Electric Rates

Current Purchased Power Adjustment (PPA) & Transmission Cost Adjustment (TCA) Rates

Effective with billings on and after July 1, 2017, the Purchase Power Adjustment (PPA) and the Transmission Cost Adjustment (TCA) change to reflect a slight change in pricing from our suppler.

The new PPA for most customers is increased from $.00307 to $0.00 cents per kilowatt-hour.
The new TCA for most customers is $0.00393 cents per kilowatt-hour.

If you have any questions on the PPA or the TCA charges, you can call one of our Customer Care Representatives at 860.446.4000.

Residential Electric Rate Schedule (Rate: RS)

Applicable to the entire electrical requirements in a single-family dwelling and appurtenances, or in an individual apartment, or in common use areas of apartment buildings or condominium buildings where residential usage exceeds 50% of monthly metered energy. The net metering rider is also applicable to any customer with approved self-generation.

Available throughout the service area from existing facilities of adequate character and capacity.

Monthly Rate is the sum of Customer Charge, Energy Charge, any Purchased Power Adjustment, and any Transmission Cost Adjustment:

  • Customer Charge: $11.50 per month
  • Winter Energy Charges: 13.074 cents per kWh
  • Summer Energy Charges: 13.774 cents per kWh

Where revenues are subject to 8.5% GRT

  • Customer Charge: $11.71 per month
  • Winter Energy Charges: 13.165 cents per kWh
  • Summer Energy Charges: 13.865 cents per kWh

Purchased Power Adjustment: An adjustment will be applied to every kWh sold to reflect any difference between the base power costs included in rates and the actual power costs (not including transmission) billed to the Department for its load.

TRANSMISSION COST ADJUSTMENT: An adjustment will be applied to every kWh sold to reflect any difference between the base transmission costs included in rates and the actual transmission costs charged to the Department.

SEASONAL DEFINITION: Winter refers to all billings between October 1 and May 31. Summer refers to all billings between June 1 and September 30.

MULTIPLE FAMILY DWELLINGS: may be served hereunder by increasing the single family dwelling Customer Charge by one-half for each additional family unit served, regardless of occupancy.

TERM OF CONTRACT: is for one year and thereafter until termination.

RULES AND REGULATIONS: of the Department governing service hereunder as to application for service, character of service, connection, seasonal service, disconnection, reconnection, termination, etc., are on file in the Department.

EFFECTIVE DATE: With all billings on and after October 1, 2008, and thereafter until revised.

Small General Service Electric Rate Schedule (Rate: SGS)

Applicable to the entire electrical requirements for light, heat, and power on the Customer’s premises for small commercial customers for which no other rate schedule is applicable. The net metering rider is also applicable to any customer on this rate with approved self-generation.

Available throughout the service area from existing facilities of adequate character and capacity.

Character of Service: Delivery and metering at one standard secondary distribution voltage.

Monthly Rate is the sum of Customer Charge, Energy Charge, Demand Charge, any Purchased Power Adjustment, and any Transmission Cost Adjustment.

  • Customer Charge: $14.50 per month
  • Demand Charge: $7.254 per KW of Demand
  • Winter Energy Charges: 10.498 cents per kWh
  • Summer Energy Charges: 11.015 cents per kWh

Rate Applicable to Customers who are not subject to the Gross Revenue Tax:

  • Customer Charge: $13.27 per month
  • Demand Charge: $6.64 per KW of Demand
  • Winter Energy Charges: 10.318 cents per kWh
  • Summer Energy Charges: 10.835 cents per kWh

Purchased Power Adjustment:> An adjustment will be applied to every kWh sold to reflect any difference between the base power costs included in rates and the actual power costs (not including transmission) billed to the Department for its load.

TRANSMISSION COST ADJUSTMENT: An adjustment will be applied to every kWh sold to reflect any difference between the base transmission costs included in rates and the actual transmission costs charged to the Department.

SEASONAL DEFINITION: Winter refers to all billings between October 1 and May 31. Summer refers to all billings between June 1 and September 30.

DETERMINATION OF DEMAND: Where Customer has a demand meter, the department will measure the maximum 15- minutes kW demand in the billing month as the Billing Demand; Customers without demand meters will be billed for .5 KW per month. Demand meters will be installed on customers with energy use of greater than 300 kWhs per month.

TERM OF CONTRACT: One year and thereafter until thirty days written notice of termination.

RULES AND REGULATIONS: of the Department governing service hereunder as to application for service, character of service, connection, seasonal service, disconnection, reconnection, termination, etc., are on file in the Department.

EFFECTIVE DATE: With all billings on and after October 1, 2008, and thereafter until revised.

Medium General Service Electric Rate Schedule (Rate: MGS)

Applicable to the entire normal electrical requirements for light, heat, and power on the Customer’s premises for customers whose normal peak demand is from 10 to 99 kilowatts. Normal requirements include those that the customer usually self-generates.

Available throughout the service area from existing facilities of adequate character and capacity.

Character of Service: Delivery and metering at standard secondary voltage.

Monthly Rate is the sum of Customer Charge, Demand Charge, Energy Charge, Reactive Charge, any Purchased Power Adjustment, and any Transmission Cost Adjustment for the appropriate service voltage.

Rate Applicable to Customers who are subject to the Gross Revenue Tax:
Service Voltage Secondary Distribution
Customer Charge Per Month $32.79
Distribution Demand Charge per kW of Billing Demand $9.00
Reactive Charge per kVar of Excess Reactive Demand $0.59
Energy Charge per kWh (Winter) $0.10076
Energy Charge per kWh (Summer) $0.10631
Rate Applicable to Customers who are not subject to the Gross Revenue Tax:
Service Voltage Secondary Distribution
Customer Charge Per Month $32.06
Distribution Demand Charge per kW of Billing Demand $8.235
Reactive Charge per kVar of Excess Reactive Demand $0.59
Energy Charge per kWh (Winter) $0.09922
Energy Charge per kWh (Summer) $0.10478

Purchased Power Adjustment: An adjustment will be applied to every kWh sold to reflect any difference between the base power costs included in rates and the actual power costs (not including transmission) billed to the Department for its load.

TRANSMISSION COST ADJUSTMENT: An adjustment will be applied to every kWh sold to reflect any difference between the base transmission costs included in rates and the actual transmission costs charged to the Department.

SEASONAL DEFINITION: Winter refers to all billings between October 1 and May 31. Summer refers to all billings between June 1 and September 30.

DETERMINATION OF DEMAND: The Department will measure the highest 15- minutes kW demand in the billing month. Billing Demand shall be the greatest of 1) That measured demand to the nearest whole kilowatt or 2) 90% of the greatest such measured demand in the preceding eleven months.

DETERMINATION OF REACTIVE DEMAND: Where Billing Demand has exceeded 500 kilowatts, the Department will continuously measure the 15-minute kilovar ampere leading or lagging reactive demand. The greatest leading or lagging reactive demand over 14% of the greatest kilowatt demand in any 15-minute period in the billing month shall be the Excess Reactive Demand.

TERM OF CONTRACT: One year and thereafter until thirty days written notice of termination. A longer term may be required for an extensive installation.

RULES AND REGULATIONS of the Department governing service hereunder as to application for service, character of service, connection, seasonal service, disconnection, reconnection, termination, etc., are on file in the Department.

EFFECTIVE DATE:> With all billings on and after October 1, 2008, and thereafter until revised.

** Customers with larger loads or that have special requirements may call our Major Accounts Representative at 860-446-4008 to discuss your requirements.

Large General Service Electric Rate Schedule (Rate: LGS)

Applicable to the entire normal electrical requirements for light, heat, and power on the Customer’s premises up to 10,000 kilowatts for which no other rate schedule is applicable. Normal requirements include those kilowatt hours that the customer usually self-generates.

Available throughout the service area from existing facilities of adequate character and capacity.

Character of Service: Delivery and metering at one standard voltage.

Monthly Rate is the sum of Customer Charge, Demand Charge, Energy Charge, Reactive Charge, any Purchased Power Adjustment, and any Transmission Cost Adjustment for the appropriate service voltage.

Rate Applicable to Customers who are subject to the Gross Revenue Tax:
Service Voltage Secondary Distribution Primary Distribution Subtransmission
Customer Charge $80.00 $80.00 $80.00
Distribution Demand Charge per kW of Billing Demand $8.798 $8.798 $8.622
Reactive Charge per kVar of Excess Reactive Demand $0.59 $0.54 $0.50
Energy Charge per kWh (Winter) $0.09492 $0.09335 $0.09194
Energy Charge per kWh (Summer) $0.10032 $0.09932 $0.09782
Rate Applicable to Customers who are not subject to the Gross Revenue Tax:
Service Voltage Secondary Distribution Primary Distribution Subtransmission
Customer Charge $80.00 $80.00 $80.00
Distribution Demand Charge per kW of Billing Demand $8.050 $8.050 $7.889
Reactive Charge per kVar of Excess Reactive Demand $0.59 $0.54 $0.50
Energy Charge per kWh (Winter) $0.09381 $0.09226 $0.09087
Energy Charge per kWh (Summer) $0.09921 $0.09823 $0.09675

PURCHASED POWER ADJUSTMENT: An adjustment will be applied to every kWh sold to reflect any difference between the base power costs included in rates and the actual power costs (not including transmission) billed to the Department for its load.

TRANSMISSION COST ADJUSTMENT: An adjustment will be applied to every kWh sold to reflect any difference between the base transmission costs included in rates and the actual transmission costs charged to the Department.

SEASONAL DEFINITION
Winter refers to all billings between October 1 and May 31.
Summer refers to all billings between June 1 and September 30.

DETERMINATION OF DEMAND: The Department will measure the highest 15- minutes kW demand in the billing month.

Distribution Billing Demand shall be the greatest of 1) That measured demand to the nearest whole kilowatt, 2) 80% of the greatest such measured demand in the preceding eleven months, or 3) 50 kilowatts.

DETERMINATION OF REACTIVE DEMAND: Where Billing Demand has exceeded 500 kilowatts, the Department will continuously measure the 15-minute kilovar ampere leading or lagging reactive demand. The greatest leading or lagging reactive demand over 14% of the greatest kilowatt demand in any 15-minute period in the billing month shall be the Excess Reactive Demand.

TERM OF CONTRACT: One year and thereafter until thirty days written notice of termination. A longer term may be required for an extensive installation.

RULES AND REGULATIONS of the Department governing service hereunder as to application for service, character of service, connection, seasonal service, disconnection, reconnection, termination, etc., are on file in the Department.

EFFECTIVE DATE: With all billings on and after October 1, 2008, and thereafter until revised.

Street and Area Lighting Service (Rate: SAL)

Applicable to public or private customers for standard street and area lighting installations provided and maintained by the Department to render 4,000 annual hours of lighting.

Overhead installation is a light fixture attached to an existing overhead distribution system pole. Underground installation is a light fixture attached to a new pole served from an existing underground distribution system.

Available throughout the service area from existing facilities of adequate character and capacity.

Monthly Rate is the sum of Light Charge, any Purchased Power Adjustment, and any Transmission Cost Adjustment:

  Per Light Charge
Light Rating in Lumens, Watts and Type  Overhead Underground
Incandescent:    
600 L, 60W Red Fire Alarm $4.14 NA
1,000 L, 92W $5.15 NNI NA
7,000 L, 500W Floodlight $21.58 NNI NA
Mercury Vapor    
3,000 L, 100W $ 6.14 NNI $ 10.54 NNI
7,000 L, 175W $ 10.09 NNI $ 13.16 NNI
10,000 L, 250W $ 12.11 NNI NA
20,000 L, 400W $ 16.12 NNI NA
High Pressure Sodium    
4,000 L, 50W $ 7.92 NA
5,800 L, 70W $ 8.67 $ 13.59
9,500 L, 100W $ 10.82 NA
16,000 L, 150W $ 13.24 $ 18.98
22,000 L, 200W $ 14.91 NA
50,000 L, 400W $ 21.10 NA
27,000 L, 250W Floodlight $ 18.46 NA
50,000 L, 400W Floodlight $ 20.91 NA
Metal Halide    
12,000 L, 175W NA $ 16.23
*NA – Never Available    
*NNI – No New Installation    

High Voltage Large General Service Rate: HVLGS

APPLICABLE to the entire normal electrical requirements for light, heat, and power on the Customer’s premises where Customer’s full energy usage exceeds 10,000 kilowatts per month and where customer is served via dual feeder delivery at a standard subtransmission voltage, nominally at 33kV.

AVAILABLE throughout the service area from existing facilities of adequate character and capacity.

CHARACTER OF SERVICE: Delivery and metering at sub-transmission voltage.

MONTHLY RATE is the sum of Customer Charge, Demand Charge, Energy Charge, Reactive Charge, and any Purchased Power Adjustment, and any Transmission Cost Adjustment for the appropriate service voltage.

Rate Applicable to Customers who are subject to the Gross Revenue Tax:

  • Distribution Demand Charge per kW of Billing Demand: $10.76
  • Generation & Transmission Demand Charge per kW:
    • Winter: $31.845
    • Summer: $33.675
  • Reactive Charge per kVar of Excess Reactive Demand: $ 0.50
  • Generation & Transmission Energy Charge per kW:
    • Winter: $0.08257
    • Summer: $0.08757

Rate Applicable to Customers who are not subject to the Gross Revenue Tax:

  • Distribution Demand Charge per kW of Billing Demand: $9.85
  • Generation & Transmission Demand Charge per kW:
    • Winter: $31.671
    • Summer: $33.501
  • Reactive Charge per kVar of Excess Reactive Demand: $ 0.50
  • Generation & Transmission Energy Charge per kW:

Net Metering Rider:
Applicable to Customers on Rates RS and SGS with Alternate Power Source.

AVAILABILITY:> This rider is applicable to Customers with approved Alternate Power Source(s) (“APS”), as defined below, of electricity (with a capacity of less than 10 KW) other than electricity supplied by Groton Utilities (GU). Customer generation on Customer’s premises relieves customers from paying for purchase of power to the extent of such generation, but does not relieve GU of the obligation to deliver all power requirements.

DEFINITIONS:

Alternate Power Sources (APS): Any non-utility electric energy source located on the Customer’s premises and approved by GU to provide electric power service to the Customer.

Capacity Responsibility Obligation of GU: GU’s Responsibility Obligation shall consist of the sum of Partial Requirements Service, and Standby Delivery Service, mutually agreed upon by GU and the Customer that is adequate to meet the Customer’s expected power requirements.

Interconnection Costs: Any and all costs attributable to the Customer’s decision to interconnect and operate its APS in parallel with the GU electric system. All interconnections must conform to GU equipment and engineering standards as set forth in Policy.

Metering Costs: Any and all costs above and beyond that normally needed to provide full requirements service that are attributable to the Customer’s decision to interconnect and operate its APS in parallel with the GU electric system. All metering installations must conform to GU equipment and engineering standards as set forth in Policy.

Parallel Operation: The Customer’s APS must be operated in compliance with the GU Policy for parallel operation of self-generating facilities. GU may suspend parallel operations of the Customer’s APS if, in GU’s opinion, continued operation would endanger the operation, physical integrity of any GU equipment or personnel or if such operation would cause or contribute to a system emergency.

METERING REQUIREMENTS: Metering equipment shall be installed, at Customer’s expense, for the purpose of accurate measurement of the electricity supplied by GU to the net-metering Customer and accurate measurement of the total electric usage by the Customer, including the Customer’s own generation. Such metering must be approved by GU. TECHNICAL REQUIREMENTS DESCRIBED HERE OR ELSEWHERE.

BILLING FOR NET METERING CUSTOMERS: The net metering Customer shall be billed the monthly customer charge, and the transmission and distribution charges for Customer’s full load which are part of the bundled rates of the Residential and Small General Service rate schedules. These rate components are shown below. Customer shall be billed the generation charge, any Purchased Power Adjustment, and any Transmission Cost Adjustment charge only for Customer’s net usage, representing the electricity supplied by GU less the electricity supplied by the Customer’s APS back to GU’s facilities during any billing period. If Customer’s net usage is negative (customer generation fed back to the utility exceeds generation supplied by the utility) during a billing period, Customer shall be credited at the applicable generation, Purchased Power Adjustment, and any Transmission Cost Adjustment rate for such generation.

Distribution and Transmission Delivery Charges

Generation & Transmission Demand Charge per kW:

  • Rate RS: $0.04915 per kWh
  • Rate SGS: $0.05048 per kWh

RULES AND REGULATIONS of the Department governing service hereunder as to application for service, character of service, connection, seasonal service, disconnection, reconnection, termination, etc., are on file in the Department.

Primary Wheeling Service

APPLICABLE for wheeling service within the GU system, to any customers who are eligible to receive service under the HVLGS, rate for the delivery of electric generation services produced at a Customer’s location over the GU system to another location occupied by Customer which is also served by GU. Customers who utilize any part of GU’s delivery system to wheel the Customer’s self generation must comply with GU’s Interconnection Policy and shall pay this tariff for wheeling service.

AVAILABLE throughout GU’s service area from existing facilities of adequate character and capacity subject to the technical requirements of GU.

CHARACTER OF SERVICE: Dual feeder delivery and metering at a standard subtransmission voltage, nominally 33 kV.

MONTHLY BILL is the sum of the Distribution Demand Charge plus the Transmission Demand Charge, multiplied by the Wheeling Demand. Customer may also be eligible for a Distribution Demand Ratchet Credit based on charges due as a result of the Customer’s HVLGS load.

Wheeling Rate Applicable to Customers who are subject to the Gross Revenue Tax:

  • Distribution Demand Charge: $10.76 per kilowatt of Wheeling Demand
  • Transmission Demand Charge: $ 1.823 per kilowatt of Wheeling Demand

Wheeling Rate Applicable to Customers who are not subject to the Gross Revenue Tax:

  • Distribution Demand Charge: $ 9.85 per kilowatt of Wheeling Demand
  • Transmission Demand Charge: $ 1.668 per kilowatt of Wheeling Demand

DISTRIBUTION DEMAND RATCHET CREDIT: If the Customer’s own generation fails or is taken down for maintenance during a month, causing the Customer’s HVLGS demand to increase, the HVLGS rate Distribution Billing Demand will increase for the next 11 months, due to the ratchet on the Distribution Demand Charge. As long as this increase in HVLGS load does not occur during the hour of Connecticut peak load which determines GU’s capacity obligation, GU may calculate and provide a credit on the Wheeling Rate that reflects the amount of the HVLGS billing ratchet caused by the cessation of the Customer’s generation.

MEASUREMENT OF WHEELING DEMAND: The Department will continuously measure the 15-minute kilowatt demand in the billing month of the customer generation that is being wheeled by GU. The Wheeling Demand shall be the greatest such measured demand during the billing month.

FORCE MAJEURE: In a billing month in which Customer’s generation facilities are idled during more than 365 hours by an event of Force Majeure on GU’s delivery system, the Wheeling Demand Charges shall be prorated to the hours not affected by Force Majeure.

NOTICE OF LOAD CHANGE: The Customer shall respond to any written request from GU concerning forecasts of the Customer’s load and generation.

TERM OF CONTRACT: One year and thereafter until cancelled by six months written notice. A longer term may be required for an extensive installation.

RULES AND REGULATIONS of GU governing service hereunder as to application for service, character of service, connection, seasonal service, disconnection, reconnection, termination, etc., are on file in GU.

EFFECTIVE DATE: With all billings on and after October 1, 2008, and thereafter until revised.