ISO New England (ISO-NE) said July 10 that its recently published June 2015 update to the regional system plan project list lists 13 new transmission projects and 25 projects placed into service since a March 2015 update, including 13 projects completed for Central Maine Power’s Maine power reliability program project.
According to the June 2015 update, CMP‘s projects that changed from “under construction” to “in-service” pertaining to its MPRP include:
· The project that involved adding a new 345-kV transmission line (3024) between Albion Rd and Coopers Mills
· The project that involved adding a new 345-kV transmission line (3025) between Coopers Mills and Larabee Road
· The project that involved adding a new 115-kV transmission line (254) between Orrington and Coopers Mills
· The project that involved adding a new Albion Road 345/115-kV substation interconnecting lines 3023, 3024, 67, 254, 257 and 258 between the Orrington, Coopers Mills and Detroit substations
· The project that involved adding a new Coopers Mills 345/115-kV substation interconnecting lines 3024, 3025, 60, 254, 257 and 258 between the Albion Road, Larrabee Road and Browns Crossing substations
ISO-NE said in its July 10 ISO Newswire that since 2002, a cumulative total of 634 project components representing an investment of about $7.2 billion have been placed into service to help ensure that the region’s transmission system continues to reliably and efficiently move wholesale electricity across New England.
As of last month, the update presentation lists 210 active projects across all six New England states, including 37 projects under construction, 131 planned projects, and 42 proposed projects.
The estimated cost of active future projects through 2019 totals about $4.8 billion, ISO-NE added.
According to the June 2015 update, projects that changed from “planned” to “under construction” from March to June include:
· Eversource Energy‘s project in New Hampshire that involves the Eagle substation and adding, for instance, 345-kV circuit breakers and 115-kV circuit breakers. It is part of the Southern New Hampshire Solution project. The projected in-service date is December 2016, and the estimated cost is $59.7 million
· National Grid USA’s project in Massachusetts that involves the Harrison Blvd substation A94 Tap. It is part of the Auburn Area Transmission System Upgrades project. The projected in-service date is December 2015, and the estimated cost is $3 million
· Eversource’s K St to Dewar/Andrew Sq Cable Project in Massachusetts, which involves installing one 115-kV breaker to a separate K St 345B bus connection from line 483-525. The projected in-service date is May 2016, and the estimated cost is $659,000
Projects that changed from “proposed” to “under construction” from March to June include Eversource’s project in Massachusetts, which involves reconductoring the 345-kV underground cable (372) between the Mystic and Kingston substations. The projected in-service date is December 2015, and the estimated cost is $15.1 million.
Projects that changed from “proposed” to “planned” from March to June include Eversource’s Blair Pond Substation Project in Massachusetts, which involves building the new 115-kV Blair Pond substation. The projected in-service date is June 2016, and the estimated cost is $32 million.
New projects in June include:
· Norwood Electric Light Department’s “planned” project in Massachusetts involving rehabilitating 115-kV lines 447-508 and 447-509 from the Eversource tap in Sharon to Dean St. #496 substation in Norwood. The projected in-service date is March 2017, and the estimated cost is $12.7 million
· Emera Maine’s “proposed” Queue Position 397 project in Maine, which involves adding a tap to the existing Bull Hill switching station. The projected in-service date is December 2015
· Hudson Light and Power’s “proposed” project in Massachusetts that involves building a new 115-kV line from the Sudbury Station 342 substation to the Hudson substation. It is part of the Greater Boston — Western Suburbs project. The projected in-service date is May 2019, and the estimated cost is $5 million
Projects that changed from “under construction” to “in-service” from March to June include:
· National Grid‘s project that involved bus upgrades at the Riverside substation. It is part of the New Highland Park Substation Project in Rhode Island. The estimated cost was $340,000
· National Grid’s project in Rhode Island that involved West Farnum substation 345-kV additions. It is part of the New England East-West Solution, or NEEWS effort, (Rhode Island Reliability Project)
· Eversource’s project in Massachusetts that involved adding a new 345-kV series breaker to the existing 106 breaker at West Medway. It is part of the NEEWS effort. The estimated cost is $3.2 million
· Eversource’s project in New Hampshire that involved rebuilding the 115-kV line K165, W157 tap (H123 renamed) — Eagle-Power St. It is part of the Southern New Hampshire Solution project. The estimated cost is $5.4 million
Projects that changed from “concept” to “canceled” from March to June include:
· Vermont Electric Power Co.’s (VELCO) project that involved installing a 115/46-kV transformer at West Rutland between breakers K30 and K34 in Vermont. It was part of the VELCO LSP – West Rutland Substation project
· National Grid’s project that involved a new 115-kV circuit between Somerset and Brayton Point in Massachusetts. It was part of the Greater Rhode Island Transmission Reinforcements project
· VELCO’s 425 MW HVDC Tie HQ to VELCO’s 345-kV New Haven substation in Vermont
ISO-NE said on July 10 that improving the movement of electricity across the region and into areas of limited transmission and high demand:
· Allows more competition among generators, reduces congestion charges in the energy market, reduces the need for expensive generator reliability agreements, and reduces out-of-market generator dispatch payments
· Allows older, more expensive generators to retire, making way for cleaner, more efficient, and less expensive resources
Noting that regional energy trends can affect transmission needs, ISO-NE said that from 2019 to 2024, state-sponsored energy efficiency programs are forecast to:
· Save the region about 9,696 GWh of energy — with an average annual savings of 1,616 GWh — keeping regional load growth essentially flat
· Shave about 1,274 MW of peak demand, with an average annual peak reduction of about 212 MW
Energy efficiency savings, when coupled with new generators and other transmission upgrades, may allow the region to defer certain transmission projects deemed necessary to address reliability needs, the ISO said.
Solar photovoltaic (PV) resources and other forms of distributed generation may also one day be able to alleviate or prevent constraints in regional power system transmission or distribution, and reduce or eliminate the need to install new transmission or distribution facilities. ISO-NE also said that about 2,500 MW of nameplate PV capacity – the maximum amount of electricity a generator is capable of producing – is anticipated in the region by the end of 2024.
Among other things, the ISO said that market resource alternatives (MRAs), such as new generators or demand response resources, may in some cases be able to help alleviate transmission needs. ISO-NE said that it has performed MRA analysis on select portions of the system to help signal to developers and stakeholders where those opportunities exist.