St Albans Substation Project objective St. Albans substation - - PDF document

Vermont System Planning Committee Geotargeting Su bcom mittee March 28,2017 Meeting Summary

ln Attendance: Gillian Eaton, Vermont Energy lnvestment Corporation (VEIC) Deena Frankel, Vermont Electric Power Company (VELCO) Kim Jones, Green Mountain Power (GMP) Al St. Peter, Vermont Public Service Department (PSD) Riley Allen, PSD Mellissa Bailey, Vermont Public Power Supply Authority Mike Beaulieu, Vermont Electric Cooperative (VEC) Cyril Brunner, VEC Nathaniel Vandal, Green Peak Solar David Westman, VEIC Hantz Presume, VELCO Shana Louiselle, VELCO Steve Litkovitz, GMP John Woodward, PSD, Chair Bill Powell, Washington Electric Cooperative Asenda: Review and approval of the January 10,2017 meeting minutes NTA screening of St. Albans Asset Condition Mitigation Project Check-in on Hinesburg reliability plan Continue discussion ofthe project review spreadsheet Schedule for annual project review Next meeting date Discussions:

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Review and approval of the January 10,2017, meeting minutes

• The most recent draft of the minutes has been circulated. Absent further comment, the

minutes will be considered approved and posted to the VSPC website.

NTA screening of St. Albans Asset Condition Mitigation Project

• The purpose of this project is to address asset condition. The VELCO St. Albans

substation was constructed in L958. Asset conditions include cracking concrete foundations, rusted control house, and circuit breakers that are beyond their useful

• lives. The presently existing two transformers will be replaced with a single transformer

that is already in VELCO's inventory.

Exhibit Petitioner DEB-9

VSPC Geota rgeting Subcommittee

Meeting Minutes March 28,2017

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Page 2

• This project does not address load concerns. There will be no addition of capacity to the

facility.

• The radialtap line to the substation will be substantially rebuilt with L2 structures

requiring replacement due to poor condition.

• The tap station, which connects the Highgate to Georgia line to the radial tap line, will

get a new steel structure and motor operated switch.

• VELCO subjected this project to NTA screening. Because the project is maintenance

related, it screens out of further NTA analysis.

• This project and associated NTA analysis will be placed on the schedule of the April 2017

VSPC quarterly meeting.

Check-in on Hinesburg reliability plan

• On March 3,20t7, the PSB issued an order approving the VSPC's October 2016

recommendations on geotargeted energy efficiency and the need for reliability plans in accordance with the Screening Framework and Guidelines. Based on GMP's Hinesburg Reliability Plan, the PSB found that the Hinesburg reliability issue cannot be solved with geotargeting or standard-offer resources above the cap.

• The new VEC Hinesburg substation, of which GMP would have feeder positions, is now

planned for construction in approximately 2021.

• GMP is presently seeking property for the location of a battery energy storage system

(BESS).

• With the BESS in place, a gravel pit/rock crushing facility, presently powered by a diesel

generator, may come onto gr¡d. This energy transformation project may be eligible for Tier 3 credit.

• The BESS will help address the uncertainty of load growth in the Hinesburg area.

Continue discussion ofthe project review spreadsheet

• At the previous GT subcommittee meeting, we addressed whether the spreadsheet tool

presently in use continues to be appropriate. ls this the best toolfor all utilities? Should it be revised or replaced?

• A blank spreadsheet file is available on the VSPC website. The first page provides an
• verview of all projects under consideration. A goal for the next GT subcommittee

meeting would be for all utilities to complete this overview. A question was raised that,

if there is no load growth, is it necessary to provide the further information required in

the so-called Phase 1 tab, i.e., the follow-up detailed spreadsheet? Consensus was not reached on this question, but can be revisited at the next GT subcommittee meeting.

• The question was raised as to whether this process captures distribution related issues

that may be subject to analysis for resolution by standard offer generation. The

consensus is that the vast majority of distribution projects in Vermont are asset related and not avoidable by non-wires alternatives.

VSPC Geotargeting Subcommittee

Meeting Minutes March 28,2017

Page 3

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Schedule for annual project review

• A tentative date of May 23'd f or project review has been set

Next meeting date

• The next meeting has been tentatively set for May 23, 2O!7.The time and location is to

be determined.

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St Albans Substation Project objective

• St. Albans substation constructed in 1958

Served by a radial transmission line tap Contains two 115134.5 kV transformers

Project will mitigate asset condition concerns

Severe cracking on concrete foundations Obsolete and degraded protection equipment Control house rusted and damaged

115 kV circuit switchers below short circuit level

34.5 kV oil circuit breakers s¡gnificantly beyond useful life

Also will make some improvements

Bring design to current standards Replace two transformers with one transformer

Preliminarylconceptual cost estimate is $S.1M

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• St. Af bans Project scope of work

Substation

Tap station

. lnstall new steel structure and motor

• perated switch inside station

. lnstall SCADA remote terminal unit

(Rru)

Tap line

. Remove existing line switch . 16 structures have been evaluated

and 12 structures require replacement due to condition

• 5 structures are also impacted by

work at substation and tap station

. New control building . New protection and controls . Replace 1 1skv circuit switcher with

1 1skv breaker and disconnect

. Replace two 115134.5kV

transformers with one existing

1 1 5134. skv transformer

. lnstall oil containment system . Replace 34.5kV oil circuit breaker

with new vacuum breaker

. lnstall new 115kV and 34.5kV

instrument voltage transformers

. New 34.5kV box structure and

switches

NTA Screening

ldentifv the proposed upgrade: St Albans Asset Condltion Miti

Proiect

Date of analysis:

gation

201

March 14s

• 1. Does the project meet one of the followingcriteria that definetheterm

*impracticable" (check all thot opply)?

Needed for a redundantsupplyto a radial load; or

M a i nten a nce-related, a d d ressing asset co n d itio n, operatio ns, o r safety; o r Ad d ressi ng tra nsmission performa nce, e.g., ad d itio n of h igh-speed

protection or a switch to sectionalize a line; or

Needed to address stabilityorshort circuit problems;lor

• ther technical reason why NTAs are impracticable..A ttach detoiled

justificøtion that must be reviewed by the [/SPC.

If ony hox ubove is checked, proje* screens out of full NTA anolysis.

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2- What is the proposed transrnission project's need date?

If the needfor the project is åosed on existing or imminent reliahility criteríø violations (i.e., orîsing within one year åased on the contrallíng load foretastJ, prøjecf screens out of futt IV?ä anøl¡æls

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December 2018

NTA Screen i ng (continued)

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VELCO

Date Signature A

H

Print name & title Company

March 14ü. ZO17

Sign and date thisform. This analysis performed by:

• 3. Could elimination or deferral of all or part of the upgrade be accomplished by a

25% or smaller load reduction or off-settinggeneration of the same magnitude? {See note.)

If ono," project scre€rs out of full NTA analysis. E Yes

ENo

• 4. ls the likely reduction in costs from the potential elimination or deferral of allor

pa rt of th e u pgra d e greater th a n $2.5 m i ll i"o_n* (Se e note. )

lf *no," praject screensout of full NTA analysis. E Yes ENo

NTA Screening (notes for tines 3 and 4)

NTA Screening Form

Notes, examples and descriptions

Line 3

line 4

Period 1-3 years

5 years 10 years

Non-transmission alternatives should be considered if the project can be altered

• r deferred with load reductions or off-settinggeneration, accordingto the

sched ule below, of existing peak load of the affected area at the time of the need

for the preferred transmission alternatives. This schedule recognizes that deployrnentof a load reduction program in a specific area takestirne to organize

and implement.Therefore,thefollowingassumptions includingtime and accrued load reduction should be considered when examiningthe load reduction:

Magnitude of load redustion and/or off-setting generation

1596 of peak load 2096 of peak load

25% of peak load

The S2.5 million is in year ?:OL? dollars and is adjusted for escalation in furure yeärs usingthe HandyWhitman transmission cost index. This threshold does not

accountforthe expected costs of the NTAs, but ratheronlyincludesthe expected

savings to the cost of the transmission project,