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Welcome! | Rates | Project Management | Products | Bozrah Light & Power |
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Rate Applicable to Customers who are not subject to the Gross Revenue Tax
Purchased Power Adjustment An adjustment will
be applied to every kWh 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 meter 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
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| Per Light Charge |
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| Light Rating in Lumens, Watts and Type | Overhead |
Underground |
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| 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 |
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| 5,800 L, 70W | $ 8.67 | $ 13.59 | |
| 9,500 L, 100W | $ 10.82 | NA |
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| 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 | N/A |
$ 16.23 | |
| NA - Never Available | |||
| NNI - No New Installation | |||
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.
CONTRACT TERM is three years for each overhead lighting installation and five years for each underground lighting 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.
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: $33.675Reactive 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:
Winter: $0.08210
Summer: $0.08710
EXCESS KWH refers to energy in excess of a base amount determined by multiplying the distribution billing demand by 365. The customer shall pay the transmission delivery charge, the PPA and the TCA but does not pay the generation energy charge for this base amount.
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 or 2) 90% of the greatest such measured demand
in the preceding eleven months.
Generation Billing Demand shall be that measured demand
to the nearest whole kilowatt.
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.
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.
EFFECTIVE DATE: With all billings on and after October 1, 2008, and thereafter until revised.
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.
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