LIQUOR DELIVERED: 11 am
DATE AND TIME WHEN LIQUOR REMOVED: 6pm
ADDITIONAL INFORMATION: See attached
Tickets:Designated Driver(no samples);General Admission un iml e oz pours); extra nour or sampling with special re eases from
breweries,unlimited 2 oz pours and limited edition shirt).Local Breweries;food trucks;Local live music;Local businesses and artisans with
booths in the event
82-1320022
Authorized Sign re Federal Identification No. or
Social Security Number
Middlesex County Beer Festival
Beer Serving Procedure
Company: Craft'd Company
Contact: Christine Healy,
Date & Time: Saturday, August 24, 2019 from 1 PM to 5PM
Location: Fletcher Park
• Beer will only be permitted within the cordoned off area of Fletcher Park.
• Signage will indicate that alcohol cannot leave the designated event area.
• There will be one entrance/exit to the festival that will be monitored by staff to
ensure all people entering the festival are observed and no beer leaves the
designated area.
• No unattended children will be allowed into the festival.
• Beer will be served from 1:OOpm until 5:OOpm
• Craft'd Company has coordinated with the Department of Public Works, Fire
Department, Police Department, Health Department, and the Town Managers
Office regarding the Festival.
Procedure for serving beer to the public:
1. Attendees must purchase a ticket online in advance or at the entrance of the
event.
2. After presenting a valid ID to security staff, attendees will receive a wristband
(Gold for VIP, Green for General Admission, and Red if they are not allowed to
drink during the event.)
3. Attendees that have purchased a beer sampling ticket and are 21+ will receive a
branded tasting glass.
4. Attendees with Gold and Green wristbands and a tasting glass may then proceed
to beer vendors, with TIPS certified (or equivalent) servers, to get a 2oz pour of
beer.
5. Two Police details and security staff will be on site for the duration of the event.
Additional precautions being taken:
• Free water will be available to all attendees.
• 3-5 food vendors will be on-site selling food and soft drinks for attendees.
• Designated Driver tickets will be sold at a discounted rate of$10.
• Ride sharing, public transportation, and the bike path will be promoted as
alternatives to driving.
Middlesex County Beer Festival
Participating Breweries
Company: Craft'd Company
Contact: Christine Healy,
Date & Time: Saturday, August 24, 2019 from 1 PM to 5PM
Location: Fletcher Park
1. BearMoose Brewing, Everett
2. Exhibit `A' Brewing, Framingham
3. Flying Dreams Brewing, Marlborough
4. Ground Effect Brewing, Hudson
5. Hopsters, Newton
6. Idle Hands Craft Ales, Malden
7. Lamplighter Brewing, Somerville
8. Lookout Farm, Natick
9. Lost Shoe Brewing, Marlborough
10. Medusa Brewing, Hudson
11. Remnant Brewing, Somerville
12. Saltbox Kitchen Brewery, Concord
13. Small Change Brewing, Somerville
14. Start Line Brewing, Hopkinton
15. Strange Brewery, Marlborough
16. Winter Hill Brewing, Somerville
Potential additions:
1. Amory's Tomb, Maynard
2. Battle Road Brewing, Maynard
3. Down the Road Beer Co., Everett
4. Jack's Abby & Springdale, Framingham
5. John Harvard's Brewhouse, Framingham
6. Lord Hobo Brewing, Woburn
7. Merrimack Ales, Lowell
8. Mighty Squirrel, Waltham
9. Navigation Brewing, Lowell
10. Night Shift Brewing, Everett
11. True West, Acton
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AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Approve Memorandum of Understanding- Lexington Municipal Management Association
(LMMA)
PRESENTER:
ITEM
NUMBER:
James Malloy, Town Manager
I.8
SUMMARY:
As per previous discussions with the Board, attached please find the signed Memorandum of Understanding
between the Town of Lexington and the LMMA Union for the amendments to the collective bargaining
agreement.
SUGGESTED MOTION:
Move to approve and authorize the Town Manager to sign the Memorandum of Understanding between the
Town and the Lexington Municipal Management Association for the contract period of July 1, 2019 through
June 30, 2022.
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:20 p.m.
ATTACHMENTS:
Description Type
APR(.N-
I --f
BetweenMemorandum of Understanding
LexingtonTown of
And
.Lexington Municipal Manage ment.Ass ociation
LMM.A
The °r of Lexington and the Lexington.Municipal Management Association.hereby agree to the following
amendments to the collective bargainingagreement, which expires June 3
1. Preamble
4. Definitions
Correct definition of Part-Time Employee t. read 41� 0 hours or more!� per week.
2. Article I Recognition of the Association/Wage and Step Schedule
Add
Assistant Building Commissioner Grade
Conservation Director Grade 4
4 Article Hours of Work
Delete e.`37 hour week for Cary Library".
4. Article ays
Sections 8,12 and 8.4 Correct ar m t re ffi ours r or �
Article 18 Tuition Reimbursement
After first sentence in. Section 1. -'12, add Courses must be from are accredited institution,"
5. Article 1.9 Clothing Allowance
Add Assistant Building Commissioner and Conservation Director under*Land Use, Health and.
Developments
Effective July . 20.19, the clothing allowanceshall increase to S300.
Effective lv 1, t clot cy allowance crease to .
Effective uv 2 , t lothing allowance shall increase to $400,
6. Article 10 SickLeave
Add the following language in 1 s 2 m Employees absent for two 2) consecutive days on two 2) or more
occasions in.one year, shall, if so requested, return to work present to their immediate supervisor
le ible odor's certificate specifving the nature of their illness, It is the intent of this lame to permit
supervisors to dealwith erceiv uses of sick leave are.individual a.s s rather than impose
restrictions all employees.
F17
0. Longevity
Delete current ongevity table and replace with"
FY?O FY21 F Y2 2
After 5 years S 150 $300 S500
S,600 900 After 10 vears S400
After 15 years S600 S900 $1,200
After 20 years S900 S11200 $1 iocl
I After 25 years S 1 2,00 S11500 $100
LA—fftte r 3 0 ye ars _$1 0-0 S1,7 $
I - .1 50 1 1,000
8. Article 25 Compensation
Amend Article 2 5),1 to reflect the following base wage increases:
4=�
Fiscal Year 2020 2,0% base wage increase effective 07/01/1201.9
ZD
/Z
Fiscal Year 202 1. 2,0% base wage increase effective 07/'01.")020
Fiscal Year 2022 2.0% base wage increase effective 07/01/202 1
9. Article 25 Compensation
-Add new Section 25.7 Merit Step
There shall be a new step (Step 9—Merit Step) added to the Wage and Classification Schedule as of July
I 2019. This Merit Step shall be 2.5% greater than Step 8. Any employee who has been at the
maximum step of his/her range for a minimum of three years, shall be eligible for the Merit Step
Increase, provided that the current performance review and all prior performance reviews have indicated
' ts" or"'ex ds ' expectations level in all areas of the review for the prior three vears, Said Merit
a meecee "
Step shall be at the sole discretion of the Town Manager or designee and shall not be subject to Article
5, Conflict Resolution., of this Agreement,
10. Article 30 Effective Date and Duration
Delete the words 'two (2)" and replace with ''three (3)". Replace the dates 'July 1, 2016 through
June 30 2019 with 'July 1 2019 through June 30 2011-2
Signed thi's day of 2019.
Town of Lexington Lexington Munich"Jal M.a gerne t Association
James Mallov Michael Golden
V
Town Manager President, LMM-A
Witness
2
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Approve Acceptance of Gift - US S Lexington
PRESENTER:
ITEM
NUMBER:
Jim Malloy, Town Manager
I.9
SUMMARY:
At the last Board of Selectmen's meeting, we discussed the donation from Charles Bonnano of a model ship
of the US S Lexington. I'm attaching the P o werP o int that the Board reviewed at the last meeting and I am
recommending that we accept this gift with the understanding that the Town will find a suitable location for the
gift.
SUGGESTED MOTION:
Move to accept the gift from Charles B o nnano of the model ship US S Lexington.
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:25 p.m.
ATTACHMENTS:
Description Type
ail
gil
41,
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AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Town Office Building Hours of Operation Six-Month Review
PRESENTER: ITEM
NUMBER:
Jim Malloy, Town Manager
I.10
SUMMARY:
As the Board will recall we established the current Town Office hours as a pilot program with a six month
review. Over the past month, I requested Town Office staff to maintain a record of how many
residents businesses came in during the 4:30 to 7:00 PM timeframe(between 5/14 and 6/11). The breakdown
is as follows:
Treasurer/Collector 25
Assessor 12
Economic Development 11
Town Clerk 29
Building 55
One Month Total 132
Annualized 11584
We also conducted a survey(survey monkey) of the staff. I've attached the summary report as well as a
printout of the open ended question. Overall as a new program, I believe the amount of residents businesses
taking advantage of the late night and the support of the staff demonstrates sufficient reason to continue the
hours and am recommending that we make it permanent. I do believe we need to do better advertising of the
hours and make it more prominent on our building as some have suggested.
There were some comments about addressing the night of the week that the late night is scheduled to make it
more consistent with meeting nights (most suggested Monday and then Wednesday). For those staff that are
required to stay late for a meeting, there can always be other accommodations. At this time, I am
recommending maintaining the current late night on Tuesday with the understanding that the Town Manager can
work with staff that are required to work late on other nights to attend meetings.
SUGGESTED MOTION:
Move to make the current office hours permanent, with the Town Office Building hours being set at Monday,
Wednesday and Thursday from 8:30 AM to 4:30 PM; Tuesday from 8:30 AM to 7:00 PM; and Friday 8:30
AM to 1:00 PM.
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:30 p.m.
ATTACHMENTS:
Description Type
Employee Survey for Town Office Building Hours
Q1 Do you prefer the current Town Office Building Hours (Tuesday until 7
p.m., and Friday until 1 p.m.)?
Yes
No ■
0% 10°/a 20% 30% 40"/0 50% 60% 70% 80% 90% 100%
ANSWER CHOICES RESPONSES
Yes 8621% 50
No 13.79% 8
TOTAL 58
1 / 5
Employee Survey for Town Office Building Hours
Q2 Would you like to have the current hours become permanent?
An: nFre<l: 58 SkiPperl. 0
Yes
No ■
0% 10% 20% 30% 40% 50% 60% 70% 80% 90% 100%
ANSWER CHOICES RESPONSES
Yes 8621% 50
No 13.79% 8
TOTAL 58
2 / 5
Employee Survey for Town Office Building Hours
Q3 Would you have any difficulty if the late night was switched to a
different day (i.e. Monday or Wednesday)?
Yes ■
No
0% 10°/a 20% 30% 40"/0 50% 60% 70% 80% 90% 100%
ANSWER CHOICES RESPONSES
Yes 1207% 7
No 87.93% 51
TOTAL 58
3 / 5
Employee Survey for Town Office Building Hours
Q4 Would you prefer to return to the previous Town Office Building Hours
(Monday-Friday, 8:30 a.m. - 4:30 p.m.)?
Yes -
No
0% 10°/a 20% 30% 40"/0 50% 60% 70% 80% 90% 100%
ANSWER CHOICES RESPONSES
Yes 1552% 9
No 84.48% 49
TOTAL 58
4 / 5
Employee Survey for Town Office Building Hours
Q5 Doyou have an feedback about the chan a of hoursyou wouId Iike
Y g
to share? (25 word limit)
Answered 8 SIk.iii p�pe
5 / 5
Do you have any feedback about the change of hours you would like to share? (25 word limit)
I would prefer that the late night be switched to Thursday.
I would prefer if we kept the hours. Moving the long day to Monday would be best.
Friday afternoons off are nice, but long day is disruptive.
I am in favor of retaining the change of hours. It allows for a convenient way to accommodate working residents at
our counter and with scheduling Assessor inspections on Tuesday evenings.
My job does not impact customer service on a daily basis. I program applications. I enable departments to have
access to the data that I develop so they can work independently of me. I work on long term projects and perform
audits and manage databases.This is a task I could do from home remotely. My commute is over an hour long, so I
had previously set up a formal agreement to work a 4 day work week, but I was no longer allowed to do that after the
town changed office hours, because I could not work a full day on Friday when I needed to change my day off.
I think switching to a Monday or Wednesday would make more sense. Or on a day when is most popular for the late
night meetings. We have received good feedback from residents about have one night with extended hours.
As an employee, I find it very beneficial to have 1 late night because it gives me an opportunity to get caught up on
much of my work.
This gives residents and developers an opportunity to come in and meet with staff after their normal business hours
instead of them having to take time off from work.
It is very wonderful! I am now able to schedule all of my doctor's appointments on Friday afternoons so I don't have to
miss any work! I have several times had homeowners who work full time come to the Town office because they are
unable to visit the town offices during their hours. Before the hour change people would always tell me that they were
taking the time off work to come in to the town off ices. Now they are able to do it all without sacrificing their work
hours.
Love the new hours.Allows for time to take care of personal things on Friday afternoon.
I feel the new hours really help. I am able to go to Dr. appointments on Friday's or other appointments since it's a
shorter day. I also noticed when we worked a full day Friday we do not get many people into the office Friday
afternoons. I think the new schedule is great! I want to keep half day Fridays!
As a resident of another town that is open late one evening also, I believe it gives people that work full time an option
to conduct business when needed.As an employee, I believe its been a positive change and has been helpful for
productivity.
Towns have adopted and made this change permanent because it benefits a majority of employees and residents
alike. Our department has received a high level of praise from residents who could not make it to the office with
parallel working hours previously.
Allows me more family time and cuts out 2 rush hour commutes. Big fan!
The late night negatively impacts productivity for the rest of the week as employees are exhausted and trying to
recover from the long day, especially since they are working the long hours without a dinner break.
With the restraints of being a public employee, benefits like these modified hours are a small change that make a big
(and positive)difference to our workforce and to the community. It also is environmentally beneficial as it reduces
traffic congestion for two of our evening commutes.
New hours allows for much better commute home on Tuesday's and Friday's
The new hours are wonderful for those of us who commute. It gives us two easier commutes each week and is
definitely a selling point to prospective employees.
This schedule is a huge perk for working here! As a younger person, this makes it more attractive than working in the
private sector.All the residents I have talked to appreciate it.
I think one late day and early Friday is great. If the day was to change I would prefer it to change to Monday, or just
stay the same.
The late night during the week has been very beneficial for residents to call and come in to visit the Land Use, Health,
and Development Department.We have received a lot of positive feedback.
I have appointments on Fridays that I would not be able to attend if hours were to change to a full day.
There are positions in town that have night meetings and working late on Tuesday makes another night at work.
While it may not be as late as a meeting it is another night not home for dinner. Thanks for asking!
When the new Police Station is built,they should include more parking lot lighting for the far end. It's too dark for
people working late in the winter.
Really happy with the new hours as it allows me to pick up my kids from school one day a week and catch up with
their teachers when needed.
I love the new hours. I feel like I get a lot of work done on the late nights, and I get a lot done in my personal life by
the early release on Friday's. I feel like it's a win win.
The current hours are great. I'd prefer extended Mondays. I would not prefer extended Wednesdays.
The small amount of feedback received on change of hours from staff and residents has all been positive. Consider
switching the late day from Tuesday to a different day for TOB staff that have night meetings.
I've had the opportunity to provide a variety of services to the residents, agents and representatives during the trial
months. Many residents are still discovering our operating hours, and would like to see this continue.
I think it is a great way to both better serve the community by offering evening office hours and provide a benefit and
incentive to employees.
This is great. I've heard from residents that come in that they used to have to take time off work and they appreciate
us giving up a night every week. I told them we get off early on Friday to compensate and they've all said that only
makes sense. Several residents said they hope we keep these hours. Thanks. On a personal note, it's helped me
with scheduling kid's doctor's appointments as well as my own. We appreciate the Board considering making this
permanent. Thanks for looking out for the employees and helping residents at the same time!
Contractors and residents utilize these hours very often.Also, a lot of other towns have these hours, so a large
population are used to it.
I really like the one late night and the early release on Fridays. It is nice to be able to pick up my children from school
once a week. It's been a nice perk. Thank you!
The current trial period seems to be working just fine for me.
Monday or Thursday would be slightly preferable as the late night.
Love the new hours. Feel reinvigorated to come back to work Monday after having just those few extra hours off.
Makes a difference!
Not able to work late on Wednesday
A few residents have commented they like the option of meeting or connecting with staff outside the traditional 8:30-
4:30 hours. Thanks.
The plan doesn't work well if you have younger kids who eat dinner earlier.The result is I miss 1 meal a week with my
family, and miss their sports games on Tuesdays.And I don't benefit from leaving 3.5 hours earlier on Friday, even in
the summer. I'd rather have dinner with my children and see their sporting events, especially at their young age.
I have heard positive feedback from residents, contractors and attorneys, they appreciate the chance to see or visit
us later in the day, it has also helped us with inspections that are better done later in the day, it's been all positive,
and as time has passed, more and more customers are becoming aware of the later Tuesday hours.
Wednesday nights might work better because a number of boards and commissions meet then.
I enjoy the current hours.
This is great.We have a residents and businesses come in at night and it seems like more are now they are familiar.
It also keeps us out of traffic two nights a week!
I believe the new hours allows us to serve the residents of Lexington better. I have performed multiple late
afternoon/early evening inspections on Tuesdays that would not have possible unless I had evening hours.
Being closed on Fridays would help.
The same total of offices-open-to-public hours, only shifted, does offer some benefit to hourly personnel in their
commute-time traffic intensity on 2 separate workdays, and that's good for them.
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Town Manager Reappointments
PRESENTER:
ITEM
NUMBER:
Jim Malloy, Town Manager
I.11
SUMMARY:
A vote is requested for this agenda item.
Board of Health
• John Flynn has been a member since 2010. Mr. Flynn's new term will expire April 30, 2022. Ethics
training is up-to-date.
Recreation Committee
• F red eric k DeAngelis has been a member since 1993. Mr. DeAngelis' new term will expire May 31,
2022. Ethics training is up-to-date.
SUGGESTED MOTION:
Move to approve the Town Manager's reappointment of John Flynn to the Board of Health and Frederick
DeAngelis to the Recreation Committee.
FOLLOW-UP:
Town Manager's O ffic e
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:40 p.m.
ATTACHMENTS:
Description Type
D .[..�'l.yn.n..Reappoi.i.i.tr...W.n.tApplica-tioll. flacku p Vl[aferia 1.
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APPLICATION FOR REAPPOINTMENT FOR BOARD/COMMITTE.E MEMBERSHIP
Board/Com.mittee
of Interest., a .
�ED
Full Name.- 07
JUN 2019
Preferred Title TOWN MANAGERS Or:FICE
(please circle) r..' s./Mrs_/Oter
.Home Address:
Length of Residence
in.Lexington.-
Current Occupation.-
Work Address.
Phone Number(s): Home-
Fax Number(s).-
.mail Address:
Comments:
Members of Town boards and committees, as defined by the Conflict of Interest Law, M.G.L. c.
268A, must abide by the standards of conduct as set forth by the Massachusetts State Ethics
Commission. Within 30 days of appointment, and annually thereafter, committee members must
acknowledge receipt of the Summary of the Conflicts of Interest Statute from the Town Clerk.
and thereafter must provide documentation of biennial completion of the on-line training
required by 'the Conflict of Interest Statute. The law places responsibility for acknowledging
receipt of the summaries,, and for completing the online training on the individual. You will be
provided additional infor b
ion the rk pertaining to this law and recently enacted
education and training re ui.r'pme s.
Signature-.
Date
G:A01,_.B&C"s Application
TOWN OF LEXINGTON
APPLICATION FOR REAPPOINTMEN1" FOR BOARDI'COMMITTEE MEMBERSHIP
Board-Conim"t-tee
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Phone . ber : F omen ork:
Fax Nurnber(s):
Email Address:
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Members ofTown boards and committees, as defined by h,(!., Conflict of Interest 1.,aw N/.G.L.
2A, must abide by the standards of conduct as set forth by the Massachusetts State Ethics
Commission. Within 30 days of appointment, and annUally thereafter, committee members
acknowledge reiC off°the Summary oft ofthe Conflicts of Interest Statute from, the Town 'Ierk,
�� thereafter providedocumentation f biennial completion f on-lime rnin
eq u Ar d by the C fl f merest Statute, :I.` e law� places soy for knowled n
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AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Reconsideration - Masslex, LLC Liquor License Transfer at 1666 Massachusetts Avenue
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
I.12
SUMMARY:
On June 3, 2019, the Board approved a Liquor License Transfer Application for 1666 Massachusetts Ave,
from Group R, Inc d/b/a Lexx Restaurant to Masslex, LLC d/b/a Clay Oven Indian Restaurant.
The A B C C sent a "return no action" notification to the Board of Selectmen's Office regarding the transfer
application citing that the applicant needs to submit the following UPDATED information to the local licensing
authority for reconsideration of the application:
• Bank Cover Letter along with the Draft Pledge Agreement and Draft Promissory Note between Masslex
LLC and Leader Bank.
Masslex, LLC has submitted all the necessary paperwork to the Board of Selectmen's Office needed to
request reconsideration.
SUGGESTED MOTION:
Motion to approve submission of the paperwork from Masslex, LLC d/b/a Clay Oven Indian Restaurant as
requested by the ABCC for Reconsideration of their Liquor License Transfer application for 1666
Massachusetts Avenue.
FOLLOW-UP:
Selectmen's O ffic e
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:45 p.m.
ATTACHMENTS:
Description Type
D DOCLIT'nr,,.�,nfs supplied fior Recons ideir,"Ition. 1.1.-ickup Matletial.
Le,ader
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June 25,2019
Kim Katzenback
Office Manager/Executive Clerk
Board of Selectmen
Town of Lexington
1625 Massachusetts Avenue
Lexington,MA
Re: SBA 7a Term Loan for Masslex LLC
Dear Kim,
This letter is to certify that Masslex LLC is approved for a loan amount of$306,000 to acquire the
business located at 1666 Massachusetts Avenue, Lexington, MA. A requirement of the loan is to pledge
the liquor license being purchased to Leader Bank. Please note that Pledge of the Liquor License along
with a Promissory Note will be executed at closing.
Should you have any questions,please do not hesitate to contact me.
Sincerely,
,
„»
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,�rnuuwWmmr Y.
Sandeep Jain
AVP-Commercial Loan Officer
180 Massachusetts Avenue, 3rd Floor
Arlington,MA 02474
Direct: 781-641-7553
Fax: 781-646-3300
The guaranteed portion of the outstanding principal balance of this Note has been transferred
to a Registered Holder for value.
Signature Date
LEADER BANK, N.A.
PROMISSORY NOTE
Loan Amount: $306,000.00 Note Date: July 2019
SBA Loan#:
SBA Loan Name: Masslex LLC
For value received, Masslex LLC ("Borrower"),
a Massachusetts Limited Liability Company with an address of
10 Butterfield Road, Lexington, MA 02420 promises to pay to the order
of Leader Bank, N.A., a national banking association ("Bank"), at the principal office of Bank at
180 Massachusetts Avenue, Arlington, MA 02474, or such other place as the holder hereof shall
designate, the principal sum of
Three Hundred Six Thousand and 00/100 ($306,000.00 )
together with interest thereon, from the date hereof until November 1, 2029 (the "Maturity
Date"). The interest rate on this Note will fluctuate. The initial interest rate is 7.75 % per year.
The initial rate is the Wall Street Journal Prime Rate in effect on the first business day of the month
in which the Small Business Administration ("SBA") received the loan application plus 2.25 %.
Beginning on September 1, 2019 , and on the first day of each calendar quarter thereafter for the
duration of the term of the Note, the interest rate shall be adjusted to 2.25 % above the Wall
Street Journal Prime Rate in effect on the first business day of the month(as published in the Wall
Street Journal) in which any interest rate change occurs without further notice to Borrower. Such
interest rates will be rounded to two decimal places with 0.004 being rounded down and 0.005
being rounded up. Interest shall be calculated on the basis of a 360-day year consisting of 12
months of 30 days each ("30/360 Basis"). If SBA purchases the guaranteed portion of the unpaid
principal balance, the interest rate becomes fixed at the rate in effect at the time of the earliest
uncured payment default. If there is no uncured payment default, the rate becomes fixed at the
rate in effect at the time of purchase.
Based on the initial interest rate, Borrower must pay monthly principal and interest payments of
$3,672.33 monthly beginning on Decemeber 1, 2019, and continue to make monthly principal
and interest payments on the first day of each calendar month thereafter until the Maturity Date.
Bank will apply each installment payment first to pay interest accrued to the day Bank receives
the payment,then to bring principal current,then to pay any late fees,and will apply any remaining
balance to reduce principal. Bank must adjust the payment amount at least annually as needed to
amortize principal over the remaining term of the Note.
Borrower may prepay all or any portion of the unpaid principal balance due under this Note
without any prepayment premium fee or charge. Borrower may prepay twenty percent (20%) or
less of the unpaid principal balance of the Note at any time without notice. If Borrower prepays
more than twenty percent(20%) of the unpaid principal balance of the Note and the Loan has been
sold on the secondary market, Borrower must (a) give Bank twenty-one days (21) prior written
notice of the prepayment; (b) pay all accrued interest as of the date of prepayment; and (c) if the
Bank receives the prepayment less than 21 days from the date Bank received the notice required
above, pay an amount equal to 21 days' interest from the date Bank received the notice, less any
interest accrued during the 21 days and paid under item(b)above. All remaining principal,interest
and other charges not previously paid under the terms of this Note shall be due and payable on the
Maturity Date, if not sooner due hereunder.
If any payment hereunder is not paid within ten (10) days of the date when due, whether
on a stated due date or upon acceleration, (1) such overdue amount shall thereafter bear interest
until paid in full at a rate per annum equal to 5% above the rate of interest otherwise in effect from
time to time hereunder, payable on demand, and (11) the undersigned shall pay the holder a late
payment charge equal to 5% of the overdue amount, payable on demand.
This Note shall, at the option of the holder, become immediately due and payable without
further notice or demand upon the occurrence of any of the following events (each, an "Event of
Default"):
(a) Failure to make any payment hereunder when due and such failure has not been
cured within ten (10) days after written notice, provided that if Bank has given two such notices
in any twelve month period under this subsection(a), then no further notice or cure period shall be
provided under this subsection (a);
(b) Failure for 90 days to discharge any attachment or levy on any property of any
maker hereof;
(c) Any warranty or representation made or furnished to the holder by or on behalf of
any maker, endorser or guarantor hereof shall prove to have been false in any material respect
when made or furnished;
(d) Any other obligation of the maker or any endorser, guarantor or surety for this Note
shall be in default or shall not have been paid when due following any applicable notice and cure
period,by acceleration or otherwise,or shall be declared to be due and payable,or shall be required
to be prepaid(other than by a regularly scheduled prepayment),prior to the stated maturity thereof;
(e) Occurrence of any of the following with respect to any maker,endorser or guarantor
hereof: admission in writing of his or its inability, or be generally unable, to pay his or its debts
as they become due, death, dissolution, termination of existence, cessation of normal business
operations, insolvency, appointment of a receiver of any part of the property of, legal or equitable
assignment, conveyance or transfer of property for the benefit of creditors by, or the
2
commencement of any proceedings under any bankruptcy or insolvency laws by or against, such
person; provided however, in the case of the commencement of any such proceedings against such
person, such person shall have thirty (30) days from the date of the commencement of such
proceedings to dismiss such proceedings provided, however, the death or legal incapacity of a
guarantor shall not constitute an Event of Default provided that Bank shall have received a
guaranty from a replacement guarantor satisfactory to Bank in its sole discretion within thirty(30)
days following the death or legal incapacity of such guarantor;
(f) Failure by Borrower or any guarantor as may be required to deliver to the Bank on
an annual basis, within 120 days of the close of each calendar year or otherwise upon the
reasonable request of the Bank, financial reports in form satisfactory to the Bank, including
without limitation, a current financial statement in form satisfactory to the Bank for the Borrower
and each guarantor(with the financial statement for Borrower being CPA reviewed and due within
120 days of the close of each fiscal year), and within 45 days of filing or otherwise upon the
reasonable request of the Bank, a copy of the most recently filed Federal Income Tax Return for
Borrower and each guarantor; or
(g) The occurrence of an event of default, after any applicable notice and cure period,
under any other loan document provided in connection herewith.
Any deposits or other sums at any time credited by or due from the holder to any maker,
endorser or guarantor of this Note, and any securities or other property of any such maker,endorser
or guarantor at any time in the possession of the holder may at all times be held and treated as
collateral for the payment of this Note and the payment and performance of any and all other
obligations, (direct or indirect, absolute or contingent, sole,joint or several, due or to become due,
now existing or hereafter arising) of any such maker to the holder. Regardless of the adequacy of
collateral, the holder may apply or set off such deposits or other sums against such obligations, at
any time in the case of makers but only with respect to matured obligations in the case of endorsers
and guarantors.
Every maker, endorser or guarantor hereof hereby waives presentment, demand,notice and
protest and all other demands and notices in connection with the delivery, acceptance,
performance, default or enforcement hereof or of any collateral, and assents to any extension or
postponement of the time of payment or other indulgence under this Note or with respect to any
collateral, and to any substitution, exchange or release of collateral, or the discharge of any party
primarily or secondarily liable hereon. No delay or omission on the part of the holder in exercising
any right hereunder shall operate as a waiver of such right or any other right hereunder, and a
waiver of any such right on one occasion shall not be construed as a bar to or waiver of any such
right on any future occasion.
This Note is secured by any and all collateral at any time granted to Bank to secure any
obligations of any maker hereof. In the event this Note is signed by more than one person, all
obligations hereunder shall be joint and several.
The Bank may, without notice to or consent of any person (including without limitation
Borrower or any guarantor), sell, assign, grant a participation in or otherwise dispose of all or any
3
portion of this Note and all other loan documents related thereto. In connection therewith, the
Bank may disclose to a prospective purchaser, assignee, participant or transferee any information
possessed by the Bank relating to this loan and the collateral securing the loan.
Every maker, endorser, and guarantor hereof agrees, jointly and severally, to pay on
demand all costs and expenses (including legal costs and attorneys' fees) incurred or paid by the
holder in enforcing this Note. This Note shall be governed by the laws of the Commonwealth of
Massachusetts,and shall take effect as an instrument under seal.However,when SBA is the holder,
this Note will be interpreted and enforced under federal law, including SBA regulations. Bank or
SBA may use state or local procedures for filing papers recording documents, giving notice,
foreclosing liens, and other purposes. By using such procedures, SBA does not waive any federal
immunity from state of local control, penalty, tax, or liability. As to this Note, Borrower may not
claim or assert against SBA any local or state law to deny any obligation,defeat any claim of SBA,
or preempt federal law.
Masslex LLC
Witness: By:
Name: Anuradha Kapoor
Title: Manager
Witness: By:
Name:
Title:
4
PLEDGE OF ALCOHOLIC BEVERAGE LICENSE AGREEMENT
This AGREEMENT entered into at Boston, Massachusetts, as of , between MASSLEX
LLC, a Massachusetts limited liability company, with an address of 10 Butterfield Road, Lexington, Massachusetts
(the "Pledgor") and Leader Bank, N.A., a national banking association, at the principal office of Bank at 180
Massachusetts Avenue,Arlington,MA 02474(the "Bank").
1. Pledge. In consideration of the Bank's extending credit and other financial accommodations to the Pledgor,
whether evidenced by notes or not,the Pledgor hereby,in accordance with Massachusetts General Laws,Chapter 138,
grants,pledges,assigns and transfers to the Bank a security interest in the alcoholic beverage license more particularly
described as follows: Assignment of Alcoholic Beverage License issued to Group R.Inc. (the "License").
2. Obligations. The security interest granted by this Agreement is given to and shall be held by the Bank as
security for the payment and performance of all Obligations(as hereinafter defined),including without limitation, all
amounts due and owing to the Bank and all obligations respecting(i)that certain Commercial Promissory Note,dated
July ,2019, by MASSLEX LLC, in favor of the Bank in the original principal amount of $306,000.00 (the
"Note"; and collectively, along with all other agreements, documents, certificates and instruments delivered in
connection therewith,the"Loan Documents"),and any substitutions,modifications,extensions or amendments to any
of the Loan Documents. "Obligation(s)" shall mean without limitation all loans, advances, indebtedness, notes,
liabilities and amounts, liquidated or unliquidated, owing by the Pledgor to the Bank at any time, of each and every
kind, nature and description, whether arising under this Agreement, any of the Loan Documents or otherwise, and
whether secured or unsecured,direct or indirect(that is,whether the same are due directly by the Pledgor to the Bank;
or are due indirectly by the Pledgor to the Bank as endorser,guarantor or other surety,or as obligor of obligations due
third persons which have been endorsed or assigned to the Bank, or otherwise), absolute or contingent, due or to
become due, now existing or hereafter contracted. Obligations shall also include all interest and other charges
chargeable to the Pledgor or due from the Pledgor to the Bank from time to time and all costs and expenses referred
to in this Agreement.
3. Representations and Warranties. The Pledgor hereby represents and warrant to the Bank as follows: (i)the
Pledgor has the power and authority to enter into this Agreement; (ii) the License is not subject to any prior lien or
encumbrance, the Pledgor will not transfer, agree to or apply for a transfer or pledge of, or sell the License to any
other individual or entity for so long as any Obligations are outstanding,without the prior written consent of the Bank;
(iii) the Pledgor will pay when due all taxes, charges, liens and assessments against the License and the beverages
authorized to be sold under the License;and the Pledgor will perform any and all acts required to keep the License in
good standing, including filing timely applications of the renewal thereof,and will not suffer or permit the License to
lapse; (iv) the Pledgor shall promptly report in writing to the Bank the occurrence of any event which might impair
the value of the License,including,but not limited to,any action taken by any local or state regulatory agencies which
in any manner restricts the use of the License;and(v)the Pledgor will comply with all applicable laws and regulations
with respect to the License or its use.
4. Further Assurance. The undersigned agrees to do such further acts or execute such further documents as may
be determined necessary by the Bank to perfect the interest granted herein, including executing any application for
approval of the pledge made pursuant to this Agreement.
5. Costs and Expenses. The Pledgor shall pay to the Bank any and all costs and expenses (including, without
limitation, reasonable attorneys' fees, court costs, litigation and other expenses) incurred or paid by the Bank in
establishing, maintaining, protecting or enforcing any of the Bank's rights or the Obligations, including, without
limitation, any and all such costs and expenses incurred or paid by the Bank in defending the Bank's security interest
in,title or right to the License or in collecting or attempting to collect or enforcing or attempting to enforce payment
of any of the Obligations.
6. Default. "Event of Default" shall mean the occurrence of any one or more of the following events: (i)default
of any liability, obligation or undertaking of the Pledgor to the Bank,hereunder or otherwise,including failure to pay
in full and when due any installment of principal or interest or default under any other Loan Document;(ii)failure of
the Pledgor to maintain aggregate collateral security value satisfactory to the Bank; (Ili) default of any material
liability, obligation or undertaking of the Pledgor to any other party; (iv)if any statement,representation or warranty
heretofore,now or hereafter made in connection with this Agreement or in any supporting financial statement of the
Pledgor shall be determined by Bank to have been false in any material respect when made; (v)if the Pledgor or any
guarantor is a corporation, trust, partnership or limited liability company, the liquidation, termination or dissolution
of any such organization,or the merger or consolidation of such organization into another entity,or its ceasing to carry
on actively its present business or the appointment of a receiver for its property; (vi)the death of the Pledgor or of any
guarantor of the Obligations and, if any of the Pledgor or any guarantor of the Obligations is a partnership or limited
liability company, the death of any partner or member; (vii) the institution by or against the Pledgor or guarantor of
the Obligations of any proceedings under the Bankruptcy Code, 11 USC §101 et seq. or any other law in which the
Pledgor or any guarantor of the Obligations is alleged to be insolvent or unable to pay their respective debts as they
mature,or the making by the Pledgor or any guarantor of the Obligations of an assignment for the benefit of creditors
or the granting by the Pledgor or any guarantor of the Obligations of a trust mortgage for the benefit of creditors; (viii)
the service upon the Bank hereof of a writ in which the Bank is named as trustee of the Pledgor or of any guarantor of
the Obligations; (ix) a judgment or judgments for the payment of money shall be rendered against the Pledgor or
guarantor hereof,and any such judgment shall remain unsatisfied and in effect for any period of thirty(30)consecutive
days without a stay of execution; (x) any levy, seizure, attachment, execution or similar process shall be issued or
levied on any of the property of the Pledgor or guarantor hereof,(xi)the termination of any guaranty of the Obligations;
or (xii) the occurrence of such a change in the condition or affairs (financial or otherwise) of the Pledgor or any
guarantor or other surety for any of the Obligations or the occurrence of any event or circumstance such that the Bank,
in its sole discretion, deems that it is insecure or that the prospects for timely or full payment or performance of any
of the Obligations has been or may be impaired.
7. Remedies. If an Event of Default shall occur, at the election of the Bank, all Obligations shall become
immediately due and payable without notice or demand,except with respect to Obligations payable on demand,which
shall be due and payable on demand,whether or not an Event of Default has occurred. The Bank is hereby authorized,
at its election, after an Event of Default or after demand,without any further demand or notice except to such extent
as notice may be required by applicable law,to sell or otherwise dispose of the License at public or private sale; and
the Bank may also exercise any and all other rights and remedies of a secured party under the Massachusetts Uniform
Commercial Code or which are otherwise accorded to it by applicable law, all as the Bank may determine. The
proceeds of any sale or disposition of the License shall be applied towards the Obligations in such order and manner
as the Bank determines in its sole discretion, any statute,custom or usage to the contrary notwithstanding.
8. Waivers. The Pledgor waives notice of nonpayment,demand,presentment,protest or notice of protest of the
Collateral, and all other notices, consents to any renewals or extensions of time of payment thereof, and generally
waives any and all suretyship defenses and defenses in the nature thereof. No delay or omission of the Bank in
exercising or enforcing any of its rights, powers, privileges, remedies, immunities or discretions (all of which are
hereinafter collectively referred to as the "Bank's Rights and Remedies") hereunder or under applicable law shall
constitute a waiver thereof, and no waiver by the Bank of any default of the Pledgor hereunder or of any demand
hereunder shall operate as a waiver of any other default hereunder or any other demand hereunder. No term or
provision hereof shall be waived,altered or modified except with the prior written consent of the Bank,which consent
makes explicit reference to this Agreement. Except as provided in the preceding sentence, no other agreement or
transaction,of whatsoever nature, entered into between the Bank and the Pledgor at any time(whether before,during
or after the effective date or term of this Agreement)shall be construed in any particular way as a waiver,modification
or limitation of any of the Bank's Rights and Remedies under this Agreement(nor shall anything in this Agreement
be construed as a waiver, modification or limitation of any of the Bank's Rights and Remedies under any such other
agreement or transaction)but all the Bank's Rights and Remedies not only under the provisions of this Agreement but
also under any such other agreement or transaction shall be cumulative and not alternative or exclusive, and may be
exercised by the Bank at such time or times and in such order of preference as the Bank in its sole discretion may
determine.
9. Severability. If any provision of this Agreement or portion of such provision or the application thereof to
any person or circumstance shall to any extent be held invalid or unenforceable,the remainder of this Agreement(or
the remainder of such provision) and the application thereof to other persons or circumstances shall not be affected
thereby.
10. Binding Effect of Agreement. This Agreement shall be binding upon and inure to the benefit of the respective
heirs, executors, administrators, legal representatives, successors and assigns of the parties hereto. The Bank may
transfer and assign this Agreement and deliver the Collateral to the assignee, who shall thereupon have all of the
Bank's Rights and Remedies.
11. Notices. Any notices under or pursuant to this Agreement shall be deemed duly received and effective if
delivered in hand to any officer or agent of the Pledgor or Bank, or if mailed by registered or certified mail, return
receipt requested,addressed to the Pledgor or Bank at the address set forth in this Agreement or as any party may from
time to time designate by written notice to the other party.
12. Governing Law. This Agreement is intended to take effect as a sealed instrument and has been executed or
completed and/or is to be performed in Massachusetts,and it and all transactions thereunder or pursuant thereto shall
be governed as to interpretation,validity, effect,rights,duties and remedies of the parties thereunder and in all other
respects by the domestic laws of Massachusetts.
13. Jurisdiction and Venue. Pledgor irrevocably submits to the nonexclusive jurisdiction of any Federal or state
court sitting in Massachusetts,over any suit,action or proceeding arising out of or relating to this Agreement. Pledgor
irrevocably waives, to the fullest extent it may effectively do so under applicable law, any objection it may now or
hereafter have to the laying of the venue of any such suit, action or proceeding brought in any such court and any
claim that the same has been brought in an inconvenient forum. Pledgor irrevocably appoints the Secretary of State
of Massachusetts as its authorized agent to accept and acknowledge on its behalf any and all process which may be
served in any such suit, action or proceeding, consents to such process being served(i)by mailing a copy thereof by
registered or certified mail, postage prepaid, return receipt requested, to Pledgor's address shown in this Agreement
or as notified to the Bank and (ii) by serving the same upon such agent, and agrees that such service shall in every
respect be deemed effective service upon Pledgor.
14. JURY WAIVER. THE PLEDGOR AND BANK EACH HEREBY KNOWINGLY,VOLUNTARILY AND
INTENTIONALLY, AND AFTER AN OPPORTUNITY TO CONSULT WITH LEGAL COUNSEL, (A) WAIVE
ANY AND ALL RIGHTS TO A TRIAL BY JURY IN ANY ACTION OR PROCEEDING IN CONNECTION WITH
THIS AGREEMENT,THE OBLIGATIONS,ALL MATTERS CONTEMPLATED HEREBY AND DOCUMENTS
EXECUTED IN CONNECTION HEREWITH AND(B)AGREE NOT TO CONSOLIDATE ANY SUCH ACTION
WITH ANY OTHER ACTION IN WHICH A JURY TRIAL CAN NOT BE,OR HAS NOT BEEN WAIVED. THE
PLEDGOR CERTIFIES THAT NEITHER THE BANK NOR ANY OF ITS REPRESENTATIVES, AGENTS OR
COUNSEL HAS REPRESENTED, EXPRESSLY OR OTHERWISE, THAT THE BANK WOULD NOT IN THE
EVENT OF ANY SUCH PROCEEDING SEEK TO ENFORCE THIS WAIVER OF RIGHT TO TRIAL BY JURY.
Executed under seal and dated July ,2019.
Witness MASSLEX LLC
Witness: By:
Anuradha Kapoor,Manager
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Entertainment License Renewal - Bertucci's Restaurant Corporation, 1777 Massachusetts
Avenue
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
I.13
SUMMARY:
Bertucci's Restaurant Corporation, 1777 Massachusetts Avenue has applied for the renewal of their
Entertainment License for 2019 to provide live ac o us tic music (guitar/keyboard) as background music for
diners in the outdoor seating area. The music is for the enjoyment of the dining patrons with no cover charge.
The original lic ens e was approved for B ertuc c i's for 2017 and renewed for 2018.
SUGGESTED MOTION:
Motion to approve an Entertainment License to Bertucci's Restaurant Corporation, 1777 Massachusetts
Avenue, for the purpose of providing live ac o us tic music in the outdoor seating area Thursday- Saturday from
6:00 p.m. to 9:30 p.m.
FOLLOW-UP:
Selectmen's O ffic e
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:50 p.m.
ATTACHMENTS:
Description Type
2019
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TOWN CIF LEXINGTON
SELECTMEN'S
a
APRIL 1Qt«
tINOT��
APPLICATION FOR
ENTERTAINMENT LICENSE
The Board of Selectmen issues Entertainment licenses to establishments that have theatrical
exhibitions,public shows, public amusements and exhibitions of every description(including
televisions). Please fill in this form completely and return to the Selectmen's Office along with a
check for$5.00 made payable to the Town of Lexington.
CORPORATE NAME: 6ew4vccis
D/B/A: 6e44j cc-#�5
ON-SITE MANAGER.NAME AND PHONE 1' UMBER,:
BUSINESS ADDDR.ESS:
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EMAIL .ADDRESS:
TYPE OF ENTERTAINMENT: bve-
V
ADDITIONAL INFORMATION:
.^�www�.+.w, wwww.v.y.rr ...w............,,......,,...,»,..wwa...:..ter,.w....,.. .,.:,...,»
A h ze Signature Federal Identification No. or
Social Security Number
Submit to Selectmen's Office:
1. Application
2. Check for$5.00 (payable to Town of Lexington)
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Limousine License Application- D&O Limo LLC
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
I.14
SUMMARY:
D&O Limo, LLC has requested a new Limousine License and has provided the necessary paperwork. A CORI
check was performed and the applicant has received a favorable Inspection Report on the livery vehicle from the
Police Department. The license will expire on May 1, 2020.
SUGGESTED MOTION:
Move to approve the limousine application and issue one(1) Limousine License to D&O Limo, 3402 Main
Campus Drive.
FOLLOW-UP:
Selectmen's O ffic e
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 8:55 p.m.
ATTACHMENTS:
Description Type
......
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CIF u1 ' .�TO►l'Tid, AM ( rr
SELECTMEN'SOWN OFFICE �
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J�J N 2 0 2019
8,/A� I
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The Board of Selectmen issues Limousine Licenses for carrying of passengers for hire. Please fill
in this form completely and return to the Selectmen's Office along all of the required items listed
below. If you have any questions please contact the Selectmen's Office at 781-862-050Ox208 or
email selectmen@lexingtorana.gov.
CORPORATE NAME: ►
D/B/A: -t, t ��
ON-SITE MANAGER.NAME AND PHONE NUMBER:
BUSINESS ADDDRESS: M' C...A, .. ..� � �. ,r
EMAIL ADDDRES S
NUMBED. OF VEHICLES:
INFORMATION ON EACH VEHICLE (Year, Make, VI No. and Plate No.):
a I-ItIt 10�m**44 5 41 Zia A=1 f4o 4"=.I J..�
ROUTES: � ►s-�c. .�.a --� ' �►u..P.. , ._. .,�... . �,�-�r -t.�►.�-�►
(D
Authorized Signature Federal Identification No. or
Social Security Number
Submit to Selectmen's Office:
1. Application
2. Check for$30.00 per vehicle (payable to Town of Lexington)
3. Workers' Compensation Insurance Affidavit (incl. copy of Declaration pg. of policy)
4. Proof that vehicle(s)has been registered and inspected by Registry of Motor Vehicle
5. Completed CORI form and drivers license or other government photo identification
6. Inspection Report from Lexington Police Mechanic (contact William Ahern at 781-862-
1212 to make an appointment for the inspection).
Tuesday,June 25, 2019
Livery cab inspection
Bayer,Nevzat Ozden
3402 Main Campus Dr
Lexington Ma 02421
The following vehicle passes a basic vehicle inspection and has a current Mass State
Inspection sticker
VEH#1 ma reg# LV81715
VIN#WBA5A7C511ED619318
2014 BMW
Passes basic inspection and has currant mass state inspection sticker.
Police Mechanic
William F.Ahern
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Selectmen Committee Appointments & Resignation
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
I.15
SUMMARY:
Resignation:
The Board is being asked to accept the resignation of Jennifer Melot from the Lexington Bicycle Advisory
Committee. The Board extends its thanks and appreciation to M s. Melot for her time and effort in serving the
Lexington Community.
App o intments:
The Board is being asked to appoint Dr. Holly Sweet as a member of the Noise Advisory Committee with a
term expiration date of September 30, 2021.
The Board is being asked to appoint Paul C hernic k as a member of the Sustainable Lexington Committee with
a term expiration date of September 30, 2019.
The Board is being asked to appoint Matthias Beebe as a member of the Lexington Bicycle Advisory
Committee to fill the unexpired term of Jennifer Melot with a term expiration of September 30, 2020.
SUGGESTED MOTION:
Move to accept the resignation of Jennifer Melot from the Lexington Bicycle Advisory Committee effective
immediately.
Move to appoint Dr. Holly Sweet to the Noise Advisory Committee with a term expiration date of September
30, 2021.
Move to appoint Paul C hernic k to the Sustainable Lexington Committee with a term expiration date of
September 30, 2019.
Move to appoint Matthias Beebe to the Lexington Bicycle Advisory Committee with a term expiration date of
September 30, 2020.
FOLLOW-UP:
Selectmen's Office
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 9:00 P.M.
ATTACHMENTS:
Description Type
D 201191 i-,xington.Bicycle Advisoiy(A,�)rnavttee J.Mlelot 1.3-ackup Material
D 2019 Noise Advisory Cmiunittee Application........I I.Sweet 13),ackup VIlaterial.
D 20119 Stistainable I exington.(I.nnt-nittee Application........R(..'hernick I kackup Material
M
icycle Ii cc.1 C Backup N11.atetial D 20191 c-xingto-n.I l Advisory Cbn,i,ttee Application MI 1.3—1.)
From:Jennifer Melot
Sent: Sunday, June 23, 2019 9:20 PM
To: Kim Katzenback
Cc: Peggy Enders
Subject: resignation from Lexington Bicycle Advisory Committee
Hello,
I'm writing to resign from the Lexington Bicycle Advisory Committee as I've moved out of
state. It was a pleasure to serve on the committee. My best wishes to Lexington!
Jennifer
i
Al
7 1
1� J LJ N 0 `7 2 019N,
u
APPLICATION FOR APPOINTMENT
FOR.BOARD/COMMITTEE MEMBERSHIP
• �
Board/Committee of Interest: l.I` oiseCommItt e 2.
3. 4.
Would you consider another Committee: Not at this time
For how long should we keep your application on file? Indefinitely
Full Name.
Holly .
Barlow Sweet •
Nickname.• Dr.
Preferred Tale(please circle) Mr./%./Mrs./Other.
5 Crescent Raga 02421
Home Address: Zip:
• since June 2010
Length of Residence Lex:�ngton..
Psycholo'-p-ist (semi retired)
P
Occu ation:
1415 Beacon Streette�ui 303 Brookline MA
W orb.Address. � �
Phone: Home work Fax
Cell
E-mail: Primary: Secondary:
If you currently serve on a Board or Committee,please identify:
Special Training, Interests, Qualifications: Past
President of Division 51(Psych of Men)of American Psych Assn,see more info on resume
•
Have y y you been asked b a Committee to become a member? yes Loa Minardi
�
• fire Next DoorHow did ou hear about the Committee?
Please attach a current resume, if possible. Add any comments below or on a separate page.
SIg11at[,lx'e: Late:
Holly Barlow Sweet Ph.D.
Licensed Psychologist
1415 Beacon Street Suite 303
Brookline MA 02446
Education
1995 Ph.D. Counseling Psychology
Boston College, Chestnut Hill, MA
Thesis: Perceptions of undergraduate male experiences in heterosexua I romantic
relationships: A sex role norms analysis
1975 MId. Counseling
Northeastern University, Boston MA
1971 B.A. Honours Degree,Sociology
University of Sussex, Falmer, England
Professional Experience
2000-present Psychologist in Independent Practice
Brookline MA
-conduct individual psychotherapy with clients with anxiety, depression,, PTSQ,
OCD, and gender and relationship issues.
1995-present Co-Founder and Co-Director
Cambridge Center for Gender Relations
Cambridge MA
—run workshops and training for universities and businesses to improve personal
and professional relationships between and women, utilizing an experiential
approach which focuses on increasing gender empathy and understanding.
2017 President, Division 51(Psychological Study of Men and Masculinities)
American Psychological Association
Washington DC
1997-1999 Co-Founder and Co-Director
GenderWorks
Massachusetts Institute of Technology
fl
flY
Cambridge MA
-developed and supervised a peer training program for improving gender
relations
1979-2014 Lecturer(part-time)
Experimental Study Group
Massachusetts Institute of Technology
Cambridge MA
-developed and taught undergraduate seminars, including Sex Roles and
Relationships,. Gender and Science,Sex Roles and Androgyny, Psychology in
Action,Three Approaches to Psychology, Psychology Looks at the First Year,
Composing a Life: Self-Exploration through Photography,Art and Writing,
Psychology of Hope and Fear, Psychology of Emerging Adulthood, and The Art
and Science of Happiness.
1977-2015 Associate Director(part-time beginning in 1986)
Experimental Study Group
Massachusetts Institute of Technology
Cambridge MA 02139
Responsible for all administrative operations of an alternative freshman learning
community at MIT, including fund-raising, budget development, alumni outreach
,organizing and running committees at ESG, overseeing student academic and
social progress, and primary administrative contact with other relevant
departments at MIT., including the School of Science and the Office of
Undergraduate Education
Publications
2012 Gender in the therapy tour: Voices of female clinicians working with men (H.
Sweet, Editor), Routledge: New York.
2010 Women counseling men (H. Sweet), article in Psychotherapy Networker,
April/May issue
2009 A creative guide to exploring your life: Self-reflection using photography, art
and writing(G. Ramsay& H. Sweet),,Jessica Kingsley Publishers: Philadelphia
2005 Finding the person behind the persona: Engaging men as a female therapist (H.
Sweet), In the room with men: A casebook of therapeutic change(M. Carlson-
Englar& M. Stevens, Editors)APA Publications: Washington DC.
2000 A feminist looks at the men's movement: The search for common ground (H.
Sweet) in Mythopoetic perspectives of men's healing work: An anthology for
therapists and others. (E. Barton,, Editor), Bergin and Garvey: Westport CT.
41
Continuing Education Programs
2018 Men as allies in combatting sexual harassment: Positive and collaborative
approaches in training. Rutgers Graduate School of Applied and Professional
Psychology, New Brunswick NJ.
2013,. 2014 Women counseling men: Practicing male-friendly therapy, American
Psychological Association convention., Honolulu HI and Washington DC.
2006 Encountering gender in relationships and therapy: An experiential case study
approach. Wyoming Psychological Association, Cheyenne WY.
2006 Silent men,,angry women: Exploring how therapists can address common
gender issues in relationships, British Columbia Psychological Association,
Vancouver, Canada.
2004 Mad or sad: Understanding and treating depression in boys and men.
Massachusetts Psychological Association, Lexington MA.
2003 Treating infidelity in couples. Harvard Medical School, Boston MA.
Awards
2010 Infinite Mile Award Dean for Undergraduate Education (given to employees who
have gone above and beyond their role at MIT)
2005 Practitioner of the Year, Division 51 (Psychological Study of Men and
Masculinities), American Psychological Association
1997 MIT Sizer Award: the most significant contribution to undergraduate education
for seminar on "Sex Roles and Relationships"
Affiliations
Massachusetts Psychological Association
American Psychological Association
APPLICATION FOR APPOINTMENT
FOR BOARD/COMMITTEE MEMBERSHIP
Board/Committee of Interest: 1.Sustainable Lexington 2
3. 4.
Would you consider another Committee:
For how long should we keep your application on file?
Full Name: Paul Chernick Nickname:
Preferred Title (please circle)��VMs./Nlrs./Other:
Home Address: 14 Somerset Rd Zip: 02420
Length of Residence in Lexington: 37 years
Occupation: Consultant in utility planning and regulation
Work Address: Resource Insight, 5 Water St., Arlington MA 02476
Phone: Home Work Fax
Cell
E-mail: Primary: Secondary:
If you currently serve on a Board or Committee, please identify: nOCI@ aCtIVG
Special Training, Interests, Qualifications: utility planning and regulation
Have you been asked by a Committee to become a member? Yes
How did you hear about the Committee? Through the former Energy Conservation Committee
Please attach a current resume, if possible. Add any comments below or on a separate page.
� 6/10/2019
Signature: Date:
PAUL L. CHERNICK
Resource Insight, Inc.
5 Water Street
Arlington, Massachusetts 02476
SUMMARY OF PROFESSIONAL EXPERIENCE
1986— President, Resource Insight,Inc. Consults and testifies in utility and insurance
Present economics. Reviews utility supply-planning processes and outcomes: assesses
prudence of prior power planning investment decisions,identifies excess generat-
ing capacity, analyzes effects of power-pool-pricing rules on equity and utility
incentives. Reviews electric-utility rate design. Estimates magnitude and cost of
future load growth. Designs and evaluates conservation programs for electric,
natural-gas, and water utilities, including hook-up charges and conservation cost
recovery mechanisms. Determines avoided costs due to cogenerators. Evaluates
cogeneration rate risk. Negotiates cogeneration contracts. Reviews management
and pricing of district heating systems. Determines fair profit margins for auto-
mobile and workers' compensation insurance lines,incorporating reward for risk,
return on investments, and tax effects. Determines profitability of transportation
services. Advises regulatory commissions in least-cost planning,rate design, and
cost allocation.
1981-86 Research Associate, Analysis and Inference, Inc. (Consultant, 1980-81).
Researched,advised,and testified in various aspects of utility and insurance regu-
lation. Designed self-insurance pool for nuclear decommissioning; estimated
probability and cost of insurable events, and rate levels; assessed alternative rate
designs. Projected nuclear power plant construction, operation, and decommis-
sioning costs.Assessed reasonableness of earlier estimates of nuclear power plant
construction schedules and costs. Reviewed prudence of utility construction
decisions. Consulted on utility rate-design issues,including small-power-producer
rates; retail natural-gas rates; public-agency electric rates, and comprehensive
electric-rate design for a regional power agency. Developed electricity cost
allocations between customer classes.Reviewed district-heating-system efficiency.
Proposed power-plant performance standards. Analyzed auto-insurance profit
requirements. Designed utility-financed, decentralized conservation program.
Analyzed cost-effectiveness of transmission lines.
1977-81 Utility Rate Analyst,Massachusetts Attorney General.Analyzed utility filings
and prepared alternative proposals. Participated in rate negotiations, discovery,
cross-examination, and briefing. Provided extensive expert testimony before
various regulatory agencies. Topics included demand forecasting, rate design,
marginal costs,time-of-use rates,reliability issues,power-pool operations,nuclear-
power cost projections, power-plant cost-benefit analysis, energy conservation,
and alternative-energy development.
SM,Technology and Policy Program,Massachusetts Institute of Technology,February 1978.
SB, Civil Engineering Department, Massachusetts Institute of Technology, June 1974.
067MOTE'RE on
Chi Epsilon (Civil Engineering)
Tau Beta Pi (Engineering)
Sigma Xi (Research)
Institute Award, Institute of Public Utilities, 1981.
PUBLICATIONS
"Price Effects as a Benefit of Energy-Efficiency Programs" (with John Plunkett), 2014
ACEEE Summer Study on Energy Efficiency in Buildings (5) 57-5-69. 2014.
"Environmental Regulation in the Changing Electric-Utility Industry" (with Rachel
Brailove), International Association for Energy Economics Seventeenth Annual North
American Conference (96-105). Cleveland, Ohio: USAEE. 1996.
"The Price is Right: Restructuring Gain from Market Valuation of Utility Generating Assets"
(with Jonathan Wallach), International Association for Energy Economics Seventeenth
Annual North American Conference (345-352). Cleveland, Ohio: USAEE. 1996.
"The Future of Utility Resource Planning: Delivering Energy Efficiency through Distributed
Utilities" (with Jonathan Wallach), International Association for Energy Economics
Seventeenth Annual North American Conference(460-469). Cleveland,Ohio:USAEE. 1996.
"The Future of Utility Resource Planning:Delivering Energy Efficiency through Distribution
Utilities" (with Jonathan Wallach), 1996 Summer Study on Energy Efficiency in Buildings,
Washington: American Council for an Energy-Efficient Economy 7(7.47-7.55). 1996.
"The Allocation of DSM Costs to Rate Classes," Proceedings of the Fifth National
Conference on Integrated Resource Planning. Washington: National Association of
Regulatory Utility Commissioners. May 1994.
"Environmental Externalities: Highways and Byways" (with Bruce Biewald and William
Steinhurst),Proceedings of the Fifth National Conference on Integrated Resource Planning.
Washington: National Association of Regulatory Utility Commissioners. May 1994.
"The Transfer Loss is All Transfer, No Loss" (with Jonathan Wallach), The Electricity
Journal 6:6 (July 1993).
"Benefit-Cost Ratios Ignore Interclass Equity"(with others),DSM Quarterly, Spring 1992.
"ESCos or Utility Programs: Which Are More Likely to Succeed?" (with Sabrina Birner),
The Electricity Journal 5:2, March 1992.
Paul L. Chernick• Resource Insight, Incorporated Page 2
"Determining the Marginal Value of Greenhouse Gas Emissions" (with Jill Schoenberg),
Energy Developments in the 1990s: Challenges Facing Global/PacificMarkets, Vol.II,July
1991.
"Monetizing Environmental Externalities for Inclusion in Demand-Side Management
Programs"(with Emily Caverhill),Proceedings from the Demand-Side Management and the
Global Environment Conference,April 1991.
"Accounting for Externalities" (with Emily Caverhill). Public Utilities Fortnightly 127(5),
March 1 1991.
"Methods of Valuing Environmental Externalities" (with Emily Caverhill), The Electricity
Journal 4(2), March 1991.
"The Valuation of Environmental Externalities in Energy Conservation Planning" (with
Emily Caverhill), Energy Efficiency and the Environment: Forging the Link. American
Council for an Energy-Efficient Economy; Washington: 1991.
"The Valuation of Environmental Externalities in Utility Regulation"(with Emily Caverhill),
External Environmental Costs of Electric Power: Analysis and Internalization. Springer-
Verlag; Berlin: 1991.
"Analysis of Residential Fuel Switching as an Electric Conservation Option" (with Eric
Espenhorst and Ian Goodman), Gas Energy Review, December 1990.
"Externalities and Your Electric Bill," The Electricity Journal, October 1990, p. 64.
"Monetizing Externalities in Utility Regulations: The Role of Control Costs" (with Emily
Caverhill) Proceedings from the NAR UC National Conference on Environmental
Externalities, October 1990.
"Monetizing Environmental Externalities in Utility Planning" (with Emily Caverhill), in
Proceedings from the NAR UC Biennial Regulatory Information Conference, September
1990.
"Analysis of Residential Fuel Switching as an Electric Conservation Option" (with Eric
Espenhorst and Ian Goodman), in Proceedings from the NAR UC Biennial Regulatory
Information Conference, September 1990.
"A Utility Planner's Checklist for Least-Cost Efficiency Investment"(with John Plunkett)in
Proceedings from the NAR UC Biennial Regulatory Information Conference, September
1990.
Environmental Costs of Electricity(with Richard Ottinger et al.). Oceana;Dobbs Ferry,New
York: September 1990.
"Demand-Side Bidding: A Viable Least-Cost Resource Strategy" (with John Plunkett and
Jonathan Wallach), in Proceedings from the NAR UC Biennial Regulatory Information
Conference, September 1990.
Paul L. Chernick• Resource Insight, Incorporated Page 3
"Incorporating Environmental Externalities in Evaluation of District Heating Options"(with
Emily Caverhill), Proceedings from the International District Heating and Cooling
Association 81stAnnual Conference, June 1990.
"A Utility Planner's Checklist for Least-Cost Efficiency Investment,"(with John Plunkett),
Proceedings from the Canadian Electrical Association Demand-Side Management
Conference, June 1990.
"Incorporating Environmental Externalities in Utility Planning" (with Emily Caverhill),
Canadian Electrical Association Demand Side Management Conference, May 1990.
"Is Least-Cost Planning for Gas Utilities the Same as Least-Cost Planning for Electric
Utilities?" in Proceedings of the NAR UC Second Annual Conference on Least-Cost
Planning, September 10-13 1989.
"Conservation and Cost-Benefit Issues Involved in Least-Cost Planning for Gas Utilities,"in
Least Cost Planning and Gas Utilities: Balancing Theories with Realities, Seminar
proceedings from the District of Columbia Natural Gas Seminar, May 23 1989.
"The Role of Revenue Losses in Evaluating Demand-Side Resources: An Economic Re-
Appraisal" (with John Plunkett), Summer Study on Energy Efficiency in Buildings, 1988,
American Council for an Energy Efficient Economy, 1988.
"Quantifying the Economic Benefits of Risk Reduction: Solar Energy Supply Versus Fossil
Fuels," in Proceedings of the 1988 Annual Meeting of the American Solar Energy Society,
American Solar Energy Society, Inc., 1988, pp. 553-557.
"Capital Minimization: Salvation or Suicide?," in I. C. Bupp, ed., The New Electric Power
Business, Cambridge Energy Research Associates, 1987, pp. 63-72.
"The Relevance of Regulatory Review of Utility Planning Prudence in Major Power Supply
Decisions," in Current Issues Challenging the Regulatory Process, Center for Public
Utilities,Albuquerque,New Mexico,April 1987, pp. 36-42.
"Power Plant Phase-In Methodologies: Alternatives to Rate Shock," in Proceedings of the
Fifth NAR UC Biennial Regulatory Information Conference,National Regulatory Research
Institute, Columbus, Ohio, September 1986, pp. 547-562.
"Assessing Conservation Program Cost-Effectiveness:Participants,Non-participants,and the
Utility System" (with A. Bachman),Proceedings of the Fifth NAR UC Biennial Regulatory
Information Conference, National Regulatory Research Institute, Columbus, Ohio,
September 1986, pp. 2093-2110.
"Forensic Economics and Statistics: An Introduction to the Current State of the Art" (with
Eden, P., Fairley, W.,Alter, C., Vencill, C., and Meyer, M.), The Practical Lawyer, June 1
1985, pp. 25-36.
"Power Plant Performance Standards: Some Introductory Principles," Public Utilities
Fortnightly,April 18 1985, pp. 29-33.
Paul L. Chernick• Resource Insight, Incorporated Page 4
"Opening the Utility Market to Conservation:A Competitive Approach,"Energy Industries in
Transition, 1985-2000, Proceedings of the Sixth Annual North American Meeting of the
International Association of Energy Economists, San Francisco,California,November 1984,
pp. 1133-1145.
"Insurance Market Assessment of Technological Risks" (with Meyer, M., and Fairley, W)
Risk Analysis in the Private Sector, pp. 401-416, Plenum Press, New York 1985.
"Revenue Stability Target Ratemaking,"Public Utilities Fortnightly,February 17 1983,pp.
35-39.
"Capacity/Energy Classifications and Allocations for Generation and Transmission Plant"
(with M. Meyer),Award Papers in Public Utility Economics and Regulation, Institute for
Public Utilities, Michigan State University 1982.
Design, Costs and Acceptability of an Electric Utility Self-Insurance Pool for Assuring the
Adequacy of Funds for Nuclear Power Plant Decommissioning Expense, (with Fairley,W.,
Meyer, M., and Scharff, L.) (NUREG/CR-2370), U.S. Nuclear Regulatory Commission,
December 1981.
Optimal Pricing for Peak Loads and Joint Production: Theory and Applications to Diverse
Conditions (Report 77-1), Technology and Policy Program, Massachusetts Institute of
Technology, September 1977.
MTRZOMTO
"Review of NS Power Compliance Filing on its Proposed AMI Opt-Out Charge" (with
Benjamin Griffiths). October 26,2018.Filed by the Nova Scotia Consumer Advocate in N.S.
UARB Matter No. M08349.
"Avoided Energy Supply Costs in New England: 2018 Report" (with Pat Knight, Max
Chang,David White,Benjamin Griffiths,Les Deman,John Rosenkranz,Jason Gifford, and
others). March 30, 2018. Cambridge, Mass.: Synapse Energy Economics.
"Review of the NS Power Application for Approval of its 2017 Annually Adjusted Rates and
Load Following Setting Methodology"(with Stacia Harper).August 2017.Filed by the Nova
Scotia Consumer Advocate in N.S. UARB Matter No. M08114.
"Charge Without a Cause?Assessing Electric Utility Demand Charges on Small Consumers"
(with John T. Colgan,Rick Gilliam,Douglas Jester and Mark LeBel).Electricity Rate Design
Review No. 1, July 2016.
"Implications of the Proposed Clean Power Plan for Arkansas: Review of Stakeholder Con-
cerns and Assessment of Feasibility."2014. Report to Arkansas Audubon,Arkansas Public
Policy Panel, and Arkansas Sierra Club.
"Comments on Nova Scotia Power Inc.'s Proposed Capital Expenditure Justification
Criteria." 2013. Filed by the Nova Scotia Consumer Advocate in N.S. UARB Matter No.
05355.
Paul L. Chernick• Resource Insight, Incorporated Page 5
"Avoided Energy Supply Costs in New England: 2013 Report" (with Rick Hornby, David
White,John Rosenkranz,Ron Denhardt,Elizabeth Stanton,Jason Gifford,Bob Grace,Max
Chang,Patrick Luckow,Thomas Vitolo,Patrick Knight,Ben Griffiths,and Bruce Biewald).
2013.Northborough,Mass.:Avoided-Energy-Supply-Component Study Group,c/o National
Grid Company.
"Affordability of Pollution Control on the Apache Coal Units: Review of Arizona Electric
Power Cooperative's Comments on Behalf of the Sierra Club" (with Ben Griffiths). 2012.
Filed as part of comments in Docket EPA-R09-OAR-2012-0021 by National Parks Conserva-
tion Association, Sierra Club, et al.
"Audubon Arkansas Comments on Entergy's 2012 IRP." 2012. Prepared for and filed by
Audubon Arkansas in Arkansas PUC Docket No. 07-016-U.
"Economic Benefits from Early Retirement of Reid Gardner"(with Jonathan Wallach).2012.
Prepared for and filed by the Sierra Club in PUC of Nevada Docket No. 11-08019.
"Analysis of Via Verde Need and Economics."2012.Appendix V 4 of public comments of
the Sierra Club et al. in response to November 30 2011 draft of U.S. Army Corps of
Engineers environmental assessment in Department of the Army Environmental Assessment
and Statement of Finding for Permit Application SAJ-2010-02881.
"Comments for The Alliance for Affordable Energy on Staff s `Proposed Integrated Resource
Planning Rules for Electric Utilities in Louisiana."' 2011. Filed by the Alliance for
Affordable Energy in Louisiana PSC Docket R-30021.
"Avoided Energy Supply Costs in New England: 2011 Report" (with Rick Hornby, Carl
Swanson, David White, Jason Gifford, Max Chang, Nicole Hughes, Matthew Wittenstein,
Rachel Wilson,and Bruce Biewald).2011.Northborough,Mass.:Avoided-Energy-Supply-
Component Study Group, c/o National Grid Company.
"State of Ohio Energy-Efficiency Technical-Reference Manual Including Predetermined
Savings Values and Protocols for Determining Energy and Demand Savings"(with others).
2010. Burlington, Vt.: Vermont Energy Investment Corporation.
"Avoided Energy Supply Costs in New England: 2011 Report" (with Rick Hornby, Carl
Swanson, David White, Ian Goodman, Bob Grace, Bruce Biewald, Ben Warfield, Jason
Gifford,and Max Chang).2009.Northborough,Mass.:Avoided-Energy-Supply-Component
Study Group, c/o National Grid Company.
"Green Resource Portfolios: Development, Integration, and Evaluation" (with Jonathan
Wallach and Richard Mazzini). 2008. Report to the Green Energy Coalition presented as
evidence in Ont. Energy Board EB 2007-0707.
"Risk Analysis of Procurement Strategies for Residential Standard Offer Service" (with
Jonathan Wallach, David White, and Rick Hornby) report to Maryland Office of People's
Counsel. 2008. Baltimore: Maryland Office of People's Counsel.
"Avoided Energy Supply Costs in New England: 2007 Final Report" (with Rick Hornby,
Carl Swanson, Michael Drunsic, David White, Bruce Biewald, and Jenifer Callay). 2007.
Paul L. Chernick• Resource Insight, Incorporated Page 6
Northborough,Mass.:Avoided-Energy-Supply-Component Study Group,c/o National Grid
Company.
"Integrated Portfolio Management in a Restructured Supply Market"(with Jonathan Wallach,
William Steinhurst, Tim Woolf, Anna Sommers, and Kenji Takahashi). 2006. Columbus,
Ohio: Office of the Ohio Consumers' Counsel.
"Natural Gas Efficiency Resource Development Potential in New York" (with Phillip
Mosenthal, R. Neal Elliott, Dan York, Chris Neme, and Kevin Petak). 2006.Albany, N.Y.;
New York State Energy Research and Development Authority.
"Natural Gas Efficiency Resource Development Potential in Con Edison Service Territory"
(with Phillip Mosenthal, Jonathan Kleinman, R. Neal Elliott, Dan York, Chris Neme, and
Kevin Petak. 2006. Albany, N.Y.; New York State Energy Research and Development
Authority.
"Evaluation and Cost Effectiveness" (principal author), Ch. 14 of"California Evaluation
Framework" Prepared for California utilities as required by the California Public Utilities
Commission. 2004.
"Energy Plan for the City of New York"(with Jonathan Wallach, Susan Geller,Brian Tracey,
Adam Auster, and Peter Lanzalotta). 2003. New York: New York City Economic Develop-
ment Corporation.
"Updated Avoided Energy Supply Costs for Demand-Side Screening in New England"(with
Susan Geller, Bruce Biewald, and David White). 2001. Northborough, Mass.: Avoided-
Energy-Supply-Component Study Group, c/o New England Power Supply Company.
"Review and Critique of the Western Division Load-Pocket Study of Orange and Rockland
Utilities, Inc." (with John Plunkett, Philip Mosenthal, Robert Wichert, and Robert Rose).
1999.White Plains,N.Y.: Pace University School of Law Center for Environmental Studies.
"Avoided Energy Supply Costs for Demand-Side Management in Massachusetts" (with
Rachel Brailove, Susan Geller, Bruce Biewald, and David White). 1999. Northborough,
Mass.:Avoided-Energy-Supply-Component Study Group, c/o New England Power Supply
Company.
"Performance-based Regulation in a Restructured Utility Industry"(with Bruce Biewald,Tim
Woolf,Peter Bradford, Susan Geller,and Jerrold Oppenheim). 1997.Washington:NARUC.
"Distributed Integrated-Resource-Planning Guidelines." 1997.Appendix 4 of"The Power to
Save:A Plan to Transform Vermont's Energy-Efficiency Markets,"submitted to the Vt.PSB
in Docket No. 5854. Montpelier: Vermont DPS.
"Restructuring the Electric Utilities of Maryland: Protecting and Advancing Consumer
Interests" (with Jonathan Wallach, Susan Geller, John Plunkett, Roger Colton, Peter
Bradford,Bruce Biewald,and David Wise). 1997.Baltimore,Maryland: Maryland Office of
People's Counsel.
Paul L. Chernick• Resource Insight, Incorporated Page 7
"Comments of the New Hampshire Office of Consumer Advocate on Restructuring New
Hampshire's Electric-Utility Industry" (with Bruce Biewald and Jonathan Wallach). 1996.
Concord,N.H.: NH OCA.
"Estimation of Market Value, Stranded Investment, and Restructuring Gains for Major
Massachusetts Utilities"(with Susan Geller,Rachel Brailove,Jonathan Wallach,and Adam
Auster). 1996. On behalf of the Massachusetts Attorney General (Boston).
From Here to Efficiency: Securing Demand-Management Resources(with Emily Caverhill,
James Peters, John Plunkett, and Jonathan Wallach). 1993. 5 vols. Harrisburg, Penn:
Pennsylvania Energy Office.
"Analysis Findings, Conclusions, and Recommendations," vol. 1 of "Correcting the
Imbalance of Power: Report on Integrated Resource Planning for Ontario Hydro" (with
Plunkett, John, and Jonathan Wallach), December 1992.
"Estimation of the Costs Avoided by Potential Demand-Management Activities of Ontario
Hydro,"December 1992.
"Review of the Elizabethtown Gas Company's 1992 DSM Plan and the Demand-Side
Management Rules" (with Jonathan Wallach, John Plunkett, James Peters, Susan Geller,
Blair.Hamilton,and Andrew Shapiro). 1992.Report to the New Jersey Department of Public
Advocate.
Environmental Externalities Valuation and Ontario Hydros Resource Planning (with E.
Caverhill and R.Brailove),3 vols.;prepared for the Coalition of Environmental Groups for a
Sustainable Energy Future, October 1992.
"Review of Jersey Central Power & Light's 1992 DSM Plan and the Demand-Side
Management Rules"(with Jonathan Wallach et al.);Report to the New Jersey Department of
Public Advocate, June 1992.
"The AGREA Project Critique of Externality Valuation:A Brief Rebuttal," March 1992.
"The Potential Economic Benefits of Regulatory NOx Valuation for Clean Air Act Ozone
Compliance in Massachusetts,"March 1992.
"Initial Review of Ontario Hydro's Demand-Supply Plan Update"(with David Argue et al.),
February 1992.
"Report on the Adequacy of Ontario Hydro's Estimates of Externality Costs Associated with
Electricity Exports" (with Emily Caverhill), January 1991.
"Comments on the 1991-1992 Annual and Long Range Demand-Side-Management Plans of
the Major Electric Utilities,"(with John Plunkett et al.), September 1990. Filed in NY PSC
Case No. 28223 in re New York utilities' DSM plans.
"Power by Efficiency:An Assessment of Improving Electrical Efficiency to Meet Jamaica's
Power Needs," (with Conservation Law Foundation, et al.), June 1990.
Paul L. Chernick• Resource Insight, Incorporated Page 8
"Analysis of Fuel Substitution as an Electric Conservation Option,"(with Ian Goodman and
Eric Espenhorst), Boston Gas Company, December 22 1989.
"The Development of Consistent Estimates of Avoided Costs for Boston Gas Company,
Boston Edison Company, and Massachusetts Electric Company" (with Eric Espenhorst),
Boston Gas Company, December 22 1989.
"The Valuation of Externalities from Energy Production, Delivery, and Use: Fall 1989
Update" (with Emily Caverhill), Boston Gas Company, December 22 1989.
"Conservation Potential in the State of Minnesota," (with Ian Goodman) Minnesota
Department of Public Service, June 16 1988.
"Review of NEPOOL Performance Incentive Program," Massachusetts Energy Facilities
Siting Council,April 12 1988.
"Application of the DPU's Used-and-Useful Standard to Pilgrim 1" (With C. Wills and M.
Meyer), Massachusetts Executive Office of Energy Resources, October 1987.
"Constructing a Supply Curve for Conservation: An Initial Examination of Issues and
Methods,"Massachusetts Energy Facilities Siting Council, June 1985.
"Final Report: Rate Design Analysis,"Pacific Northwest Electric Power and Conservation
Planning Council, December 18 1981.
PRESENTATIONS
"Rethinking Utility Rate Design Retail Demand and Energy Charges," Solar Power PV
Conference, Boston MA, February 24, 2016.
"Residential Demand Charges - Load Effects, Fairness &Rate Design Implications."Web
seminar sponsored by the NixTheFix Forum. September 2015.
"The Value of Demand Reduction Induced Price Effects."With Chris Neme. Web seminar
sponsored by the Regulatory Assistance Project. March 2015.
"Adding Transmission into New York City:Needs,Benefits,and Obstacles."Presentation to
FERC and the New York ISO on behalf of the City of New York. October 2004.
"Plugging Into a Municipal Light Plant."With Peter Enrich and Ken Barna.Panel presenta-
tion as part of the 2004 Annual Meeting of the Massachusetts Municipal Association.January
2004.
"Distributed Utility Planning." With Steve Litkovitz. Presentation to the Vermont Distri-
buted-Utility-Planning Collaborative. November 1999.
"The Economic and Environmental Benefits of Gas IRP: FERC 636 and Beyond."
Presentation as part of the Ohio Office of Energy Efficiency's seminar, "Gas Utility
Integrated Resource Planning,"April 1994.
Paul L. Chernick• Resource Insight, Incorporated Page 9
"Cost Recovery and Utility Incentives."Day-long presentation as part of the Demand-Side-
Management Training Institute's workshop, "DSM for Public Interest Groups," October
1993.
"Cost Allocation for Utility Ratemaking." With Susan Geller. Day-long workshop for the
staff of the Connecticut Department of Public Utility Control, October 1993.
"Comparing and Integrating DSM with Supply." Day-long presentation as part of the
Demand-Side-Management Training Institute's workshop,"DSM for Public Interest Groups,"
October 1993.
"DSM Cost Recovery and Rate Impacts." Presentation as part of "Effective DSM
Collaborative Processes,"a week-long training session for Ohio DSM advocates sponsored
by the Ohio Office of Energy Efficiency,August 1993.
"Cost-Effectiveness Analysis." Presentation as part of "Effective DSM Collaborative
Processes," a week-long training session for Ohio DSM advocates sponsored by the Ohio
Office of Energy Efficiency,August 1993.
"Environmental Externalities: Current Approaches and Potential Implications for District
Heating and Cooling" (with R. Brailove), International District Heating and Cooling
Association 84th Annual Conference. June 1993.
"Using the Costs of Required Controls to Incorporate the Costs of Environmental Extern-
alities in Non-Environmental Decision-Making." Presentation at the American Planning
Association 1992 National Planning Conference; presentation cosponsored by the Edison
Electric Institute. May 1992.
"Cost Recovery and Decoupling" and "The Clean Air Act and Externalities In Utility
Resource Planning"panels (session leader), DSM Advocacy Workshop.April 15 1992.
"Overview of Integrated Resources Planning Procedures in South Carolina and Critique of
South Carolina Demand Side Management Programs," Energy Planning Workshops;
Columbia, S.C. October 21 1991.
"Least Cost Planning and Gas Utilities."Demand-Side Management and the Global Environ-
ment Conference; Washington, D.C.April 22 1991.
Conservation Law Foundation Utility Energy Efficiency Advocacy Workshop; Boston,
February 28 1991.
"Least-Cost Planning in a Multi-Fuel Context."NARUC Forum on Gas Integrated Resource
Planning; Washington, D.C., February 24 1991.
"Accounting for Externalities:Why,Which and How?"Understanding Massachusetts'New
Integrated Resource Management Rules. Needham, Massachusetts,November 9 1990.
New England Gas Association Gas Utility Managers' Conference. Woodstock, Vermont,
September 10 1990.
Paul L. Chernick• Resource Insight, Incorporated Page 10
"Quantifying and Valuing Environmental Externalities." Presentation at the Lawrence
Berkeley Laboratory Training Program for Regulatory Staff, sponsored by the U.S.
Department of Energy's Least-Cost Utility Planning Program;Berkeley,California,February
2 1990;
"Conservation in the Future of Natural Gas Local Distribution Companies." District of
Columbia Natural Gas Seminar; Washington, D.C. May 23 1989.
"Conservation and Load Management for Natural Gas Utilities,"Massachusetts Natural Gas
Council; Newton, Massachusetts.April 3 1989.
New England Conference of Public Utilities Commissioners, Environmental Externalities
Workshop. Portsmouth,New Hampshire, January 22-23 1989.
"Assessment and Valuation of External Environmental Damages."New England Utility Rate
Forum. Plymouth,Massachusetts, October 11 1985; "Lessons from Massachusetts on Long
Term Rates for QFs".
"Reviewing Utility Supply Plans."Massachusetts Energy Facilities Siting Council;Boston,
Massachusetts. May 30 1985.
"Power Plant Performance.," National Association of State Utility Consumer Advocates;
Williamstown, Massachusetts.August 13 1984.
"Utility Rate Shock," National Conference of State Legislatures; Boston, Massachusetts,
August 6 1984.
"Review and Modification of Regulatory and Rate Making Policy," National Governors'
Association Working Group on Nuclear Power Cost Overruns; Washington, D.C., June 20
1984.
"Review and Modification of Regulatory and Rate Making Policy,"Annual Meeting of the
American Association for the Advancement of Science, Session on Monitoring for Risk
Management; Detroit, Michigan, May 27 1983.
ADVISORY ASSIGNMENTS TO REGULATORY COMMISSIONS
District of Columbia Public Service Commission, Docket No. 834, Phase II; Least-cost
planning procedures and goals.August 1987 to March 1988.
Connecticut Department of Public Utility Control, Docket No. 87-07-01, Phase 2; Rate
design and cost allocations. March 1988 to June 1989.
Austin City Council,Austin Energy Rates, March to June 2012.
Puerto Rico Energy Commission, Puerto Rico Electric Power Authority,rate design issues,
September 2015 to present.
Paul L. Chernick• Resource Insight, Incorporated Page 11
EXPERT TESTIMONY
1. Mass. EFSC 78-12/MDPU 19494, Phase I; Boston Edison 1978 forecast;
Massachusetts Attorney General. June 1978.
Appliance penetration projections, price elasticity, econometric commercial fore-
cast, peak demand forecast. Joint testimony with Susan C. Geller.
2. Mass. EFSC 78-17, Northeast Utilities 1978 forecast; Massachusetts Attorney
General. September 1978.
Specification of economic/demographic and industrial models,appliance efficiency,
commercial model structure and estimation.
3. Mass. EFSC 78-33, Eastern Utilities Associates 1978 forecast; Massachusetts
Attorney General. November 1978.
Household size, appliance efficiency, appliance penetration, price elasticity,
commercial forecast, industrial trending, peak demand forecast.
4. Mass. DPU 19494, Phase II; Boston Edison Company construction program;
Massachusetts Attorney General.April 1979.
Review of numerous aspects of the 1978 demand forecasts of nine New England
electric utilities,constituting 92%of projected regional demand growth, and of the
NEPOOL demand forecast. Joint testimony with Susan Geller.
5. Mass. DPU 19494, Phase II; Boston Edison Company construction program;
Massachusetts Attorney General.April 1979.
Reliability, capacity planning, capability responsibility allocation, customer gen-
eration, co-generation rates, reserve margins, operating reserve allocation. Joint
testimony with S. Finger.
6. U.S.ASLB NRC 50-471, Pilgrim Unit 2; Commonwealth of Massachusetts. June
1979.
Review of the Oak Ridge National Laboratory and NEPOOL demand forecast
models;cost-effectiveness of oil displacement;nuclear economics. Joint testimony
with Susan Geller.
7. Mass. DPU 19845, Boston Edison time-of-use-rate case; Massachusetts Attorney
General. December 1979.
Critique of utility marginal cost study and proposed rates; principles of marginal
cost principles, cost derivation, and rate design; options for reconciling costs and
revenues. Joint testimony with Susan Geller.
8. Mass.DPU 20055,petition of Eastern Utilities Associates,New Bedford G. &E.,
and Fitchburg G. & E. to purchase additional shares of Seabrook Nuclear Plant;
Massachusetts Attorney General. January 1980.
Paul L. Chernick• Resource Insight, Incorporated Page 12
Review of demand forecasts of three utilities purchasing Seabrook shares; Seabrook
power costs, including construction cost, completion date, capacity factor, O&M
expenses, interim replacements, reserves and uncertainties; alternative energy
sources, including conservation, cogeneration, rate reform, solar, wood and coal
conversion.
9. Mass. DPU 20248, petition of Massachusetts Municipal Wholesale Electric
Company to purchase additional share of Seabrook Nuclear Plant; Massachusetts
Attorney General. June 1980.
Nuclear power costs; update and extension of MDPU 20055 testimony.
10. Mass. DPU 200, Massachusetts Electric Company rate case; Massachusetts
Attorney General. June 1980.
Rate design; declining blocks, promotional rates, alternative energy, demand
charges,demand ratchets;conservation:master metering,storage heating,efficiency
standards, restricting resistance heating.
11. Mass. EFSC 79-33, Eastern Utilities Associates 1979 forecast; Massachusetts
Attorney General. July 1980.
Customer projections,consistency issues,appliance efficiency,new appliance types,
commercial specifications, industrial data manipulation and trending, sales and
resale.
12. Mass. DPU 243, Eastern Edison Company rate case; Massachusetts Attorney
General.August 1980.
Rate design: declining blocks, promotional rates, alternative energy, master me-
tering.
13. Texas PUC 3298, Gulf States Utilities rates; East Texas Legal Services. August
1980.
Inter-class revenue allocations,including production plant in-service,O&M,CWIP,
nuclear fuel in progress, amortization of canceled plant residential rate design;
interruptible rates; off-peak rates. Joint testimony with M. B. Meyer.
14. Mass. EFSC 79-1, Massachusetts Municipal Wholesale Electric Company
Forecast; Massachusetts Attorney General. November 1980.
Cost comparison methodology; nuclear cost estimates; cost of conservation, co-
generation, and solar.
15. Mass.DPU 472,recovery of residential conservation-service expenses;Massachu-
setts Attorney General. December 1980.
Conservation as an energy source; advantages of per-kWh allocation over per-
customer-month allocation.
Paul L. Chernick• Resource Insight, Incorporated Page 13
16. Mass. DPU 535; regulations to carry out Section 210 of PURPA; Massachusetts
Attorney General. January 1981 and February 1981.
Filing requirements, certification,qualifying-facility status, extent of coverage,re-
view of contracts; energy rates; capacity rates; extra benefits of qualifying facilities
in specific areas; wheeling; standardization of fees and charges.
17. Mass. EFSC 80-17, Northeast Utilities 1980 forecast; Massachusetts Attorney
General. March 1981.
Specification process, employment, electric heating promotion and penetration,
commercial sales model, industrial model specification, documentation of price
forecasts and wholesale forecast.
18. Mass.DPU 558,Western Massachusetts Electric Company rate case;Massachusetts
Attorney General. May 1981.
Rate design including declining blocks, marginal cost conservation impacts, and
promotional rates.Conservation,including terms and conditions limiting renewable,
cogeneration, small power production; scope of current conservation program;
efficient insulation levels; additional conservation opportunities.
19. Mass. DPU 1048, Boston Edison plant performance standards; Massachusetts
Attorney General. May 1982.
Critique of company approach, data, and statistical analysis; description of com-
parative and absolute approaches to standard-setting; proposals for standards and
reporting requirements.
20. DC PSC FC785, Potomac Electric Power rate case; DC Peoples Counsel. July
1982.
Inter-class revenue allocations,including generation,transmission,and distribution
plant classification;fuel and O&M classification;distribution and service allocators.
Marginal cost estimation, including losses.
21. N.H. PSC DE 81-312, Public Service of New Hampshire supply and demand;
Conservation Law Foundation et al. October 1982.
Conservation program design, ratemaking, and effectiveness. Cost of power from
Seabrook nuclear plant, including construction cost and duration, capacity factor,
O&M, replacements, insurance, and decommissioning.
22. Mass.Division of Insurance,hearing to fix and establish 1983 automobile insur-
ance rates; Massachusetts Attorney General. October 1982.
Profit margin calculations, including methodology, interest rates, surplus flow,tax
flows, tax rates, and risk premium.
23. Ill. CC 82-0026, Commonwealth Edison rate case; Illinois Attorney General.
October 1982.
Paul L. Chernick• Resource Insight, Incorporated Page 14
Review of Cost-Benefit Analysis for nuclear plant. Nuclear cost parameters (con-
struction cost, O&M,capital additions,useful like,capacity factor),risks,discount
rates, evaluation techniques.
24. N.M. PSC 1794, Public Service of New Mexico application for certification;New
Mexico Attorney General. May 1983.
Review of Cost-Benefit Analysis for transmission line. Review of electricity price
forecast, nuclear capacity factors, load forecast. Critique of company ratemaking
proposals; development of alternative ratemaking proposal.
25. Conn. DPUC 830301, United Illuminating rate case; Connecticut Consumers
Counsel. June 17 1983.
Cost of Seabrook nuclear power plants, including construction cost and duration,
capacity factor, O&M, capital additions, insurance and decommissioning.
26. Mass. DPU 1509, Boston Edison plant performance standards; Massachusetts
Attorney General. July 15 1983.
Critique of company approach and statistical analysis;regression model of nuclear
capacity factor; proposals for standards and for standard-setting methodologies.
27. Mass. Division of Insurance, hearing to fix and establish 1984 automobile-
insurance rates; Massachusetts Attorney General. October 1983.
Profit margin calculations, including methodology, interest rates.
28. Conn. DPUC 83-07-15, Connecticut Light and Power rate case; Alloy Foundry.
October 3 1983.
Industrial rate design. Marginal and embedded costs; classification of generation,
transmission, and distribution expenses; demand versus energy charges.
29. Mass.EFSC 83-24,New England Electric System forecast of electric resources and
requirements;Massachusetts Attorney General.November 14 1983,Rebuttal,Feb-
ruary 2 1984.
Need for transmission line. Status of supply plan,especially Seabrook 2.Review of
interconnection requirements.Analysis of cost-effectiveness for power transfer,line
losses, generation assumptions.
30. Mich. PSC U-7775, Detroit Edison Fuel Cost Recovery Plan; Public Interest
Research Group in Michigan. February 21 1984.
Review of proposed performance target for new nuclear power plant. Formulation
of alternative proposals.
31. Mass. DPU 84-25, Western Massachusetts Electric Company rate case; Massa-
chusetts Attorney General.April 6 1984.
Paul L. Chernick• Resource Insight, Incorporated Page 15
Need for Millstone 3. Cost of completing and operating unit, cost-effectiveness
compared to alternatives, and its effect on rates. Equity and incentive problems
created by CWIP. Design of Millstone 3 phase-in proposals to protect ratepayers:
limitation of base-rate treatment to fuel savings benefit of unit.
32. Mass.DPU 84-49 and 84-50, Fitchburg Gas &Electric financing case; Massachu-
setts Attorney General.April 13 1984.
Cost of completing and operating Seabrook nuclear units.Probability of completing
Seabrook 2.Recommendations regarding FG&E and MDPU actions with respect to
Seabrook.
33. Mich. PSC U-7785, Consumers Power fuel-cost-recovery plan; Public Interest
Research Group in Michigan.April 16 1984.
Review of proposed performance targets for two existing and two new nuclear
power plants. Formulation of alternative policy.
34. FERC ER81-749-000 and ER82-325-000,Montaup Electric rate cases;Massachu-
setts Attorney General.April 27 1984.
Prudence of Montaup and Boston Edison in decisions regarding Pilgrim 2 con-
struction: Montaup's decision to participate, the Utilities' failure to review their
earlier analyses and assumptions,Montaup's failure to question Edison's decisions,
and the utilities' delay in canceling the unit.
35. Maine PUC 84-113, Seabrook-1 investigation;Maine Public Advocate. September
13 1984.
Cost of completing and operating Seabrook Unit 1. Probability of completing
Seabrook 1. Comparison of Seabrook to alternatives. Rate effects. Recommenda-
tions regarding utility and PUC actions with respect to Seabrook.
36. Mass.DPU 84-145, Fitchburg Gas and Electric rate case; Massachusetts Attorney
General. November 6 1984.
Prudence of Fitchburg and Public Service of New Hampshire in decision regarding
Seabrook 2 construction: FGE's decision to participate, the utilities' failure to
review their earlier analyses and assumptions, FGE's failure to question PSNH's
decisions,and utilities'delay in halting construction and canceling the unit.Review
of literature, cost and schedule estimate histories, cost-benefit analyses, and
financial feasibility.
37. Penn. PUC R-842651, Pennsylvania Power and Light rate case; Pennsylvania
Consumer Advocate. November 1984.
Need for Susquehanna 2. Cost of operating unit, power output, cost-effectiveness
compared to alternatives, and its effect on rates. Design of phase-in and excess
capacity proposals to protect ratepayers: limitation of base-rate treatment to fuel
savings benefit of unit.
Paul L. Chernick• Resource Insight, Incorporated Page 16
38. N.H. PSC 84-200, Seabrook Unit-1 investigation; New Hampshire Consumer
Advocate. November 1984.
Cost of completing and operating Seabrook Unit 1. Probability of completing
Seabrook 1. Comparison of Seabrook to alternatives. Rate and financial effects.
39. Mass. Division of Insurance, hearing to fix and establish 1986 automobile
insurance rates; Massachusetts Attorney General. November 1984.
Profit-margin calculations, including methodology and implementation.
40. Mass. DPU 84-152, Seabrook Unit 1 investigation; Massachusetts Attorney
General. December 1984.
Cost of completing and operating Seabrook.Probability of completing Seabrook 1.
Seabrook capacity factors.
41. Maine PUC 84-120; Central Maine Power rate case; Maine PUC Staff. December
1984.
Prudence of Central Maine Power and Boston Edison in decisions regarding Pilgrim
2 construction: CMP's decision to participate, the utilities' failure to review their
earlier analyses and assumptions,CMP's failure to question Edison's decisions,and
the utilities' delay in canceling the unit. Prudence of CMP in the planning and
investment in Sears Island nuclear and coal plants. Review of literature, cost and
schedule estimate histories, cost-benefit analyses, and financial feasibility.
42. Maine PUC 84-113, Seabrook 2 investigation; Maine PUC Staff.December 1984.
Prudence of Maine utilities and Public Service of New Hampshire in decisions
regarding Seabrook 2 construction: decisions to participate and to increase owner-
ship share, the utilities' failure to review their earlier analyses and assumptions,
failure to question PSNH's decisions,and the utilities'delay in halting construction
and canceling the unit. Review of literature, cost and schedule estimate histories,
cost-benefit analyses, and financial feasibility.
43. Mass.DPU 1627,Massachusetts Municipal Wholesale Electric Company financing
case; Massachusetts Executive Office of Energy Resources. January 1985.
Cost of completing and operating Seabrook nuclear unit 1.Cost of conservation and
other alternatives to completing Seabrook. Comparison of Seabrook to alternatives.
44. Vt.PSB 4936,Millstone 3 costs and in-service date;Vermont Department of Public
Service. January 1985.
Construction schedule and cost of completing Millstone Unit 3.
45. Mass. DPU 84-276, rules governing rates for utility purchases of power from
qualifying facilities; Massachusetts Attorney General. March 1985 and October
1985.
Paul L. Chernick• Resource Insight, Incorporated Page 17
Institutional and technological advantages of Qualifying Facilities.Potential for QF
development. Goals of QF rate design. Parity with other power sources. Security
requirements.Projecting avoided costs. Capacity credits.Pricing options.Line loss
corrections.
46. Mass. DPU 85-121, investigation of the Reading Municipal Light Department;
Wilmington(Mass.) Chamber of Commerce. November 1985.
Calculation on return on investment for municipal utility.Treatment of depreciation
and debt for ratemaking. Geographical discrimination in street-lighting rates.
Relative size of voluntary payments to Reading and other towns. Surplus and
disinvestment. Revenue allocation.
47. Mass.Division of Insurance,hearing to fix and establish 1986 automobile insur-
ance rates; Massachusetts Attorney General and State Rating Bureau. November
1985.
Profit margin calculations, including methodology, implementation, modeling of
investment balances, income, and return to shareholders.
48. N.M. PSC 1833, Phase II; El Paso Electric rate case; New Mexico Attorney
General. December 1985.
Nuclear decommissioning fund design.Internal and external funds;risk and return;
fund accumulation,recommendations.Interim performance standard for Palo Verde
nuclear plant.
49. Penn.PUC R-850152,Philadelphia Electric rate case;Utility Users Committee and
University of Pennsylvania. January 1986.
Limerick-1 rate effects. Capacity benefits, fuel savings, operating costs, capacity
factors, and net benefits to ratepayers. Design of phase-in proposals.
50. Mass. DPU 85-270;, Western Massachusetts Electric rate case; Massachusetts
Attorney General. March 1986.
Prudence of Northeast Utilities in generation planning related to Millstone 3 con-
struction: decisions to start and continue construction, failure to reduce ownership
share,failure to pursue alternatives.Review of industry literature,cost and schedule
histories, and retrospective cost-benefit analyses.
51. Penn.PUC R-850290,Philadelphia Electric auxiliary service rates;Albert Einstein
Medical Center, University of Pennsylvania, and Amtrak. March 1986.
Review of utility proposals for supplementary and backup rates for small power
producers and cogenerators. Load diversity, cost of peaking capacity, value of
generation,price signals,and incentives.Formulation of alternative supplementary
rate.
Paul L. Chernick• Resource Insight, Incorporated Page 18
52. N.M. PSC 2004, Public Service of New Mexico Palo Verde issues; New Mexico
Attorney General. May 1986.
Recommendations for power-plant performance standards for Palo Verde nuclear
units 1, 2, and 3.
53. Ill. CC 86-0325, Iowa-Illinois Gas and Electric Co. rate investigation; Illinois
Office of Public Counsel.August 1986.
Determination of excess capacity based on reliability and economic concerns.
Identification of specific units associated with excess capacity. Required reserve
margins.
54. N.M.PSC 2009,El Paso Electric rate moderation program;New Mexico Attorney
General.August 1986.
Prudence of EPE in generation planning related to Palo Verde nuclear construction,
including failure to reduce ownership share and failure to pursue alternatives.
Review of industry literature, cost and schedule histories, and retrospective cost-
benefit analyses.
Recommendation for rate-base treatment; proposal of power plant performance
standards.
55. City of Boston Public Improvements Commission, transfer of Boston Edison
district heating steam system to Boston Thermal Corporation; Boston Housing
Authority. December 1986.
History and economics of steam system; possible motives of Boston Edison in
seeking sale;problems facing Boston Thermal;information and assurances required
prior to Commission approval of transfer.
56. Mass. Division of Insurance, hearing to fix and establish 1987 automobile in-
surance rates;Massachusetts Attorney General and State Rating Bureau.December
1986 and January 1987.
Profit margin calculations, including methodology, implementation, derivation of
cash flows, installment income, income tax status, and return to shareholders.
57. Mass. DPU 87-19, petition for adjudication of development facilitation program;
Hull (Mass.) Municipal Light Plant. January 1987.
Estimation of potential load growth; cost of generation, transmission, and distri-
bution additions. Determination of hook-up charges. Development of residential
load estimation procedure reflecting appliance ownership, dwelling size.
58. N.M. PSC 2004, Public Service of New Mexico nuclear decommissioning fund;
New Mexico Attorney General. February 1987.
Decommissioning cost and likely operating life of nuclear plants.Review of utility
funding proposal. Development of alternative proposal. Ratemaking treatment.
Paul L. Chernick• Resource Insight, Incorporated Page 19
59. Mass. DPU 86-280, Western Massachusetts Electric rate case; Massachusetts
Energy Office. March 1987.
Marginal cost rate design issues. Superiority of long-run marginal cost over short-
run marginal cost as basis for rate design.Relationship of Consumer reaction,utility
planning process,and regulatory structure to rate design approach.Implementation
of short-run and long-run rate designs. Demand versus energy charges, economic
development rates, spot pricing.
60. Mass.Division of Insurance 87-9, 1987 Workers'Compensation rate filing; State
Rating Bureau. May 1987.
Profit-margin calculations, including methodology, implementation, surplus re-
quirements, investment income, and effects of 1986 Tax Reform Act.
61. Texas PUC 6184, economic viability of South Texas Nuclear Plant#2; Committee
for Consumer Rate Relief.August 1987.
Nuclear plant operating parameter projections;capacity factor,O&M,capital addi-
tions, decommissioning, useful life. STNP-2 cost and schedule projections.
Potential for conservation.
62. Minn. PUC ER-015/GR-87-223, Minnesota Power rate case; Minnesota
Department of Public Service.August 1987.
Excess capacity on MP system; historical, current, and projected. Review of MP
planning prudence prior to and during excess; efforts to sell capacity. Cost of excess
capacity. Recommendations for ratemaking treatment.
63. Mass. Division of Insurance 87-27, 1988 automobile insurance rates; Massa-
chusetts Attorney General and State Rating Bureau. September 2 1987. Rebuttal
October 1987.
Underwriting profit margins. Effect of 1986 Tax Reform Act. Biases in calculation
of average margins.
64. Mass. DPU 88-19, power Sales Contract from Riverside Steam and Electric to
Western Massachusetts Electric; Riverside Steam and Electric. November 1987.
Comparison of risk from QF contract and utility avoided-cost sources. Risk of oil
dependence. Discounting cash flows to reflect risk.
65. Mass. Division of Insurance 87-53, 1987 Workers' Compensation rate refiling;
State Rating Bureau. December 1987.
Profit-margin calculations including updating of data, compliance with Commis-
sioner's order, treatment of surplus and risk, interest rate calculation, and
investment tax rate calculation.
Paul L. Chernick• Resource Insight, Incorporated Page 20
66. Mass.Division of Insurance, 1987 and 1988 automobile insurance remand rates;
Massachusetts Attorney General and State Rating Bureau. February 1988.
Underwriting profit margins. Provisions for income taxes on finance charges.
Relationships between allowed and achieved margins, between statewide and na-
tionwide data, and between profit allowances and cost projections.
67. Mass. DPU 86-36, investigation into the pricing and ratemaking treatment to be
afforded new electric generating facilities which are not qualifying facilities;
Conservation Law Foundation. May 1988.
Cost recovery for utility conservation programs. Compensating for lost revenues.
Utility incentive structures.
68. Mass. DPU 88-123, petition of Riverside Steam & Electric; Riverside Steam and
Electric Company. May 1988 and November 1988.
Estimation of avoided costs of Western Massachusetts Electric Company.Nuclear
capacity factor projections and effects on avoided costs. Avoided cost of energy
interchange and power plant life extensions. Differences between median and ex-
pected oil prices. Salvage value of cogeneration facility. Off-system energy purchase
projections. Reconciliation of avoided cost projection.
69. Mass. DPU 88-67, Boston Gas Company; Boston Housing Authority. June 1988.
Estimation of annual avoidable costs, 1988 to 2005, and levelized avoided costs.
Determination of cost recovery and carrying costs for conservation investments.
Standards for assessing conservation cost-effectiveness. Evaluation of cost-effec-
tiveness of utility funding of proposed natural gas conservation measures.
70. R.I. PUC 1900, Providence Water Supply Board tariff filing; Conservation Law
Foundation, Audubon Society of Rhode Island, and League of Women Voters of
Rhode Island. June 1988.
Estimation of avoidable water supply costs. Determination of costs of water con-
servation. Conservation cost-benefit analysis.
71. Mass.Division of Insurance 88-22, 1989 automobile insurance rates; Massachu-
setts Attorney General and State Rating Bureau;Profit Issues,August 1988,supple-
mented August 1988; Losses and Expenses, September 1988.
Underwriting profit margins.Effects of 1986 Tax Reform Act.Taxation of common
stocks. Lag in tax payments. Modeling risk and return over time. Treatment of
finance charges. Comparison of projected and achieved investment returns.
Paul L. Chernick• Resource Insight, Incorporated Page 21
72. Vt. PSB 5270 Module 6, investigation into least-cost investments, energy
efficiency, conservation, and the management of demand for energy; Conservation
Law Foundation,Vermont Natural Resources Council, and Vermont Public Interest
Research Group. September 1988.
Cost recovery for utility conservation programs. Compensation of utilities for
revenue losses and timing differences. Incentive for utility participation.
73. Vt. House of Representatives, Natural Resources Committee, House Act 130;
"Economic Analysis of Vermont Yankee Retirement"; Vermont Public Interest
Research Group. February 1989.
Projection of capacity factors,operating and maintenance expense,capital additions,
overhead, replacement power costs, and net costs of Vermont Yankee.
74. Mass. DPU 88-67 Phase II, Boston Gas company conservation program and rate
design; Boston Gas Company. March 1989.
Estimation of avoided gas cost; treatment of non-price factors; estimation of ex-
ternalities; identification of cost-effective conservation.
75. Vt. PSB 5270, status conference on conservation and load management policy
settlement; Central Vermont Public Service, Conservation Law Foundation,
Vermont Natural Resources Council,Vermont Public Interest Research Group,and
Vermont Department of Public Service. May 1989.
Cost-benefit test for utility conservation programs. Role of externalities. Cost re-
covery concepts and mechanisms.Resource allocations,cost allocations,and equity
considerations. Guidelines for conservation preapproval mechanisms. Incentive
mechanisms and recovery of lost revenues.
76. Boston Housing Authority Court 05099, Gallivan Boulevard Task Force vs.
Boston Housing Authority, et al.; Boston Housing Authority. June 1989.
Effect of master-metering on consumption of natural gas and electricity.Legislative
and regulatory mandates regarding conservation.
77. Mass.DPU 89-100,Boston Edison rates;Massachusetts Energy Office.June 1989.
Prudence of decision to spend$400 million from 1986-88 to return Pilgrim nuclear
plant to service. Projections of nuclear capacity factors, O&M, capital additions,
and overhead. Review of decommissioning cost, tax effect of abandonment,
replacement power cost,and plant useful life estimates. Requirements for prudence
and used-and-useful analyses.
Paul L. Chernick• Resource Insight, Incorporated Page 22
78. Mass.DPU 88-123,petition of Riverside Steam and Electric Company; Riverside
Steam and Electric. July 1989. Rebuttal, October 1989.
Reasonableness of Northeast Utilities' 1987 avoided cost estimates. Projections of
nuclear capacity factors, economy purchases, and power plant operating life.
Treatment of avoidable energy and capacity costs and of off-system sales.Expected
versus reference fuel prices.
79. Mass. DPU 89-72, Statewide Towing Association police-ordered towing rates;
Massachusetts Automobile Rating Bureau. September 1989.
Review of study supporting proposed increase in towing rates. Critique of study
sample and methodology. Comparison to competitive rates. Supply of towing
services. Effects of joint products and joint sales on profitability of police-ordered
towing. Joint testimony with I. Goodman.
80. Vt. PSB 5330, application of Vermont utilities for approval of a firm power and
energy contract with Hydro-Quebec; Conservation Law Foundation, Vermont
Natural Resources Council, Vermont Public Interest Research Group. December
1989. Surrebuttal February 1990.
Analysis of a proposed 20-year power purchase. Comparison to efficiency
investment. Critique of conservation potential analysis.Analysis of Vermont electric
energy supply. Planning risk of large supply additions.Valuation of environmental
externalities. Identification of possible improvements to proposed contract.
81. Mass. DPU 89-239, inclusion of externalities in energy-supply planning,
acquisition, and dispatch for Massachusetts utilities. Boston Gas Company.
December 1989;April 1990; May 1990.
Critique of Division of Energy Resources report on externalities. Methodology for
evaluating external costs. Proposed values for environmental and economic
externalities of fuel supply and use.
82. California PUC, incorporation of environmental externalities in utility planning
and pricing; Coalition of Energy Efficient and Renewable Technologies. February
1990.
Approaches for valuing externalities for inclusion in setting power purchase rates.
Effect of uncertainty on assessing externality values.
83. Ill. CC 90-003 8, proceeding to adopt a least-cost electric-energy plan for
Commonwealth Edison Company; City of Chicago. May 25 1990. Joint rebuttal
testimony with David Birr,August 1990.
Problems in Commonwealth Edison's approach to demand-side management.
Potential for cost-effective conservation.Valuing externalities in least-cost planning.
Paul L. Chernick• Resource Insight, Incorporated Page 23
84. Md. PSC 8278, adequacy of Baltimore Gas &Electric's integrated resource plan;
Maryland Office of People's Counsel. September 1990.
Rationale for demand-side management. BG&E's problems in approach to DSM
planning. Potential for cost-effective conservation. Valuation of environmental
externalities. Recommendations for short-term DSM program priorities.
85. Ind.URC,integrated-resource-planning docket;Indiana Office of Utility Consumer
Counselor. November 1990.
Integrated resource planning process and methodology,including externalities and
screening tools.Incentives,screening,and evaluation of demand-side management.
Potential of resource bidding in Indiana.
86. Mass. DPU 89-1411 90-731 90-1411 90-1941 90-270; preliminary review of utility
treatment of environmental externalities in October qualifying-facilities filings;
Boston Gas Company. November 1990.
Generic and specific problems in Massachusetts utilities'RFPs with regard to ex-
ternality valuation requirements. Recommendations for corrections.
87. Mass. EFSC 90-12/90-12A, adequacy of Boston Edison proposal to build com-
bined-cycle plant; Conservation Law Foundation. December 1990.
Problems in Boston Edison's treatment of demand-side management,supply option
analysis, and resource planning. Recommendations of mitigation options.
88. Maine PUC 90-286,adequacy of conservation program of Bangor Hydro Electric;
Penobscot River Coalition. February 1991.
Role of utility-sponsored DSM in least-cost planning.Bangor Hydro's potential for
cost-effective conservation. Problems with Bangor Hydro's assumptions about
customer investment in energy efficiency measures.
89. Va. SCC PUE900070, commission investigation; Southern Environmental Law
Center. March 1991.
Role of utilities in promoting energy efficiency. Least-cost planning objectives of
and resource acquisition guidelines for DSM.Ratemaking considerations for DSM
investments.
90. Mass.DPU 90-261-A, economics and role of fuel-switching in the DSM program
of the Massachusetts Electric Company; Boston Gas Company.April 1991.
Role of fuel-switching in utility DSM programs and specifically in Massachusetts
Electric's. Establishing comparable avoided costs and comparison of electric and
gas system costs. Updated externality values.
Paul L. Chernick• Resource Insight, Incorporated Page 24
91. Private arbitration,Massachusetts Refusetech Contractual Request forAdjustment
to Service Fee; Massachusetts Refusetech. May 1991.
NEPCo rates for power purchases from the New England Solid Waste Compact
plant. Fuel price and avoided cost projections vs. realities.
92. Vt. PSB 5491, cost-effectiveness of Central Vermont's commitment to Hydro
Quebec purchases; Conservation Law Foundation. July 1991.
Changes in load forecasts and resale markets since approval of HQ purchases.
Effect of HQ purchase on DSM.
93. S.C. PSC 91-216-E, cost recovery of Duke Power's DSM expenditures; South
Carolina Department of Consumer Affairs. Direct, September 13 1991; Surrebuttal
October 1991.
Problems with conservation plans of Duke Power, including load building, cream
skimming, and inappropriate rate designs.
94. Md.PSC 8241 Phase II,review of Baltimore Gas&Electric's avoided costs;Mary-
land Office of People's Counsel. September 1991.
Development of direct avoided costs for DSM. Problems with BG&E's avoided
costs and DSM screening. Incorporation of environmental externalities.
95. Bucksport(Maine)Planning Board,AES/Harriman Cove shoreland zoning appli-
cation; Conservation Law Foundation and Natural Resources Council of Maine.
October 1991.
New England's power surplus. Costs of bringing AES/Harriman Cove on line to
back out existing generation.Alternatives.
96. Mass. DPU 91-131, update of externalities values adopted in Docket 89-239;
Boston Gas Company. October 1991. Rebuttal, December 1991.
Updates on pollutant externality values.Addition of values for chlorofluorocarbons,
air toxics, thermal pollution, and oil import premium. Review of state regulatory
actions regarding externalities.
97. Fla.PSC 910759,petition of Florida Power Corporation for determination of need
for proposed electrical power plant and related facilities;Floridians for Responsible
Utility Growth. October 1991.
Florida Power's obligation to pursue integrated resource planning and failure to
establish need for proposed facility.Methods to increase scope and scale of demand-
side investment.
Paul L. Chernick• Resource Insight, Incorporated Page 25
98. Fla. PSC 910833-EI, petition of Tampa Electric Company for a determination of
need for proposed electrical power plant and related facilities; Floridians for
Responsible Utility Growth. October 1991.
Obligation to pursue integrated resource planning, failure to establish need for
proposed facility. Methods to increase scope and scale of demand-side investment.
99. Penn. PUC I-900005, R-901880; investigation into demand-side management by
electric utilities; Pennsylvania Energy Office. January 1992.
Appropriate cost recovery mechanism for Pennsylvania utilities.Purpose and scope
of direct cost recovery, lost revenue recovery, and incentives.
100. S.C.PSC 91-606-E,petition of South Carolina Electric and Gas for a certificate of
public convenience and necessity for a coal-fired plant; South Carolina Department
of Consumer Affairs. January 1992.
Justification of plant certification under integrated resource planning. Failures in
SCE&G's DSM planning and company potential for demand-side savings.
101. Mass. DPU 92-92, adequacy of Boston Edison's street-lighting options; Town of
Lexington. June 1992.
Efficiency and quality of street-lighting options.Boston Edison's treatment of high-
quality street lighting. Corrected rate proposal for the Daylux lamp. Ownership of
public street lighting.
102. S.C. PSC 92-208-E, integrated-resource plan of Duke Power Company; South
Carolina Department of Consumer Affairs.August 1992.
Problems with Duke Power's DSM screening process, estimation of avoided cost,
DSM program design, and integration of demand-side and supply-side planning.
103. N.C. UC E-100 Sub 64, integrated-resource-planning docket; Southern
Environmental Law Center. September 1992.
General principles of integrated resource planning, DSM screening, and program
design. Review of the IRPs of Duke Power Company, Carolina Power & Light
Company, and North Carolina Power.
104. Ont. EAB Ontario Hydro Demand/Supply Plan Hearings,Environmental Extern-
alities Valuation and Ontario Hydros Resource Planning (3 vols.); Coalition of
Environmental Groups. October 1992.
Valuation of environmental externalities from fossil fuel combustion and the nuclear
fuel cycle.Application to Ontario Hydro's supply and demand planning.
Paul L. Chernick• Resource Insight, Incorporated Page 26
105. Texas PUC 110000, application of Houston Lighting and Power company for a
certificate of convenience and necessity for the DuPont Project;Destec Energy,Inc.
September 1992.
Valuation of environmental externalities from fossil fuel combustion and the
application to the evaluation of proposed cogeneration facility.
106. Maine BEP, in the matter of the Basin Mills Hydroelectric Project application;
Conservation Intervenors. November 1992.
Economic and environmental effects of generation by proposed hydro-electric
project.
107. Md.PSC 8473,review of the power sales agreement of Baltimore Gas and Electric
with AES Northside; Maryland Office of People's Counsel. November 1992.
Non-price scoring and unquantified benefits;DSM potential as alternative;environ-
mental costs; cost and benefit estimates.
108. N.C.UC E-100 Sub 64,analysis and investigation of least cost integrated resource
planning in North Carolina; Southern Environmental Law Center.November 1992.
Demand-side management cost recovery and incentive mechanisms.
109. S.C. PSC 92-209-E, in re Carolina Power & Light Company; South Carolina
Department of Consumer Affairs. November 1992.
Demand-side-management planning: objectives, process, cost-effectiveness test,
comprehensiveness,lost opportunities. Deficiencies in CP&L's portfolio.Need for
economic evaluation of load building.
110 Fla.DER hearings on the Power Plant Siting Act;Legal Environmental Assistance
Foundation. December 1992.
Externality valuation and application in power-plant siting. DSM potential, cost-
benefit test, and program designs.
111. Md. PSC 8487, Baltimore Gas and Electric Company electric rate case. Direct
January 1993; rebuttal February 1993.
Class allocation of production plant and O&M; transmission, distribution, and
general plant; administrative and general expenses. Marginal cost and rate design.
112. Md. PSC 8179,Approval of amendment to Potomac Edison purchase agreement
with AES Warrior Run; Maryland Office of People's Counsel. January 29 1993.
Economic analysis of proposed coal-fired cogeneration facility.
Paul L. Chernick• Resource Insight, Incorporated Page 27
113. Mich. PSC U-10102, Detroit Edison rate case; Michigan United Conservation
Clubs. February 17 1993.
Least-cost planning; energy efficiency planning,potential,screening,avoided costs,
cost recovery, and shareholder incentives.
114. Ohio PUC 91-63 5-EL-FOR, 92-312-EL-FOR, 92-1172-EL-ECP; Cincinnati Gas
and Electric demand-management programs; City of Cincinnati.April 1993.
Demand-side-management planning, program designs, potential savings, and
avoided costs.
115. Mich.PSC U-103 3 5, Consumers Power rate case; Michigan United Conservation
Clubs. October 1993.
Least-cost planning; energy efficiency planning,potential,screening,avoided costs,
cost recovery, and shareholder incentives.
116. Ill.CC 92-0268, electric-energy plan for Commonwealth Edison; City of Chicago.
Direct, February 1 1994; rebuttal, September 1994.
Cost-effectiveness screening of demand-side management programs and measures;
estimates by Commonwealth Edison of costs avoided by DSM and of future cost,
capacity, and performance of supply resources.
117. FERC 2422 et al., application of James River—New Hampshire Electric, Public
Service of New Hampshire, for licensing of hydro power; Conservation Law
Foundation; 1993.
Cost-effective energy conservation available to the Public Service of New
Hampshire; power-supply options; affidavit.
118. Vt. PSB 5270-CV 1,-3, and 5686; Central Vermont Public Service fuel-switching
and DSM program design,on behalf of the Vermont Department of Public Service.
Direct,April 1994; rebuttal, June 1994.
Avoided costs and screening of controlled water-heating measures; risk, rate
impacts,participant costs,externalities, space-and water-heating load,benefit-cost
tests.
119. Fla.PSC 93 0548-EG-93 05 5 1-EG,conservation goals for Florida electric utilities;
Legal Environmental Assistance Foundation, Inc.April 1994.
Integrated resource planning, avoided costs,rate impacts, analysis of conservation
goals of Florida electric utilities.
120. Vt. PSB 5724, Central Vermont Public Service Corporation rate request;Vermont
Department of Public Service. Joint surrebuttal testimony with John Plunkett.
August 1994.
Costs avoided by DSM programs; Costs and benefits of deferring DSM programs.
Paul L. Chernick• Resource Insight, Incorporated Page 28
121. Mass. DPU 94-49, Boston Edison integrated-resource-management plan; Massa-
chusetts Attorney General.August 1994.
Least-cost planning, modeling, and treatment of risk.
122. Mich. PSC U-105 54, Consumers Power Company DSM program and incentive;
Michigan Conservation Clubs. November 1994.
Critique of proposed reductions in DSM programs; discussion of appropriate
measurements of cost-effectiveness, role of DSM in competitive power markets.
123. Mich. PSC U-10702, Detroit Edison Company cost recovery, on behalf of the
Residential Ratepayers Consortium. December 1994.
Impact of proposed changes to DSM plan on energy costs and power-supply-cost-
recovery charges. Critique of proposed DSM changes; discussion of appropriate
measurements of cost-effectiveness, role of DSM in competitive power markets.
124. N.J.BRC EM92030359, environmental costs of proposed cogeneration; Freehold
Cogeneration Associates. November 1994.
Comparison of potential externalities from the Freehold cogeneration project with
that from three coal technologies; support for the study"The Externalities of Four
Power Plants."
125. Mich. PSC U-10671, Detroit Edison Company DSM programs; Michigan United
Conservation Clubs. January 1995.
Critique of proposal to scale back DSM efforts in light of potential for competition.
Loss of savings, increase of customer costs, and decrease of competitiveness.
Discussion of appropriate measurements of cost-effectiveness, role of DSM in
competitive power markets.
126. Mich. PSC U-10710, power-supply-cost-recovery plan of Consumers Power
Company; Residential Ratepayers Consortium. January 1995.
Impact of proposed changes to DSM plan on energy costs and power-supply-cost-
recovery charges. Critique of proposed DSM changes; discussion of appropriate
measurements of cost-effectiveness, role of DSM in competitive power markets.
127. FERC 2458 and 2572, Bowater—Great Northern Paper hydropower licensing;
Conservation Law Foundation. February 1995.
Comments on draft environmental impact statement relating to new licenses for two
hydropower projects in Maine.Applicant has not adequately considered how energy
conservation can replace energy lost due to habitat-protection or -enhancement
measures.
Paul L. Chernick• Resource Insight, Incorporated Page 29
128. N.C. UC E-100 Sub 74, Duke Power and Carolina Power & Light avoided costs;
Hydro-Electric—Power Producer's Group. February 1995.
Critique and proposed revision of avoided costs offered to small hydro-power
producers by Duke Power and Carolina Power and Light.
129. New Orleans City Council UD-92-2A and -2B, least-cost IRP for New Orleans
Public Service and Louisiana Power & Light; Alliance for Affordable Energy.
Direct, February 1995; rebuttal,April 1995.
Critique of proposal to scale back DSM efforts in light of potential competition.
130. D.C. PSC FC917 II, prudence of DSM expenditures of Potomac Electric Power
Company; Potomac Electric Power Company. Rebuttal testimony, February 1995.
Prudence of utility DSM investment;prudence standards for DSM programs of the
Potomac Electric Power Company.
131. Ont.Energy Board EBRO 490,DSM cost recovery and lost-revenue—adjustment
mechanism for Consumers Gas Company; Green Energy Coalition.April 1995.
Demand-side-management cost recovery.Lost-revenue—adjustment mechanism for
Consumers Gas Company.
132. New Orleans City Council CD-85-1, New Orleans Public Service rate increase;
Alliance for Affordable Energy. Rebuttal, May 1995.
Allocation of costs and benefits to rate classes.
133. Mass. DPU Docket DPU-95-40, Mass. Electric cost-allocation; Massachusetts
Attorney General. June 1995.
Allocation of costs to rate classes. Critique of cost-of-service study.Implications for
industry restructuring.
134. Md. PSC 8697, Baltimore Gas & Electric gas rate increase; Maryland Office of
People's Counsel. July 1995.
Rate design, cost-of-service study, and revenue allocation.
135. N.C. UC E-2 Sub 669. December 1995.
Need for new capacity. Energy-conservation potential and model programs.
136. Arizona CC U-1933-95-317, Tucson Electric Power rate increase; Residential
Utility Consumer Office. January 1996.
Review of proposed rate settlement. Used-and-usefulness of plant. Rate design.
DSM potential.
Paul L. Chernick• Resource Insight, Incorporated Page 30
137. Ohio PUC 95-203-EL-FOR; Campaign for an Energy-Efficient Ohio. February
1996
Long-term forecast of Cincinnati Gas and Electric Company, especially its DSM
portfolio. Opportunities for further cost-effective DSM savings. Tests of cost
effectiveness. Role of DSM in light of industry restructuring; alternatives to
traditional utility DSM.
138 Vt. PSB 5835, Central Vermont Public Service Company rates; Vermont
Department of Public Service. February 1996.
Design of load-management rates of Central Vermont Public Service Company.
139. Md.PSC 8720,Washington Gas Light DSM;Maryland Office of People's Counsel.
May 1996.
Avoided costs of Washington Gas Light Company; integrated least-cost planning.
140. Mass. DPU 96-100, Massachusetts Utilities' Stranded Costs; Massachusetts
Attorney General. Oral testimony in support of "estimation of Market Value,
Stranded Investment, and Restructuring Gains for Major Massachusetts Utilities,"
July 1996.
Stranded costs. Calculation of loss or gain. Valuation of utility assets.
141. Mass. DPU 96-70, Essex County Gas Company rates; Massachusetts Attorney
General. July 1996.
Market-based allocation of gas-supply costs of Essex County Gas Company.
142. Mass.DPU 96-60,Fall River Gas Company rates;Massachusetts Attorney General.
Direct, July 1996; surrebuttal,August 1996.
Market-based allocation of gas-supply costs of Fall River Gas Company.
143. Md. PSC 8725, Maryland electric-utilities merger; Maryland Office of People's
Counsel. July 1996.
Proposed merger of Baltimore Gas &Electric Company, Potomac Electric Power
Company, and Constellation Energy. Cost allocation of merger benefits and rate
reductions.
144. N.H.PUC DR 96-150,Public Service Company of New Hampshire stranded costs;
New Hampshire Office of Consumer Advocate. December 1996.
Market price of capacity and energy; value of generation plant; restructuring gain
and stranded investment; legal status of PSNH acquisition premium; interim
stranded-cost charges.
Paul L. Chernick• Resource Insight, Incorporated Page 31
145. Ont.Energy Board EBRO 495,LRAM and shared-savings incentive for DSM per-
formance of Consumers Gas; Green Energy Coalition. March 1997.
LRAM and incentive mechanisms in rates for the Consumers Gas Company.
146. New York PSC 96-E-0897, Consolidated Edison restructuring plan; City of New
York.April 1997.
Electric-utility competition and restructuring; critique of proposed settlement of
Consolidated Edison Company; stranded costs;market power;rates;market access.
147. Vt. PSB 5980, proposed statewide energy plan; Vermont Department of Public
Service. Direct,August 1997; rebuttal, December 1997.
Justification for and estimation of statewide avoided costs;guidelines for distributed
IRP.
148. Mass.DPU 96-23,Boston Edison restructuring settlement;Utility Workers Union
of America. September 1997.
Performance incentives proposed for the Boston Edison company.
149. Vt.PSB 5983,Green Mountain Power rate increase;Vermont Department of Public
Service. Direct, October 1997; rebuttal, December 1997.
In three separate pieces of prefiled testimony,addressed the Green Mountain Power
Corporation's (1) distributed-utility-planning efforts, (2) avoided costs, and (3)
prudence of decisions relating to a power purchase from Hydro-Quebec.
150. Mass.DPU 97-63,Boston Edison proposed reorganization;Utility Workers Union
of America. October 1997.
Increased costs and risks to ratepayers and shareholders from proposed reorgani-
zation; risks of diversification; diversion of capital from regulated to unregulated
affiliates; reduction in Commission authority.
151. Mass. DTE 97-111, Commonwealth Energy proposed restructuring; Cape Cod
Light Compact. Joint testimony with Jonathan Wallach, January 1998.
Critique of proposed restructuring plan filed to satisfy requirements of the electric-
utility restructuring act of 1997. Failure of the plan to foster competition and
promote the public interest.
152. N.H. PUC Docket DR 97-241, Connecticut Valley Electric fuel and purchased-
power adjustments; City of Claremont, N.H. February 1998.
Prudence of continued power purchase from affiliate; market cost of power;
prudence disallowances and cost-of-service ratemaking.
153. Md.PSC 87741 APS-DQE merger;Maryland Office of People's Counsel.February
1998.
Paul L. Chernick• Resource Insight, Incorporated Page 32
Proposed power-supply arrangements between APS's potential operating
subsidiaries; power-supply savings; market power.
154. Vt.PSB 6018, Central Vermont Public Service Co.rate increase;Vermont Depart-
ment of Public Service. February 1998.
Prudence of decisions relating to a power purchase from Hydro-Quebec. Reason-
ableness of avoided-cost estimates. Quality of DU planning.
155. Maine PUC 97-5 80,Central Maine Power restructuring and rates;Maine Office of
Public Advocate. May 1998; Surrebuttal,August 1998.
Determination of stranded costs; gains from sales of fossil, hydro, and biomass
plant; treatment of deferred taxes; incentives for stranded-cost mitigation; rate
design.
156. Mass.DTE 98-89,purchase of Boston Edison municipal street lighting; Towns of
Lexington and Acton.Affidavit,August 1998.
Valuation of municipal streetlighting; depreciation; applicability of unbundled rate.
157. Vt.PSB 6107,Green Mountain Power rate increase;Vermont Department of Public
Service.Direct, September 1998; Surrebuttal drafted but not filed,November 2000.
Prudence of decisions relating to a power purchase from Hydro-Quebec.Least-cost
planning and prudence. Quality of DU planning.
158. Mass. DTE 97-120, Western Massachusetts Electric Company proposed restruc-
turing; Massachusetts Attorney General. Joint testimony with Jonathan Wallach,
October 1998. Joint surrebuttal with Jonathan Wallach, January 1999.
Market value of the three Millstone nuclear units under varying assumptions of
plant performance and market prices. Independent forecast of wholesale market
prices. Value of Pilgrim and TMI-1 asset sales.
159. Md. PSC 8794 and 8804, BG&E restructuring and rates; Maryland Office of
People's Counsel. Direct, December 1998; rebuttal, March 1999.
Implementation of restructuring. Valuation of generation assets from comparable-
sales and cash-flow analyses. Determination of stranded cost or gain.
160. Md.PSC 8795; Delmarva Power&Light restructuring and rates;Maryland Office
of People's Counsel. December 1998.
Implementation of restructuring.Valuation of generation assets and purchases from
comparable-sales and cash-flow analyses. Determination of stranded cost or gain.
161. Md.PSC 8797,Potomac Edison Company restructuring and rates;Maryland Office
of People's Counsel. Direct, January 1999; rebuttal, March 1999.
Implementation of restructuring.Valuation of generation assets and purchases from
comparable-sales and cash-flow analyses. Determination of stranded cost or gain.
Paul L. Chernick• Resource Insight, Incorporated Page 33
162. Conn. DPUC 99-02-05, Connecticut Light and Power Company stranded costs;
Connecticut Office of Consumer Counsel.April 1999.
Projections of market price.Valuation of purchase agreements and nuclear and non-
nuclear assets from comparable-sales and cash-flow analyses.
163. Conn.DPUC 99-03-04,United Illuminating Company stranded costs;Connecticut
Office of Consumer Counsel.April 1999.
Projections of market price. Valuation of purchase agreements and nuclear assets
from comparable-sales and cash-flow analyses.
164. Wash.UTC UE-981627,PacifiCorp—Scottish Power merger,Office of the Attorney
General. June 1999.
Review of proposed performance standards and valuation of performance. Review
of proposed low-income assistance.
165. Utah PSC 98-2035-04, PacifiCorp—Scottish Power merger, Utah Committee of
Consumer Services. June 1999.
Review of proposed performance standards and valuation of performance.
166. Conn. DPUC 99-03-35, United Illuminating Company proposed standard offer;
Connecticut Office of Consumer Counsel. July 1999.
Design of standard offer by rate class. Design of price adjustments to preserve rate
decrease. Market valuations of nuclear plants. Short-term stranded cost
167. Conn.DPUC 99-03-36,Connecticut Light and Power Company proposed standard
offer; Connecticut Office of Consumer Counsel. Direct, July 1999; supplemental,
July 1999.
Design of standard offer by rate class. Design of price adjustments to preserve rate
decrease. Market valuations of nuclear plants. Short-term stranded cost.
168. W.Va.PSC 98-0452-E-GI,electric-industry restructuring,West Virginia Consumer
Advocate. July 1999.
Market value of generating assets of, and restructuring gain for, Potomac Edison,
Monongahela Power, and Appalachian Power. Comparable-sales and cash-flow
analyses.
169. Ont. Energy Board RP-1999-0034, Ontario performance-based rates; Green
Energy Coalition. September 1999.
Rate design.Recovery of demand-side-management costs under PBR.Incremental
costs.
Paul L. Chernick• Resource Insight, Incorporated Page 34
170. Conn. DPUC 99-08-01, standards for utility restructuring; Connecticut Office of
Consumer Counsel. Direct, November 1999; supplemental, January 2000.
Appropriate role of regulation. T&D reliability and service quality. Performance
standards and customer guarantees.Assessing generation adequacy in a competitive
market.
171. Conn. Superior Court CV 99-049-7239, Connecticut Light and Power Company
stranded costs; Connecticut Office of Consumer Counsel. Affidavit, December
1999.
Errors of the Conn. DPUC in deriving discounted-cash-flow valuations for
Millstone and Seabrook, and in setting minimum bid price.
172. Conn. Superior Court CV 99-049-7597, United Illuminating Company stranded
costs; Connecticut Office of Consumer Counsel. December 1999.
Errors of the Conn. DPUC, in its discounted-cash-flow computations, in selecting
performance assumptions for Seabrook, and in setting minimum bid price.
173. Ont. Energy Board RP-1999-0044, Ontario Hydro transmission-cost allocation
and rate design; Green Energy Coalition. January 2000.
Cost allocation and rate design. Net vs. gross load billing. Export and wheeling-
through transactions. Environmental implications of utility proposals.
174. Utah PSC 99-2035-03, PacifiCorp Sale of Centralia plant, mine, and related
facilities; Utah Committee of Consumer Services. January 2000.
Prudence of sale and management of auction.Benefits to ratepayers.Allocation and
rate treatment of gain.
175. Conn. DPUC 99-09-12, Nuclear Divestiture by Connecticut Light & Power and
United Illuminating; Connecticut Office of Consumer Counsel. January 2000.
Market for nuclear assets. Optimal structure of auctions. Value of minority rights.
Timing of divestiture.
176. Ont. Energy Board RP-1999-0017, Union Gas PBR proposal; Green Energy
Coalition. March 2000.
Lost-revenue-adjustment and shared-savings incentive mechanisms for Union Gas
DSM programs. Standards for review of targets and achievements, computation of
lost revenues. Need for DSM expenditure true-up mechanism.
177. N.Y. PSC 99-5-1621, Consolidated Edison steam rates; City of New York. April
2000.
Allocation of costs of former cogeneration plants,and of net proceeds of asset sale.
Economic justification for steam-supply plans. Depreciation rates. Weather
normalization and other rate adjustments.
Paul L. Chernick• Resource Insight, Incorporated Page 35
178. Maine PUC 99-666, Central Maine Power alternative rate plan; Maine Public
Advocate. Direct, May 2000; Surrebuttal,August 2000.
Likely merger savings. Savings and rate reductions from recent mergers. Implica-
tions for rates.
179. Mass. EFSB 97-4, Massachusetts Municipal Wholesale Electric Company gas-
pipeline proposal; Town of Wilbraham, Mass. June 2000.
Economic justification for natural-gas pipeline. Role and jurisdiction of EFSB.
180. Conn.DPUC 99-09-03;Connecticut Natural Gas Corporation merger and rate plan;
Connecticut office of Consumer Counsel. September 2000.
Performance-based ratemaking in light of mergers. Allocation of savings from
merger. Earnings-sharing mechanism.
181. Conn. DPUC 99-09-12RE01, Proposed Millstone sale; Connecticut Office of
Consumer Counsel. November 2000.
Requirements for review of auction of generation assets. Allocation of proceeds
between units.
182. Mass. DTE 01-25, Purchase of streetlights from Commonwealth Electric; Cape
Light Compact. January 2001
Municipal purchase of streetlights; Calculation of purchase price under state law;
Determination of accumulated depreciation by asset.
183. Conn.DPUC 00-12-01 and 99-09-12RE03,Connecticut Light&Power rate design
and standard offer; Connecticut Office of Consumer Counsel. March 2001.
Rate design and standard offer under restructuring law; Future rate impacts;
Transition to restructured regime; Comparison of Connecticut and California
restructuring challenges.
184. Vt.PSB 6460&6120,Central Vermont Public Service rates;Vermont Department
of Public Service. Direct, March 2001; Surrebuttal,April 2001.
Review of decision in early 1990s to commit to long-term uneconomic purchase
from Hydro Quebec. Calculation of present damages from imprudence.
185. N.J.BPU EM00020106,Atlantic City Electric Company sale of fossil plants;New
Jersey Ratepayer Advocate.Affidavit, May 2001.
Comparison of power-supply contracts. Comparison of plant costs to replacement
power cost.Allocation of sales proceeds between subsidiaries.
Paul L. Chernick• Resource Insight, Incorporated Page 36
186. N.J. BPU GM00080564, Public Service Electric and Gas transfer of gas supply
contracts; New Jersey Ratepayer Advocate. Direct, May 2001.
Transfer of gas transportation contracts to unregulated affiliate.Potential for market
power in wholesale gas supply and electric generation. Importance of reliable gas
supply. Valuation of contracts. Effect of proposed requirements contract on rates.
Regulation and design of standard-offer service.
187. Conn.DPUC 99-04-18 Phase 3, 99-09-03 Phase 2; Southern Connecticut Natural
Gas and Connecticut Natural Gas rates and charges; Connecticut Office of
Consumer Counsel. Direct, June 2001; supplemental, July 2001.
Identifying,quantifying,and allocating merger-related gas-supply savings between
ratepayers and shareholders.Establishing baselines.Allocations between affiliates.
Unaccounted-for gas.
188. N.J. BPU EX01050303, New Jersey electric companies' procurement of basic
supply; New Jersey Ratepayer Advocate.August 2001.
Review of proposed statewide auction for purchase of power requirements.Market
power. Risks to ratepayers of proposed auction.
189. N.Y.PSC 00-E-1208,Consolidated Edison rates; City of New York. October 2001.
Geographic allocation of stranded costs. Locational and postage-stamp rates.
Causation of stranded costs. Relationship between market prices for power and
stranded costs.
190. Mass. DTE 01-56, Berkshire Gas Company; Massachusetts Attorney General.
October 2001.
Allocation of gas costs by load shape and season. Competition and cost allocation.
191. N.J.BPU EM00020106,Atlantic City Electric proposed sale of fossil plants;New
Jersey Ratepayer Advocate. December 2001.
Current market value of generating plants vs. proposed purchase price.
192. Vt. PSB 6545, Vermont Yankee proposed sale; Vermont Department of Public
Service. January 2002.
Comparison of sales price to other nuclear sales. Evaluation of auction design and
implementation. Review of auction manager's valuation of bids.
193. Conn.Siting Council 217,Connecticut Light&Power proposed transmission line
from Plumtree to Norwalk; Connecticut Office of Consumer Counsel.March 2002.
Nature of transmission problems. Potential for conservation and distributed
resources to defer, reduce or avoid transmission investment. CL&P transmission
planning process. Joint testimony with John Plunkett.
Paul L. Chernick• Resource Insight, Incorporated Page 37
194. Vt. PSB 6596, Citizens Utilities rates; Vermont Department of Public Service.
Direct, March 2002; rebuttal, May 2002.
Review of 1991 decision to commit to long-term uneconomic purchase from Hydro
Quebec. Alternatives; role of transmission constraints. Calculation of present
damages from imprudence.
195. Conn. DPUC 01-10-10, United Illuminating rate plan; Connecticut Office of
Consumer Counsel.April 2002
Allocation of excess earnings between shareholders and ratepayers.Asymmetry in
treatment of over- and under-earning.Accelerated amortization of stranded costs.
Effects of power-supply developments on ratepayer risks. Effect of proposed rate
plan on utility risks and required return.
196. Conn. DPUC 01-12-13RE01, Seabrook proposed sale; Connecticut Office of
Consumer Counsel. July 2002
Comparison of sales price to other nuclear sales. Evaluation of auction design and
implementation.Assessment of valuation of purchased-power contracts.
197. Ont. Energy Board RP-2002-0120, review of transmission-system code; Green
Energy Coalition. October 2002.
Cost allocation. Transmission charges. Societal cost-effectiveness. Environmental
externalities.
198. N.J. BPU ER02080507, Jersey Central Power & Light rates; N.J. Division of the
Ratepayer Advocate. Phase I December 2002; Phase II (oral) July 2003.
Prudence of procurement of electrical supply.Documentation of procurement deci-
sions. Comparison of costs for subsidiaries with fixed versus flow-through cost
recovery.
199. Conn. DPUC 03-07-02, CL&P rates;AARP. October 2003
Proposed distribution investments, including prudence of prior management of
distribution system and utility's failure to make investments previously funded in
rates. Cost controls.Application of rate cap. Legislative intent.
200. Conn.DPUC 03-07-01,CL&P transitional standard offer;AARP.November 2003.
Application of rate cap. Legislative intent.
201. Vt. PSB 6596, Vermont Electric Power Company and Green Mountain Power
Northwest Reliability transmission plan; Conservation Law Foundation.December
2003.
Inadequacies of proposed transmission plan. Failure of to perform least-cost
planning. Distributed resources.
Paul L. Chernick• Resource Insight, Incorporated Page 38
202. Ohio PUC 03-2144-EL-ATA,Ohio Edison,Cleveland Electric,and Toledo Edison
Cos. rates and transition charges; Green Mountain Energy Co. February 2004.
Pricing of standard-offer service in competitive markets.Critique of anticompetitive
features of proposed standard-offer supply, including non-bypassable charges.
203. N.Y. PSC 03-G-1671 & 03-5-1672, Consolidated Edison company steam and gas
rates; City of New York. Direct March 2004; rebuttal April 2004; settlement June
2004.
Prudence and cost allocation for the East River Repowering Project. Gas and steam
energy conservation. Opportunities for cogeneration at existing steam plants.
204. N.Y. PSC 04-E-0572, Consolidated Edison rates and performance; City of New
York. Direct, September 2004; rebuttal, October 2004.
Consolidated Edison's role in promoting adequate supply and demand resources.
Integrated resource and T&D planning. Performance-based ratemaking and
streetlighting.
205. Ont. Energy Board RP 2004-0188, cost recovery and DSM for Ontario electric-
distribution utilities; Green Energy Coalition. Exhibit, December 2004.
Differences in ratemaking requirements for customer-side conservation and demand
management versus utility-side efficiency improvements.Recovery of lost revenues
or incentives. Reconciliation mechanism.
206. Mass.DTE 04-65,Cambridge Electric Light Co. streetlighting;City of Cambridge.
Direct, October 2004; supplemental, January 2005.
Calculation of purchase price of street lights by the City of Cambridge.
207. N.Y. PSC 04-W-1221, rates, rules, charges, and regulations of United Water New
Rochelle; Town of Eastchester and City of New Rochelle. Direct, February 2005.
Size and financing of proposed interconnection.Rate design.Water-mains replace-
ment and related cost recovery. Lost and unaccounted-for water.
208. N.Y. PSC 05-M-0090, system-benefits charge; City of New York. Comments,
March 2005.
Assessment and scope of, and potential for,New York system-benefits charges.
209. Md. PSC 9036, Baltimore Gas & Electric rates; Maryland Office of People's
Counsel. Direct,August 2005.
Allocation of costs. Design of rates. Interruptible and firm rates.
Paul L. Chernick• Resource Insight, Incorporated Page 39
210. B.C. UC 3698388, British Columbia Hydro resource-acquisition plan; British
Columbia Sustainable Energy Association and Sierra Club of Canada BC Chapter.
September 2005.
Renewable energy and DSM. Economic tests of cost-effectiveness. Costs avoided
by DSM.
211. Conn.DPUC 05-07-18,financial effect of long-term power contracts;Connecticut
Office of Consumer Counsel. September 2005.
Assessment of effect of DSM, distributed generation, and capacity purchases on
financial condition of utilities.
212. Conn.DPUC 03-07-01 RE03 &03-07-15RE02,incentives for power procurement;
Connecticut Office of Consumer Counsel. Direct, September 2005; Additional,
April 2006.
Utility obligations for generation procurement.Application of standards for utility
incentives.Identification and quantification of effects of timing,load characteristics,
and product definition.
213. Conn.DPUC Docket 05-10-03, Connecticut L&P; time-of-use, interruptible, and
seasonal rates; Connecticut Office of Consumer Counsel.Direct and Supplemental
Testimony February 2006.
Seasonal and time-of-use differentiation of generation,congestion,transmission and
distribution costs; fixed and variable peak-period timing; identification of pricing
seasons and seasonal peak periods; cost-effectiveness of time-of-use rates.
214. Ont. Energy Board Case EB-2005-0520, Union Gas rates; School Energy Coali-
tion. Evidence,April 2006.
Rate design related to splitting commercial rate class into two classes. New break
point, cost allocation, customer charges, commodity rate blocks.
215. Ont.Energy Board EB-2006-0021,Natural-gas demand-side-management generic
issues proceeding; School Energy Coalition. Evidence, June 2006.
Multi-year planning and budgeting;lost-revenue adjustment mechanism;determin-
ing savings for incentives; oversight; program screening.
216. Ind. URC 42943 and 43046, Vectren Energy DSM proceedings; Citizens Action
Coalition. Direct, June 2006.
Rate decoupling and energy-efficiency goals.
217. Penn.PUC 00061346,Duquesne Lighting;Real-time pricing;PennFuture.Direct,
July 2006; surrebuttal August 2006.
Real-time and time-dependent pricing; benefits of time-dependent pricing; appro-
priate metering technology; real-time rate design and customer information
Paul L. Chernick• Resource Insight, Incorporated Page 40
218. Penn. PUC R-000613 66 et al., rate-transition-plan proceedings of Metropolitan
Edison and Pennsylvania Electric;Real-time pricing;PennFuture.Direct,July 2006;
surrebuttal August 2006.
Real-time and time-dependent pricing; appropriate metering technology;real-time
rate design and customer information.
219. Conn. DPUC 06-01-08, Connecticut L&P procurement of power for standard
service and last-resort service; Connecticut Office of Consumer Counsel. Reports
and technical hearings quarterly since September 2006 to October 2013.
Conduct of auction; review of bids; comparison to market prices; selection of
winning bidders.
220. Conn. DPUC 06-01-08, United Illuminating procurement of power for standard
service and last-resort service; Connecticut Office of Consumer Counsel. Reports
and technical hearings quarterly August 2006 to October 2013.
Conduct of auction; review of bids; comparison to market prices; selection of
winning bidders.
221. N.Y.PSC Case No. 06-M-1017,policies,practices,and procedures for utility com-
modity supply service; City of New York. Comments, November and December
2006.
Multi-year contracts, long-term planning, new resources, procurement by utilities
and other entities, cost recovery.
222. Conn.DPUC 06-01-08,procurement of power for standard service and last-resort
service,lessons learned; Connecticut Office Of Consumer Counsel.Comments and
Technical Conferences December 2006 and January 2007.
Sharing of data and sources;benchmark prices;need for predictability,transparency
and adequate review; utility-owned resources; long-term firm contracts.
223. Ohio PUC PUCO 05-1444-GA-UNC,recovery of conservation costs,decoupling,
and rate-adjustment mechanisms for Vectren Energy Delivery of Ohio; Ohio
Consumers' Counsel. February 2007.
Assessing cost-effectiveness of natural-gas energy-efficiency programs.Calculation
of avoided costs. Impact on rates. System benefits of DSM.
224. N.Y. PSC 06-G-1332, Consolidated Edison Rates and Regulations; City of New
York. March 2007.
Gas energy efficiency: benefits to customers, scope of cost-effective programs,
revenue decoupling, shareholder incentives.
Paul L. Chernick• Resource Insight, Incorporated Page 41
225. Alb. EUB 1500878, ATCo Electric rates; Association of Municipal Districts &
Counties and Alberta Federation of Rural Electrical Associations. May 2007.
Direct assignment of distribution costs to street lighting. Cost causation and cost
allocation. Minimum-system and zero-intercept classification.
226. Conn. DPUC 07-04-24, review of capacity contracts under Energy Independence
Act; Connecticut Office of Consumer Counsel. Direct (with Jonathan Wallach),
June 2007.
Assessment of proposed capacity contracts for new combined-cycle, peakers and
DSM. Evaluation of contracts for differences, modeling of energy, capacity and
forward-reserve markets. Corrections of errors in computation of costs,valuation of
energy-price effects of peakers, market-driven expansion plans and retirements,
market response to contracted resource additions, DSM proposal evaluation.
227. N.Y. PSC 07-E-0524, Consolidated Edison electric rates; City of New York. Sep-
tember 2007.
Energy-efficiency planning. Recovery of DSM costs. Decoupling of rates from
sales. Company incentives for DSM.Advanced metering. Resource planning.
228. Man. PUB 136-07, Manitoba Hydro rates; Resource Conservation Manitoba and
Time to Respect Earth's Ecosystem. February 2008.
Revenue allocation, rate design, and demand-side management. Estimation of
marginal costs and export revenues.
229. Mass. EFSB 07-7, DPU 07-58 & -59; proposed Brockton Power Company plant;
Alliance Against Power Plant Location. March 2008
Regional supply and demand conditions.Effects of plant construction and operation
on regional power supply and emissions.
230. Conn. DPUC 08-01-01, peaking generation projects; Connecticut Office of
Consumer Counsel. Direct (with Jonathan Wallach),April 2008.
Assessment of proposed peaking projects.Valuation of peaking capacity.Modeling
of energy margin, forward reserves, other project benefits.
231. Ont. Energy Board 2007-0905, Ontario Power Generation payments; Green
Energy Coalition. April 2008.
Cost of capital for Hydro and nuclear investments.Financial risks of nuclear power.
232. Utah PSC 07-035-93,Rocky Mountain Power Rates;Utah Committee of Consumer
Services. July 2008
Cost allocation and rate design. Cost of service.Correct classification of generation,
transmission, and purchases.
Paul L. Chernick• Resource Insight, Incorporated Page 42
233. Ont. Energy Board 2007-0707, Ontario Power Authority integrated system plan;
Green Energy Coalition, Penimba Institute, and Ontario Sustainable Energy
Association.Evidence(with Jonathan Wallach and Richard Mazzini),August 2008.
Critique of integrated system plan. Resource cost and characteristics; finance cost.
Development of least-cost green-energy portfolio.
234. N.Y. PSC 08-E-0596, Consolidated Edison electric rates; City of New York.
September 2008.
Estimated bills, automated meter reading, and advanced metering.Aggregation of
building data.Targeted DSM program design.Using distributed generation to defer
T&D investments.
235. Conn.DPUC 08-07-01,Integrated resource plan; Connecticut Office of Consumer
Counsel. September 2008.
Integrated resource planning scope and purpose. Review of modeling and assump-
tions. Review of energy efficiency,peakers, demand response,nuclear, and renew-
ables. Structuring of procurement contracts.
236. Man. PUB 2008 MH EIIR, Manitoba Hydro intensive industrial rates; Resource
Conservation Manitoba and Time to Respect Earth's Ecosystem.November 2008.
Marginal costs. Rate design. Time-of-use rates.
237. Md.PSC 9036,Columbia Gas rates;Maryland Office of People's Counsel.January
2009.
Cost allocation and rate design. Critique of cost-of-service studies.
238. Vt. PSB 7440, extension of authority to operate Vermont Yankee; Conservation
Law Foundation and Vermont Public Interest Research Group. Direct, February
2009; Surrebuttal, May 2009.
Adequacy of decommissioning funding. Potential benefits to Vermont of revenue-
sharing provision. Risks to Vermont of underfunding decommissioning fund.
239. N.S. UARB M01439, Nova Scotia Power DSM and cost recovery; Nova Scotia
Consumer Advocate. May 2009.
Recovery of demand-side-management costs and lost revenue.
240. N.S.UARB MO 1496,proposed biomass project;Nova Scotia Consumer Advocate.
June 2009.
Procedural, planning, and risk issues with proposed power-purchase contract.
Biomass price index. Nova Scotia Power's management of other renewable
contracts.
Paul L. Chernick• Resource Insight, Incorporated Page 43
241. Conn. Siting Council 370A, Connecticut Light & Power transmission projects;
Connecticut Office of Consumer Counsel. July 2009. Also filed and presented in
MA EFSB 08-02, February 2010.
Need for transmission projects. Modeling of transmission system. Realistic
modeling of operator responses to contingencies
242. Mass. DPU 09-39, NGrid rates; Mass. Department of Energy Resources. August
2009.
Revenue-decoupling mechanism.Automatic rate adjustments.
243. Utah PSC 09-035-23, Rocky Mountain Power rates; Utah Office of Consumer
Services. Direct, October 2009; rebuttal,November 2009.
Cost-of-service study. Cost allocators for generation,transmission, and substation.
244. Utah PSC 09-03 5-15,Rocky Mountain Power energy-cost-adjustment mechanism;
Utah Office of Consumer Services. Direct, November 2009; surrebuttal, January
2010.
Automatic cost-adjustment mechanisms.Net power costs and related risks.Effects
of energy-cost-adjustment mechanisms on utility performance.
245. Penn. PUC R-2009-2139884, Philadelphia Gas Works energy efficiency and cost
recovery; Philadelphia Gas Works. December 2009.
Avoided gas costs. Recovery of efficiency-program costs and lost revenues. Rate
impacts of DSM.
246. B.C. UC 3698573, British Columbia Hydro rates; British Columbia Sustainable
Energy Association and Sierra Club British Columbia. February 2010.
Rate design and energy efficiency.
247. Ark. PSC 09-084-U, Entergy Arkansas rates; National Audubon Society and
Audubon Arkansas. Direct, February 2010; surrebuttal,April 2010.
Recovery of revenues lost to efficiency programs. Determination of lost revenues.
Incentive and recovery mechanisms.
248. Ark. PSC 10-010-U, Energy efficiency; National Audubon Society and Audubon
Arkansas. Direct, March 2010; reply,April 2010.
Regulatory framework for utility energy-efficiency programs. Fuel-switching pro-
grams. Program administration, oversight, and coordination. Rationale for com-
mercial and industrial efficiency programs. Benefit of energy efficiency.
Paul L. Chernick• Resource Insight, Incorporated Page 44
249. Ark.PSC 08-13 7-U,Generic rate-making;National Audubon Society and Audubon
Arkansas. Direct, March 2010; supplemental, October 2010; reply, October 2010.
Calculation of avoided costs. Recovery of utility energy-efficiency-program costs
and lost revenues. Shareholder incentives for efficiency-program performance.
250. Plymouth, Mass., Superior Court Civil Action No. PLCV2006-00651-B
(Hingham Municipal Lighting Plant v.Gas Recovery Systems LLC et al.),Breach of
agreement; defendants.Affidavit, May 2010.
Contract interpretation. Meaning of capacity measures. Standard practices in capa-
city agreements.Power-pool rules and practices.Power planning and procurement.
251. N.S. UARB M02961, Port Hawkesbury biomass project; Nova Scotia Consumer
Advocate. June 2010.
Least-cost planning and renewable-energy requirements.Feasibility versus alternat-
ives. Unknown or poorly estimated costs.
252. Mass. DPU 10-54,NGrid purchase of long-term power from Cape Wind;Natural
Resources Defense Council et al. July 2010.
Effects of renewable-energy projects on gas and electric market prices. Impacts on
system reliability and peak loads. Importance of PPAs to renewable development.
Effectiveness of proposed contracts as price edges.
253. Md. PSC 9230, Baltimore Gas & Electric rates; Maryland Office of People's
Counsel. Direct, July 2010; rebuttal, surrebuttal,August 2010.
Allocation of gas- and electric-distribution costs. Critique of minimum-system an-
alyses and direct assignment of shared plant.Allocation of environmental compli-
ance costs.Allocation of revenue increases among rate classes.
254. Ont.Energy Board 2010-0008,Ontario Power Generation facilities charges;Green
Energy Coalition. Evidence, August 2010.
Critique of including a return on CWIP in current rates. Setting cost of capital by
business segment.
255. N.S. UARB Matter No. 03454, Heritage Gas rates; Nova Scotia Consumer
Advocate. October 2010.
Cost allocation. Cost of capital. Effect on rates of growth in sales.
256. Man. PUB 17/10, Manitoba Hydro rates; Resource Conservation Manitoba and
Time to Respect Earth's Ecosystem. December 2010.
Revenue-allocation and rate design. DSM program.
Paul L. Chernick• Resource Insight, Incorporated Page 45
257. N.S. UARB M03665, Nova Scotia Power depreciation rates; Nova Scotia
Consumer Advocate. February 2011.
Depreciation and rates.
258. New Orleans City Council UD-08-02,Entergy IRP rules;Alliance for Affordable
Energy. December 2010.
Integrated resource planning: Purpose, screening, cost recovery, and generation
planning.
259. N.S. UARB M03665, depreciation rates of Nova Scotia Power; Nova Scotia
Consumer Advocate. February 2011.
Steam-plant retirement dates,post-retirement use,timing of decommissioning and
removal costs.
260. N.S. UARB M03632, renewable-energy community-based feed-in tariffs; Nova
Scotia Consumer Advocate. March 2011.
Adjustments to estimate of cost-based feed-in tariffs.Rate effects of feed-in tariffs.
261. Mass. EFSB 10-2/DPU 10-131, 10-132; NStar transmission; Town of Sandwich,
Mass. Direct, May 2011; Surrebuttal, June 2011.
Need for new transmission; errors in load forecasting;probability of power outages.
262. Utah PSC 10-03 5-124,Rocky Mountain Power rate case;Utah Office of Consumer
Services. June 2011.
Load data, allocation of generation plants, scrubbers,power purchases,and service
drops. Marginal cost study: inclusion of all load-related transmission projects, cri-
tique of minimum- and zero-intercept methods for distribution. Residential rate
design.
263. N.S. UARB M04104; Nova Scotia Power general rate application; Nova Scotia
Consumer Advocate.August 2011.
Cost allocation: allocation of costs of wind power and substations. Rate design:
marginal-cost-based rates, demand charges, time-of-use rates.
264. N.S. UARB M04175, Load-retention tariff; Nova Scotia Consumer Advocate.
August 2011.
Marginal cost of serving very large industrial electric loads;risk,incentives and rate
design.
265. Ark. PSC 10-101-R, Rulemaking re self-directed energy efficiency for large cus-
tomers; National Audubon Society and Audubon Arkansas. July 2011.
Structuring energy-efficiency programs for large customers.
Paul L. Chernick• Resource Insight, Incorporated Page 46
266. Okla.CC PUD 201100077,current and pending federal regulations and legislation
affecting Oklahoma utilities; Sierra Club. Comments July, October 2011;
presentation July 2011.
Challenges facing Oklahoma coal plants; efficiency, renewable and conventional
resources available to replace existing coal plants; integrated environmental com-
pliance planning.
267. Nevada PUC 11-08019, integrated analysis of resource acquisition, Sierra Club.
Comments, September 2011; hearing, October 2011.
Scoping of integrated review of cost-effectiveness of continued operation of Reid
Gardner 1-3 coal units.
268. La. PSC R-30021, Louisiana integrated-resource-planning rules; Alliance for
Affordable Energy. Comments, October 2011.
Scoping of integrated review of cost-effectiveness of continued operation of Reid
Gardner 1-3 coal units.
269. Okla. CC PUD 201100087, Oklahoma Gas and Electric Company electric rates;
Sierra Club. November 2011.
Resource monitoring and acquisition.Benefits to ratepayers of energy conservation
and renewables. Supply planning
270. Ky. PSC 2011-00375, Kentucky utilities' purchase and construction of power
plants; Sierra Club and National Resources Defense Council. December 2011.
Assessment of resources, especially renewables. Treatment of risk. Treatment of
future environmental costs.
271. N.S. UARB M04819, demand-side-management plan of Efficiency Nova Scotia;
Nova Scotia Consumer Advocate. May 2012.
Avoided costs.Allocation of costs. Reporting of bill effects.
272. Kansas CC 12-GIMX-337-GIV, utility energy-efficiency programs; The Climate
and Energy Project. June 2012.
Cost-benefit tests for energy-efficiency programs. Collaborative program design.
273. N.S. UARB M04862, Port Hawksbury load-retention mechanism; Nova Scotia
Consumer Advocate. June 2012.
Effect on ratepayers of proposed load-retention tariff. Incremental capital costs,
renewable-energy costs, and costs of operating biomass cogeneration plant.
274. Utah PSC 11-03 5-200, Rocky Mountain Power Rates; Utah Office of Consumer
Council. June 2012.
Cost allocation. Estimation of marginal customer costs.
Paul L. Chernick• Resource Insight, Incorporated Page 47
275. Ark. PSC 12-008-U, environmental controls at Southwestern Electric Power
Company's Flint Creek plant; Sierra Club.Direct,June 2012;rebuttal,August 2012;
further, March 2013.
Costs and benefits of environmental retrofit to permit continued operation of coal
plant,versus other options including purchased gas generation,efficiency,and wind.
Fuel-price projections. Need for transmission upgrades.
276. U.S.EPA EPA-R09-OAR-2012-0021,air-quality implementation plan; Sierra Club.
September 2012.
Costs,financing,and rate effects ofApache coal-plant scrubbers.Relative incomes
in service territories of Arizona Coop and other utilities.
277. Arkansas PSC Docket No. 07-016-U;Entergy Arkansas'integrated resource plan;
Audubon Arkansas. Comments, September 2012.
Estimation of future gas prices.Estimation of energy-efficiency potential. Screening
of resource decisions. Wind costs.
278. Vt.PSB 7862,Entergy Nuclear Vermont and Entergy Nuclear Operations petition to
operate Vermont Yankee; Conservation Law Foundation. October 2012.
Effect of continued operation on market prices.Value of revenue-sharing agreement.
Risks of underfunding decommissioning fund.
279. Man.PUB 2012-13 GRA,Manitoba Hydro rates; Green Action Centre.November
2012.
Estimation of marginal costs. Fuel switching.
280. N.S. UARB M05339, Capital Plan of Nova Scotia Power;Nova Scotia Consumer
Advocate. January 2013.
Economic and financial modeling of investment. Treatment of AFUDC.
281. N.S. UARB M05416, South Canoe wind project of Nova Scotia Power; Nova
Scotia Consumer Advocate. January 2013.
Revenue requirements.Allocation of tax benefits. Ratemaking.
282. N.S.UARB 05419;Maritime Link transmission project and related contracts,Nova
Scotia Consumer Advocate and Small Business Advocate. Direct, April 2013;
supplemental (with Seth Parker), November 2013.
Load forecast, including treatment of economy energy sales. Wind power cost
forecasts. Cost effectiveness and risk of proposed project. Opportunities for
improving economics of project.
Paul L. Chernick• Resource Insight, Incorporated Page 48
283. Ont. Energy Board 2012-0451/0433/0074, Enbridge Gas Greater Toronto Area
project; Green Energy Coalition. June 2013, revised August 2013.
Estimating gas pipeline and distribution costs avoidable through gas DSM and
curtailment of electric generation. Integrating DSM and pipeline planning.
284. N.S. UARB 05092, tidal-energy feed-in-tariff rate; Nova Scotia Consumer
Advocate.August 2013.
Purchase rate for test and demonstration projects. Maximizing benefits under rate-
impact caps.Pricing to maximize provincial advantage as a hub for emerging tidal-
power industry.
285. N.S. UARB 05473, Nova Scotia Power 2013 cost-of-service study; Nova Scotia
Consumer Advocate. October 2013.
Cost-allocation and rate design.
286. B.C. UC 3698715 & 3698719; performance-based ratemaking plan for FortisBC
companies; British Columbia Sustainable Energy Association and Sierra Club
British Columbia. Direct (with John Plunkett), December 2013.
Rationale for enhanced gas and electric DSM portfolios. Correction of utility esti-
mates of electric avoided costs. Errors in program screening. Program potential.
Recommended program ramp-up rates.
287. Conn.PURA Docket No. 14-01-01, Connecticut Light and Power Procurement of
Standard Service and Last-Resort Service. July and October 2014.
Proxy for review of bids. Oversight of procurement and selection process.
288. Conn.PURR Docket No. 14-01-02,United Illuminating Procurement of Standard
Service and Last-Resort Service. January,April, July, and October 2014.
Proxy for review of bids. Oversight of procurement and selection process.
289. Man. PUB 2014, need for and alternatives to proposed hydro-electric facilities;
Green Action Centre. Evidence (with Wesley Stevens) February 2014.
Potential for fuel switching, DSM, and wind to meet future demand.
290. Utah PSC 13-035-184, Rocky Mountain Power Rates; Utah Office of Consumer
Services. May 2014.
Class cost allocation.Classification and allocation of generation plant and purchased
power. Principles of cost-causation. Design of backup rates.
291. Minn. PSC E002/GR-13-868, Northern States Power rates; Clean Energy Inter-
venors. Direct, June 2014; rebuttal, July 2014; surrebuttal,August 2014.
Inclining-block residential rate design.Rationale for minimizing customer charges.
Paul L. Chernick• Resource Insight, Incorporated Page 49
292. Cal. PUC Rulemaking 12-06-013, electric rates and rate structures; Natural
Resources Defense Council. September 2014.
Redesigning residential rates to simplify tier structure while maintaining efficiency
and conservation incentives. Effect of marginal price on energy consumption.
Realistic modeling of consumer price response. Benefits of minimizing customer
charges.
293. Md.PSC 9361,proposed merger of PEPCo Holdings into Exelon; Sierra Club and
Chesapeake Climate Action Network.Direct,December 2014; surrebuttal,January
2015.
Effect of proposed merger on Consumer bills,renewable energy,energy efficiency,
and climate goals.
294. N.S. UARB M06514, 2015 capital-expenditure plan of Nova Scotia Power; Nova
Scotia Consumer Advocate. January 2015.
Economic evaluation of proposed projects. Treatment of AFUDC, overheads, and
replacement costs of lost generation. Computation of rate effects of spending plan.
295. Md. PSC 9153 et al., Maryland energy-efficiency programs; Maryland Office of
People's Counsel. January 2015.
Costs avoided by demand-side management. Demand-reduction-induced price
effects.
296. Quebec Regie de V e"nergie R-3 867-2013 phase 1, Gaz Metro cost allocation and
rate structure; ROES. February 2015
Classification of the area-spanning system; minimum system and more realistic
approaches.Allocation of overhead,energy-efficiency,gas-supply,engineering-and-
planning, and billing costs.
297. Conn.PURA Docket No. 15-01-01, Connecticut Light and Power Procurement of
Standard Service and Last-Resort Service. February and July 2015.
Proxy for review of bids. Oversight of procurement and selection process.
298. Conn.PURA Docket No. 15-01-02,United Illuminating Procurement of Standard
Service and Last-Resort Service. February, July, and October 2015.
Proxy for review of bids. Oversight of procurement and selection process.
299. Ky. PSC 2014-00371, Kentucky Utilities electric rates; Sierra Club. March 2015.
Review basis for higher customer charges,including cost allocation.Design of time-
of-day rates.
Paul L. Chernick• Resource Insight, Incorporated Page 50
300. Ky.PSC 2014-00372,Louisville Gas and Electric electric rates; Sierra Club.March
2015.
Review basis for higher customer charges,including cost allocation.Design of time-
of-day rates.
301. Mich. PSC U-17767, DTE Electric Company rates; Michigan Environmental
Council, Sierra Club, and Natural Resource Defense Council. May 2015.
Cost effectiveness of pollution-control retrofits versus retirements. Market prices.
Costs of alternatives.
302. N.S. UARB M06733, supply agreement between Efficiency One and Nova Scotia
Power; Nova Scotia Consumer Advocate. June 2015.
Avoided costs. Cost-effectiveness screening of DSM.Portfolio design.Affordability
and bill effects.
303. Penn.PUC P-2014-2459362,Philadelphia Gas Works DSM,universal-service,and
energy-conservation plans; Philadelphia Gas Works. Direct, May 2015; Rebuttal,
July 2015.
Avoided costs. Recovery of lost margin.
304. Ont.Energy Board EB-2015-0029/0049,2015-2020 DSM Plans Of Enbridge Gas
Distribution and Union Gas, Green Energy Coalition. Evidence July 31, 2015,
Corrected August 12, 2015.
Avoided costs:price mitigation,carbon prices,marginal gas supply costs,avoidable
distribution costs, avoidable upstream costs (including utility-owned pipeline
facilities).
305. PUC Ohio Case No. 14-1693-EL-RDR, AEP Ohio Affiliate purchased-power
agreement, Sierra Club. September 2015.
Economics of proposed PPA,market energy and capacity projections.Risk shifting.
Lack of price stability and reliability benefits. Market viability of PPA units.
306. N.S.UARB Matter No.M06214,NS Power Renewable-to-Retail rate,Nova Scotia
Consumer Advocate. November 2015.
Review of proposed design of rate for third-party sales of renewable energy to retail
customers. Distribution, transmission and generation charges.
307. PUC Texas Docket No.44941,El Paso Electric rates;Energy Freedom Coalition of
America. December 2015.
Cost allocation and rate design. Effect of proposed DG rate on solar customers.
Load shapes of residential customers with and without solar.Problems with demand
charges.
Paul L. Chernick• Resource Insight, Incorporated Page 51
308. N.S.UARB Matter No.M07176,NS Power 2016 Capital Expenditures Plan,Nova
Scotia Consumer Advocate. February 2016.
Economic evaluation of proposed projects,including replacement energy costs and
modeling of equipment failures. Treatment of capitalized overheads and
depreciation cash flow in computation of rate effects of spending plan.
309. Md. PSC Case No. 9406, BGE Application for recovery of Smart Meter costs,
Maryland Office of People's Counsel.Direct February 2016,Rebuttal March 2016,
Surrebuttal March 2016.
Assessment of benefits of Smart Meter programs for energy revenue, load
reductions and price mitigation; capacity load reductions and price mitigation; free
riders and load shifting in peak-time rebate (PTR) program; cost of PTR
participation; effect of load reductions on PJM capacity obligations,capacity prices
and T&D costs.
310. City of Austin TX, Austin Energy 2016 Rate Review, Sierra Club and Public
Citizen. May 2016
Allocation of generation costs. Residential rate design. Geographical rate
differentials. Recognition of coal-plant retirement costs.
311. Manitoba PUB, Manitoba Hydro Cost of Service Methodology Review, Green
Action Centre. June 2016, reply August 2016.
Allocation of generation costs. Identifying generation-related transmission assets.
Treatment of subtransmission. Classification of distribution lines. Allocation of
distribution substations and lines. Customer allocators. Shared service drops.
312. Md. PSC Case No. 9418, PEPCo Application for recovery of Smart Meter costs,
Maryland Office of People's Counsel. Direct July 2016, Rebuttal August 2016,
Surrebuttal September 2016.
Assessment of benefits of Smart Meter programs for energy revenue, load
reductions and price mitigation;load reductions in dynamic-pricing(DP)program;
cost of DP participation; effect of load reductions on PJM capacity obligations,
capacity prices and T&D costs.
313. Md.PSC Case No. 9424,Delmarva P&L Application for recovery of Smart Meter
costs, Maryland Office of People's Counsel. Direct September 2016, Rebuttal
October 2016, Surrebuttal October 2016.
Estimation of effects of Smart Meter programs dynamic pricing (DP),
conservation voltage reduction and an informational program on wholesale
revenues, wholesale prices and avoided costs; estimating load reductions from the
DP program; cost of DP participation; effect of load reductions on PJM capacity
obligations, capacity prices and T&D costs.
Paul L. Chernick• Resource Insight, Incorporated Page 52
314. N.H.PUC Docket No.DE 16-576,Alternative Net Metering Tariffs,Conservation
Law Foundation. Direct October 2016, Reply December 2016.
Framework for evaluating rates for distributed generation. Costs avoided and
imposed by distributed solar. Rate design for distributed generation.
315. Puerto Rico Energy Commission CEPR-AP-2015-0001, Puerto Rico Electric
Power Authority rate proceeding,PR Energy Commission.Report December 2016.
Comprehensive review of structure of electric utility,cost causation,load data,cost
allocation,revenue allocation,marginal costs,retail rate designs,identification and
treatment of customer subsidies, structuring rate riders, and rates for distributed
generation and net metering.
316. N.S.UARB Matter No.M07745,NS Power 2017 Capital Expenditures Plan,Nova
Scotia Consumer Advocate. January 2017.
Computation and presentation of rate effects. Consistency of assumed plant
operation and replacement power costs. Control of total cost of small projects.
Coordination of information-technology investments.Investments in biomass plant
with uncertain future.
317. N.S.UARB Matter No.M07746,NS Power Enterprise Resource Planning project,
Nova Scotia Consumer Advocate. February 2017.
Estimated software project costs. Costs of internal and contractor labor. Affiliate
cost allocation.
318. N.S. UARB Matter No. M07767, NS Power Advanced Metering Infrastructure
projects, Nova Scotia Consumer Advocate. February 2017.
Design and goals of the AMI pilot program. Procurement. Coordination with
information-technology and software projects.
319. Quebec Regie de Pe"nergie R-3867-2013 phase 3A; Gaz Metro estimates of
marginal O&M costs; ROEE. March 2017.
Estimation of one-time, continuing and periodic customer-related operating and
maintenance cost. Costs related to loads and revenues. Dealing with lumpy costs.
320. N.S. UARB Matter No. M07718,NS Power Maritime Link Cost Recovery, Nova
Scotia Consumer Advocate.April 2017.
Usefulness of transmission interconnection prior to operation of the associated
power plant.
321. Mass.DPU 17-05,Eversource Rate Case, Cape Light Compact.Direct April 2017,
Rebuttal May 2017.
Critique of proposed performance-based ratemaking mechanism. Proposal for
improvements.
Paul L. Chernick• Resource Insight, Incorporated Page 53
322. PUCO 16-1852, AEP Ohio Electric Security Plan, Natural Resources Defense
Council. May 2017.
Residential customer charge. Cost causation.Effect of rate design on consumption.
323. Iowa Utilities Board RPU-2017-0001,Interstate Power and Light rate case,Natural
Resources Defense Council. Direct August 2017, Reply September 2017.
Critique of proposed demand-charge pilot rates for residential and small commercial
customers.Defects of demand rates and shortcomings of IPL experimental proposal
design.
324. N.S. UARB Matter No. M08087, NS Power 2017 Load Forecast, Nova Scotia
Consumer Advocate. Direct August 2017.
Review of forecast methodology,including extrapolation of drivers of commercial
load from US national data; treatment of non-firm and competitive loads; behind-
the-meter generation and controlling peak-load growth.
325. Quebec Regie de Pe"nergie R-3867-2013 phase 3B; Gaz Metro line-extension
policy; ROES. September 2017.
The costs of adding new load. Estimating the durability of revenues from line
extensions.
326. Mass.EFSB 17-02;Eversource proposed Hudson-Sudbury transmission line;Town
of Sudbury. October 2017.
Accuracy of ISO New England regional load forecasts. Potential for distributed
solar, storage and demand response.
327. Manitoba PUB, Manitoba 2017/18 & 2018/19 General Rate Application; Green
Action Coalition. October 2017.
Marginal costs.Rate design.Affordability rate design for low-income and electric-
heating customers. Design of residential inclining blocks. Problems with demand
charges and demand ratchets. Cost-of-service study improvements.
328. N.S. UARB Matter No. M083 83, NS Power 2018 Annually Adjusted Rates;
Consumer Advocate. January 2018.
Projection of incremental dispatch cost. Computing administrative charges.
Methodological issues.
Paul L. Chernick• Resource Insight, Incorporated Page 54
329. N.S. UARB Matter No. M08349, NS Power's Advanced Metering Infrastructure
Proposal; Consumer Advocate. January 2018.
Estimation of AMI benefits: load balancing among feeders, critical peak pricing,
avoided costs of meters for distributed generation. NS Power's claims of benefits
from accounting credits(AFUDC,overheads,and converting write-offs to reduced
revenue) and shifting costs to customers (earlier billing, higher recorded usage).
Realistic AMI meter life. Excessive charge for customers who opt out of AMI.
330. N.S. UARB Matter No. M08350, NS Power 2018 Annual Capital Expenditures
Plan; Consumer Advocate. February 2018.
Overlap between ACE projects and AMI project. Hydro project planning and
valuation of lost hydro energy output.
331. Conn. PURR Docket No. 08-01-01 RE05, Proposed Amendment to Peaker
Contracts; Connecticut Consumers Counsel. May 2018.
Dividing increased revenues from ISO-NE's Pay-for-Performance mechanism
between contract generators and ratepayers.
332. Kansas CC Docket No. 18-WSEE-328-RTS,Westar Rate Case; Sierra Club.Direct
June 2018. Rebuttal June 2018. Supplement July 2018.
Costs and benefits of running Westar coal plants. Costs of renewables and other
alternatives. Recommendation regarding planning, coal retirement schedule, and
acquisition of leased capacity.
333. Cal. PUC Application 17-09-006; Pacific Gas and Electric Gas Cost Allocation
Proceeding; Small Business Utility Advocates. Direct June 2018.
Allocation of gas distribution system costs.Allocation of costs of energy-efficiency
programs.
334. N.S. UARB Matter No. M08670, NS Power 2018 Load Forecast, Nova Scotia
Consumer Advocate. Direct July 2018.
Review of forecast methodology, including treatment of future energy-efficiency
programs, treatment of third-party supply and behind-the-meter generation.
335. Iowa Utilities Board RPU-2018-0003,MidAmerican Energy Request forApproval
of Ratemaking Principles for Wind XII; Sierra Club. Direct August 2018.
Cost and benefits of continued operation of six MidAmerican coal-fired units.
336. Cal. PUC A.18-02-016, 03-001, 03-002; 2018 Energy Storage Plans; Small
Business Utility Advocates. Direct, Rebuttal and Supplement, August 2018.
Reliance on substation-sited storage.Need for increased emphasis on customer-sited
and shared storage. Maximizing benefits, total and for small business. Oversized
SDG&E proposed projects. Cost recovery. Storage technology diversity.
Paul L. Chernick• Resource Insight, Incorporated Page 55
337. La.PSC U-34794; Cleco Corp Purchase of NRG Assets and Contracts;Sierra Club.
Direct, September 2018.
Economics of NRG generation resources, Cleco Power coal plants and wholesale
sales contracts. Risks of the proposed transaction.
338. Cal. PUC A.18-11-005; Southern California Gas Demand-Response Proposal;
Small Business Utility Advocates. Direct March 2019, Rebuttal April 2019.
Potential benefits of gas demand response and SoCalGas failure to identify potential
benefits from its programs. Program design. Cost allocation.
339. Cal. PUC A.18-11-003; Pacific Gas & Electric Electric Vehicle Rate; Small
Business Utility Advocates. Direct April 2019, Rebuttal May 2019.
Critique of subscription demand charge. Time-of-use periods. Outreach to small
business. Time-of-use price differentials.
340. Cal. PUC A.18-07-024; Southern California Gas and San Diego Gas & Electric
Triennial Cost Allocation Proceeding; Small Business Utility Advocates. Direct
April 2019.
Core commercial declining blocks. Computation of customer charges. Embedded
versus marginal cost allocation. Marginal cost computation. Allocation of self-
generation incentives.
341. Vt. PUC Case No. 19-0397-PET; Screening Values for Energy-Efficiency
Measures; Conservation Law Foundation. Direct May 2019.
Conceptual basis for including price-suppression benefits to consumers.Avoided
T&D costs. Avoided externalities with a renewable energy standard. Risk
mitigation.
342. N.S.UARB Matter No. M09096; EfficiencyOne Application for 2020-2022 DSM
Plan; Consumer Advocate. May 2019
Evaluate NS Power critique of EfficiencyOne proposal.Comparability of efficiency
budgets.Affordability. Energy-efficiency programs and resource planning.
343.
Paul L. Chernick• Resource Insight, Incorporated Page 56
ACRONYMS
R• AND
INITIALISMS
APS Alleghany Power System LRAM Lost-Revenue-Adjustment Mechanism
ASLB Atomic Safety and Licensing Board NARUC National Association of Regulatory
BEP Board of Environmental Protection Utility Commissioners
BPU Board of Public Utilities NEPOOL New England Power Pool
BRC Board of Regulatory Commissioners NRC Nuclear Regulatory Commission
cc Corporation Commission OCA Office of Consumer Advocate
CMP Central Maine Power PSB Public Service Board
DER Department of Environmental PBR Performance-based Regulation
Regulation PSC Public Service Commission
DPS Department of Public Service PUC Public Utility Commission
DQE Duquesne Light PUB Public Utilities Board
DPUC Department of Public Utilities Control PURA Public Utility Regulatory Authority
DSM Demand-Side Management PURPA Public Utility Regulatory Policy Act
DTE Department of Telecommunications ROES Regroupement des organismes
and Energy environnementaux en energie
EAB Environmental Assessment Board SCC State Corporation Commission
EFSB Energy Facilities Siting Board UARB Utility and Review Board
EFSC Energy Facilities Siting Council USAEE U.S. Association of Energy Economists
EUB Energy and Utilities Board Uc Utilities Commission
FERC Federal Energy Regulatory URC Utility Regulatory Commission
Commission UTC Utilities and Transportation
ISO Independent System Operator Commission
0
N
co
co
U
J
Paul L. Chernick• Resource Insight, Incorporated Page 57
pp till 0 3 2 019
APPLICATTON FOR APPOINTMENT
FOR BOARD/COMMITTEE MEMBERSHIP
IL
Board/Committee of Interest: 1 1."4 J�hry
i..Cdt UV
3.
' 4,,
Would you consider another Committee:
��,
For how lon should we keep your application on file? � i�n«��+c
'9
Full Name: 1 Qk4 A4t% R"cc Nickname#
Preferred Title(please cirole) ./]ti&s./Other.
Home Address: ZIP. ot� 2.0
Length of Residence in Lexington: KA-L3
I T L%A c& v% LoJba r&+-o r Occupation: ap�c�^n%49%� sv*-��
Work Address: Ltt ' M� ��..�{�1
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Phone: Home Work Fax
cell
5,mail: Primary: Secondary:
If you currently serve on a Board or Committee,please identify:
Special Training,Interests, Qualifications# � " flk%vr k
-q e*y OVAA I 4" COCO%40"
$4 CAX 4efr 4tit Aro
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Have you been asked,by a Committee to become a member?,..Y'.C4
How did you hear about the Committee? W j&.sa �.as-o-t
V
Please attach a current resume,if possible. Add any comments below or on a separate,page,
i ature: .0 AL 6 /3111
ggn Date:
9G:qc*.z� 6Goz/c/unr
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Discuss Potential Special Fall Town Meeting and Goal Setting Dates
PRESENTER: ITEM
NUMBER:
Jim Malloy, Town Manager
I.16
SUMMARY:
We've previously discussed a Fall Special Town Meeting date of Oct 28 based on the Police Station project
and the timing for a debt exclusion vote in early December. However, given the current schedule for the Police
Station as being a Spring 2020 project, the Town Meeting could be pushed back a few weeks into mid-
November(similar to 2018)which would provide some additional time for any financial articles that involve the
tax rate setting process. At this time the only certain items for the Town Meeting are the 7 Hartwell and 186
Bedford rezoning articles and any potential finance articles.
SUGGESTED MOTION:
No motion is necessary but general consensus on moving the Town Meeting date into mid-November would
be helpful for planning purposes.
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 9:10 P.M.
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Update Regarding Planning Department
PRESENTER: ITEM
NUMBER:
Doug Lucente, Chair
I.17
SUMMARY:
At the May 20, 2019 meeting, the Board of Selectmen discussed the operation of the Planning Department and
suggested the Board of Selectmen and Planning Board Chair/Vice Chairs meet. Doug Lucente will provide a
status and an update on next steps for Board discussion.
SUGGESTED MOTION:
FOLLOW-UP:
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019 9:20 p.m.
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Water and Sewer Commitments
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
C.1
SUMMARY:
Water and Sewer Commitment May 2019 Cycle 9 Billing $ 280,221.25
Water and S ewer Commitment May 2019 Finals $ 4,056.54
SUGGESTED MOTION:
Motion to approve the above May Water and Sewer Commitments for the May 2019 Cycle 9 Billing in the
amount of$280,221.25 and Water and Sewer Committment for May 2019 Finals in the amount of$4,056.54.
FOLLOW-UP:
Treasurer/ Collector
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019
ATTACHMENTS:
Description Type
D W&S May 201..9 C�yde 9 an .l.'"'in als (A.Wer VIlerrio
Departments o ub�lic works
1175 Town of Lexington
SewerWater and Enterprise Funds
FISCAL YEAR 2,019
MAY 20,19 Cycle 9 Alin
TPTAL
MAY 2019
FEE FOR BEDFORD 5,311.28 311.28
TOTAL $ 280,?221.25 2800221.25,
To the Collector of Revenue for the Town of Lexington:
You are hereby authorized and required to levy and collect f the persons named
ire the list water/sewer charged herewith committed to you and each one of his/her
respective portion herein set down to the sum total of'such list. Said sump being:
h i re ars an- 22
tho',usatzd' t, i, tzd' d"it,(t,,ent.y o'ne d),11 �"f' o(,)
And pay the same, into the treasury of the Town of Lexington
and to exercise the powers conferred y law in regard thereto,
BOARD OF SELECTMEN 89
DIRECTOR OF PUBLIC WORKS
Treasurer/Col l r, Director of'Public li works, Water/Sewer Billing
Department of Public Works
Town, Lexington
Ills
...
. Water and Sewer Enterprise Funds
1
FISCAL YEAR 2019
N.'11
FINALS GRAND TOTALS
MA 21 9
WATER $21288-52 $2r288.52
SEWER $ ,7 . 2 1,7 . 2
TOTAL:,. $4,056-54 $41,056.54
To the Collector f Revenue for the Town of Lexington:
You are hereby authorizedn required to levy and collect of the persons named
the list of water,/sewer , r � � r /her
resp�ective portion herein set down of the sum total of such list. Said sumbeing:
f I
our thousandfifty six doQrs and541iool
And pay the same into the treasury of the Town of Lexington
and'. to exercisethe powers conferred by law in regard thereto.
el
DIRECT ECT -R OF PUBLIC WORKS BOARD OF SELECTMEN 2 1
Treasurer/Collector, Director of Public Works, Water/Sewer Billing
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Water and Sewer Adjustment
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
C.2
SUMMARY:
Water& Sewer Adjustment as recommended by W S AB 6/27/19 ($ 3,215.20)
SUGGESTED MOTION:
Motion to approve the above Water& Sewer adjustment recommended by W S AB in the amount of$3,
215.20.
FOLLOW-UP:
Treasurer/ Collector
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019
ATTACHMENTS:
Description Type
FY2020
It7s ADJUSTMENTS TO WATER/SEWER
AS RECOMMENDED BY THE WATER AND SEWER ABATEMENT BOARD
PAGE I OF 1
'WSAB JUNE 27,2019 BOS JUILY 8p 2019
Apt t Fr,
N
W1
45-84
.............
n 7nrl PA A MIn n 019 Tiodet leak
",0300844300 325�ljnc(flriStreq ($7 )_ 7($2,4679,36), ($3,215.20) 941737 201
76 ...... ....................
.............. 77..................................... ........... ..............
.... .................... ............. ......
.......... ........... ...............
... ........................... .................................... ........ ...................
............ .......................
......................
($745 ($2,469.36) ($3,215.20)
It is the recommendotibn of the'Woter and Sewer Abate,e Board that the Town Collector be authorized to waive interest,that has accrued on the bills inclQded
herein,unless stated here otherwise,from the due date of the,bill until caler-idor days after the date of written notification to applicant of the Selectmen's action.
.......... ........ ...... ........-----
THE SUm SET AGAINST'rHE ABOVE ACCOUNTS IS tiEREBYADJUSTED,
'WATER SEWER TOTAL
ACTING DIRECTOR OF PUBLIC WO,RKS BOARD OF SELECTMEN' 7/8/19
AGENDA ITEM SUMMARY
LEXINGTON BOARD OF SELECTMEN MEETING
AGENDA ITEM TITLE:
Approve One-Day Liquor License
PRESENTER:
ITEM
NUMBER:
Doug Luc ente, Chair
C.3
SUMMARY:
The Lexington Players (EMACT)have requested a one-day liquor license to serve beer and wine for the
purpose of their Community Theater Awards Gala to be held at Cary Memorial Building, 1605 Massachusetts
Avenue, on Saturday, August 24, 2019. The beer and wine will be served from 5:00 p.m. to 11:00 p.m.
SUGGESTED MOTION:
Move to approve the consent.
FOLLOW-UP:
Selectmen's O ffic e
DATE AND APPROXIMATE TIME ON AGENDA:
7/8/2019
ATTACHMENTS:
Description Type
► j r
f f
TOWN OF LEXINGTON J U 1.- 0 2 2 019
XT
yy, 6
.n {{y�yy gg` SELE
tTME ' ' S d"f#'i4e E 9
� V1 c O
FICE
A 1C"ATION FOR
UNE
-SAYLIVULI.CENSE �, 0,
The Board and of Selectmen{Local Licensing Authority)may issue One-Day LigUor Licenses ltor the sale arrc i"or service ol,\�inn
and malt beverages to any enterprise:all alcoholic be,era�es may be iS'rUed only to non-profit organizations. As required by
the. BCC, Liquor for use at a one-day lic-lUor license event must be purchased from a license vN;°h lesal er.Please fill in this
fiomr completely and return to the electrrren"s Office along with a check for$25.00 made payable to the Town of Lexington.
14
BUSINESS/Ft NIDRAISING ORGtxNIZATION i_- 144C Lip Flei
A tj yegs
CONTACT NAME AND NUMBER-. 6Q �J'6 A e S
ADDRESS FORMAILIN`G: t-e4ile 6&CIFS
EMAIL, ADDRESS-.
"FITLETURPOSE OF EVEN]': 00 M A411;VA t/ Tltiq�r AcJa v-d 5 4
MCM ricti 6ui Id.I
LC C�� TI I` AND ADORE0 6-�Z ML
"�Iq 14 5 5 �'�' � (OctV1
DATE OF FUNCTION.,- 4u q 2-4 2-of q
TIMES OF FUNC110N.
TYPE OF L�IQUOR TO BE SERVED.- K tK e- a&ic� S 04�4 rt
DATE AND TIME THEN LIQUOR DELIVERED: �� .�- �' �?`� � --F ?, 1 q
:R..*"' T. N D J4. .k R...If i .E �..R.�N L� U O !..RE M O T E i....f /1"00 /1 r � �`r"�i f �. \�
Y
INFORMATION:ADDITIONAL L tc.e_pu_ r rUtCcp_
------------
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