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Subject to adjustments as applicable and stipulated in § 51.03, the following rates and charges apply to the indicated classes of electric service.
(A) Residential service.
2021 | 2022 | |
Customer charge (per meter per month) | $8 | $12.50 |
Energy charge (per kWh per month) | ||
First 500 kWh | $0.1140 | $0.1220 |
Next 1,000 kWh | $0.1015 | $0.1050 |
Over 1,500 kWh | $0.0937 | $0.0944 |
(2) Minimum charge shall be the customer charge.
(B) (1) Commercial service.
2021 | 2022 |
2021 | 2022 | |
Customer charge (per meter per month) | ||
Single phase service | $10 | $15 |
Three phase service | $15 | $20 |
Energy charge (per kWh per month) | ||
First 1,500 kWh | $0.1180 | $0.1340 |
Next 3,500 kWh | $0.1015 | $0.1220 |
Over 5,000 kWh | $0.0937 | $0.0944 |
(2) Minimum charge shall be the customer charge.
(C) (1) General service.
2021 | 2022 | |
Customer charge (per meter per month) | ||
Single phase service | $15 | $20 |
Three phase service | $25 | $30 |
Billing maximum demand ($ per kW per month) | $6.50 | $8 |
Energy charge (per kWh per month) | $0.0737 | $0.0767 |
(2) Minimum charge shall be the customer charge plus the maximum load charge.
(3) Determination of maximum load and measurement of energy: maximum load in KW shall be measured by suitable instruments provided by the utility and in any month the maximum load in KW shall be measured by suitable instruments provided by the utility and in any month the maximum load shall be the average number of kilowatts in the recorded 30-minute interval during which energy metered is greater than in any other 30-minute interval in such month. Energy shall be measured by suitable integrating instruments provided by the utility. For billing purposes, the billing maximum load shall be the greater of the maximum load occurring during the month or twenty (20) KW.
(D) Industrial power service.
(l) Rates.
Rate Components | Phase 1 (2021) | Phase 2 (2022) |
Customer charge, per month | $100 | $200 |
Distribution demand charge, per kVA | $1.50 | $2 |
Billing maximum demand charge, per kVA | $12.50 | $13.50 |
Energy charge, per kWh | $0.0483 | $0.0504 |
(2) Minimum charge. The monthly minimum charge shall be the customer charge and distribution demand charge.
(3) Measurement of maximum load and energy. Maximum demand shall be measured by suitable instruments, and, in any month, the maximum demand shall be the average number of kilowatts (kW) in the 30-minute interval during which the energy metered is greater than in any other 30-minute interval in such month, divided by the average lagging power factor (expressed as a decimal) calculated for the month. Energy (kWh) shall be measured by a suitable integrating instrument.
(4) Billing maximum demand. The billing maximum demand for any month shall be the maximum demand for the month, but in no month shall the billing maximum demand be less than 100 kilovolt-amperes (kVA),
(5) Measurement of distribution demand. The distribution demand shall be the greater of the billing maximum demand (kVA) in the current month or 60% of the billing maximum demand in the preceding 11 months.
(6) Metering adjustment. When the measurement of energy is made at the primary voltage of the transmission or distribution line used to supply the customer, the maximum demand and energy measurements shall be multiplied by 98% or such measurements shall be converted to the equivalent of metering at the utility's secondary voltage.
(7) Equipment supplied by customer. When the customer furnishes and maintains the complete substation equipment including all transformation equipment necessary to take its entire service at the primary voltage of the distribution system from which the service is to be received, a credit will be applied to each month's net bill.
Phase 1 (2021) | Phase 2 (2022) | |
Credit per kVA of distribution demand | $1.25 | $1.75 |
(E) (1) Industrial primary power service.
Rate Components | Phase 1 (2021) | Phase 2 (2022) |
Customer charge, per month | $250 | $500 |
Distribution demand charge, per kVA | $2 | $3.50 |
Billing maximum demand charge, per kVA | $15.00 | $17.50 |
Energy charge, per kWh | $0.0415 0 | $0.0388 6 |
(2) Minimum charge. The monthly minimum charge shall be the customer charge and distribution demand charge.
(3) Measurement of maximum load and energy. Maximum demand shall be measured by suitable instruments, and, in any month, the maximum demand shall be the average number of kilowatts (kW) in the 30-minute interval during which the energy metered is greater than in any other 30-minute interval in such month, divided by the average lagging power factor (expressed as a decimal) calculated for the month. Energy (kWh) shall be measured by a suitable integrating instrument.
(4) Billing maximum demand. The billing maximum demand for any month shall be the maximum demand for the month, but in no month shall the billing maximum demand be less than 2,000 kilovolt-amperes (kVA).
(5) Measurement of distribution demand. The distribution demand shall be the greater of the billing maximum demand (kVA) in the current month or 60% of the billing maximum demand in the preceding 11 months.
(6) Metering adjustment. When the measurement of energy is made at the primary voltage of the transmission or distribution line used to supply the customer, the maximum demand and energy measurements shall be multiplied by 98% or such measurements shall be converted to the equivalent of metering at the utility's secondary voltage.
(7) Equipment supplied by customer. When the customer furnishes and maintains the complete substation equipment including all transformation equipment necessary to take its entire service at the primary voltage of the distribution system from which the service is to be received, a credit will be applied to each month's net bill.
Phase 1 (2021) | Phase 2 (2022) | |
Credit per kVA of distribution demand | $1.75 | $3.25 |
(F) Economic development rider.
(1) Availability. This rider is available to a qualifying customer (as defined herein) to encourage large power users to expand or create new operations within the utility's service territory.
(2) Qualifications.
(a) A QUALIFYING CUSTOMER is a new or existing non-residential customer in the utility's service territory that is establishing new operations or expanding existing operations such that the new or expanded operations will result in new or additional demand of at least one MW (500 kW) at one delivery point (the qualifying demand) and the new or expanded operations has involved a capital investment of at least $1,000,000 within the utility's service territory.
(b) For a qualifying customer that is expanding operations, qualifying demand is measured from the average monthly peak demand for the 12 months immediately preceding the effective date of the service application. For a qualifying customer that is establishing new operations, qualifying demand is measured from zero.
(c) A qualifying customer is not a customer: (1) with "new" demand that results from a change in ownership of an existing establishment without qualifying new load; (2) renewing service following interruptions such as equipment failure, temporary plant shutdown, strike, economic conditions, or natural disaster; or (3) that has shifted its load from one operation or customer to another within the utility's service territory. The utility may determine exclusively, without recourse by the customer, whether an event has occurred that would prevent a customer from being a qualifying customer.
(3) Rate incentive.
(a) Beginning with the effective date indicated in the service application submitted by the qualifying customer, the utility will receive a credit on its wholesale bill for the qualifying new load. The incentive amount received by utility from the Indiana Municipal Power Agency for such load will be passed in full to qualifying customers. For reference purposes, the discount to the qualifying customer's wholesale cost for a qualifying new load will be calculated according to the following schedule:
Months 1 - 12 | 20% |
Months 13 - 24 | 15% |
Months 25 - 36 | 10% |
Months 37 - 48 | 10% |
Months 49 - 60 | 5% |
(b) The qualifying customer must meet the minimum qualifying demand during each month of the incentive period (i.e., months one through 60, as designated above). Failure to meet the minimum qualifying demand in a particular month will result in 0% reduction for that month.
(4) Terms and conditions.
(a) The qualifying customer must submit a service application to the utility specifying:
1. A description of the amount and nature of the new load;
2. The basis on which the qualifying customer meets the requirements of this rider;
3. The qualifying customer's desired effective date; and
4. Any other information required by the utility.
(b) This rider will terminate on the same date that IMPA's economic development rider terminates, except that any qualifying customer receiving the rate incentive at the time of the rider's termination may continue receiving the incentive for the remainder of the applicable incentive period for as long it continues to meet the rider's requirements.
(5) Applicable rate schedules. This rider is applicable to the following rate schedules: general service, industrial service, and industrial primary service.
(G) Municipal street lighting service.
(1) Rates.
Monthly Rate Per Lamp | Phase 1 (2021) | Phase 2 (2022) |
Up to 20,000 lumens | $12 | $12 |
Over 20,000 lumens | $16.50 | $16.50 |
(2) Hours of lighting. All lamps shall burn approximately one-half hour after sunset until approximately one-half hour before sunrise each day in the year, approximately 4,000 hours per annum.
(3) Facilities. All facilities necessary for the service hereunder, including all poles, fixtures, street lighting circuits, transformers, lamps, and other necessary facilities will be furnished and maintained by the utility.
(H) Outdoor lighting service.
(1) Rates.
Monthly Rate Per Lamp | Phase 1 (2021) | Phase 2 (2022) |
Up to 20,000 lumens | $12 | $12 |
Over 20,000 lumens | $16.50 | $16,50 |
(2) Ownership of system. All facilities installed by the utility for service hereunder including all fixtures, controls, poles, transformers, secondary lines, lamps and other equipment shall be owned and maintained by the utility. All service and necessary maintenance will be performed only during regularly scheduled working hours of the utility. Non-operative lamps will normally be restored to service within two working days after notification by customer.
(3) Additional facilities. When facilities not provided for in the above charges are required for the installation of lamps, customer will pay in advance of installation the cost of such facilities required to supply service from the most suitable existing pole of utility to the point designated by customer for the installation of lamps.
(4) Hours of lighting. All amps shall burn approximately one-half hour after sunset until approximately one-half hour before sunrise each day in the year, approximately 4,000 hours per annum.
(1985 Code, § 6-11-2) (Ord. 1-1982, passed 2-8-1982; Ord. 1992-2, passed - -1992; Ord. 1993-5, passed - -1993; Ord. 1993-6, passed 12-13-1993; Ord. 1998-5, passed 10-15-1998; Ord. 2020-13, passed 12-9-2020)
The following adjustments are applicable to the rates and charges set forth in § 51.02 with respect to the several classes of electric service, as indicated.
(A) The rate adjustment is applicable to all metered rates of the utility. The applicable adjustment shall be applied to the total kWh billed to the customer for the meter reading period that the utility determines as most nearly corresponding to the meter reading periodfsl set forth in utility's power billings from its power supplier(s). The rate adjustment shall be on the basis of a purchase power cost adjustment tracking factor occasioned solely by changes in the cost of purchased power and energy, in accordance with the order of the Indiana Utility Regulatory Commission, approved on December 13, 1989 in Cause No. 36835-S3.
(B) Power cost.
(1) The rates and charges set forth in the utility's rate schedules are based on the cost of the utility's purchase power, fuel costs, and/or purchase power billing adjustments. Base power cost is the amount of power supply costs included in the rates. The base power cost is determined from the following wholesale power supply cost:
Demand charge ($ per kW per month) | $22.957 |
Energy charge ($ per kWh) | $0.026390 |
(2) The rate adjustment shall be determined based on a purchased power cost adjustment tracking factor occasioned solely by changes in the cost of purchased power and energy.
(1985 Code, § 6-11-3) (Ord. 1-1982, passed 2-8-1982; Ord. 1993-6, passed 12-13-1993; Ord. 1995-2, passed 2-14-1995; Ord. 1996-15, passed 8-14-1996; Ord. 1998-5, passed 10-15-1998; Ord. 2020-13, passed 12-9-2020)
The following charges are applicable to the rates and charges set forth in § 51.02 with respect to the several classes of electric service as indicated.
(A) Advance deposit. All residential and commercial classes of service shall pay an advance deposit of $450. The deposit may be waived at the sole discretion of the Utility Superintendent for residential customers who are in good standing for two years with an existing utility.
(B) Collection and deferred payment charge. This division (B) applies to residential, commercial, primary power, and municipal electric service rate schedules. Bills shall be rendered and due monthly. If paid within 15 days of the due date thereof, as stated in the bill, the net bill shall be the amount paid. If not paid within 15 days from the due date thereof, as stated in the bill, the gross bill, which includes the collection charge, shall be the amount to be paid. When the fifteenth day falls on Saturday, Sunday, or a legal holiday, the first business day thereafter shall be added to the 15-day period. The collection charge shall be 10% on the first $3 or less of net billing, plus 3% on the excess of $3 of net billing.
(C) Service charge for dishonored checks. This division (C) applies to residential, commercial, primary power, and municipal electric service rate schedules. Each check, draft, or order on a credit institution issued or delivered to the city or any of its utilities for the payment of money which the drawee refuses to pay or dishonors for any reason shall be subject to a service charge of $30, payable by the person who issues or delivers the check, draft, or order.
(D) Meter test charge. This division (D) applies to residential, commercial, primary power, and municipal electric service rate schedules. When a test meter is requested by a customer, the cost of the test to the utility will be charged with a minimum of a $50 charge for each test. If a meter shows the customer’s meter to be off plus or minus 2%, the charge will be voided.
(E) Reconnection charge. This division (E) applies to residential and commercial service rate schedules. When the service is turned off for non-payment of bills, or whenever for any reason beyond the control of the utility a re-establishment of service is required by any one customer, a charge of $50 will be made by the utility to cover a part of the cost of discontinuance and re-establishment of service. If reconnection is made outside of normal operating hours of the utility, the charge shall be $100 for re-establishment of service.
(F) Temporary charge. There shall be a charge of $50 when no more than a single span service drop and meter are required plus $10 per month in addition to the normal bill.
(1985 Code, § 6-11-4) (Ord. 1-1982, passed 2-8-1982; Ord. 1992-2, passed - -1992; Ord. 1993-5, passed - -1993; Ord. 1993-6, passed 12-13-1993; Ord. 1998-5, passed 10-15-1998; Ord. 2009-11, passed 10-14-2009; Ord. 2020-13, passed 12-9-2020)
All rates and charges are payable by the owner of each lot, parcel of real property, or building that:
(A) Is connected with the electric utility by or through any part of the electric utility works; or
(B) Uses or is served by the electric utility works.
(Ord. 2009-1, passed 4-8-2009)
INTERCONNECTION WITH
ELECTRIC UTILITY
(A) A customer desiring to interconnect renewable generation facilities with the utility’s grid for the purpose of offsetting the customer’s electric load shall complete an interconnection application and submit the application to the utility for review. After receipt of the application, the utility shall conduct such further inspection of the renewable generation facilities as the utility deems necessary and approve or deny the application. If the application is denied, the utility shall provide a written response to the customer explaining why the application was denied. The utility is hereby authorized to charge a reasonable application fee to offset costs involved with reviewing the application, inspecting the renewable generation facilities, and otherwise ensuring compliance with this section.
(B) If the interconnection application is approved, then the customer agrees that no changes shall be made to the configuration of the renewable generation facilities, as that configuration is described in the application, and no relay or other control or protection settings specified in the application shall be set, reset, adjusted or tampered with, except to the extent necessary to verify that the renewable generation facilities comply with the utility’s approved settings.
(C) In addition to such other requirements as the utility deems necessary, any renewable generation facility allowed to interconnect to the utility’s grid must comply with:
(1) The National Electrical Code and the National Electrical Safety Code, as each may be revised from time to time;
(2) The utility’s rules and regulations and the utility’s general terms and conditions for electric service, each as contained in the utility’s electric tariff and each as may be revised from time to time; and
(3) All other applicable local, state, and federal codes and laws, as the same may be in effect from time to time.
(D) For any approved renewable generation facilities interconnected to the utility’s grid, the customer shall install, operate, and maintain, at the customer’s sole cost and expense, the renewable generation facilities in accordance with the Institute of Electrical and Electronics Engineers’ applicable Standard for Interconnecting Distributed Resources with Electric Power Systems, as it may be amended from time to time. The customer shall be responsible for protecting, at the customer’s sole cost and expense, the renewable generation facilities from any condition or disturbance on the utility’s electric system, including, but not limited to, voltage sags or swells, system faults, outages, loss of a single phase of supply, equipment failures, and lightning or switching surges.
(E) The customer shall operate any interconnected renewable generation facilities in such a manner as not to cause undue fluctuations in voltage, intermittent load characteristics or otherwise interfere with the operation of the utility’s electric system. At all times when the renewable generation facilities are being operated in parallel with the utility’s electric system, the customer shall operate the renewable generation facilities in a manner that no disturbance will be produced to the service rendered by the utility to any of its other customers or to any electric system interconnected with the utility’s electric system. The customer’s control equipment for the renewable generation facilities shall immediately, completely, and automatically disconnect and isolate the renewable generation facilities from the utility’s electric system in the event of a fault on the utility’s electric system, a fault on the customer’s renewable generation facilities, or loss of a source or sources on the utility’s electric system. The automatic disconnecting device included in such control equipment shall not be capable of reclosing until after service is restored on the utility’s electric system. Additionally, if the fault is with the customer’s renewable generation facilities, such automatic disconnecting device shall not be reclosed until after the fault is isolated from the customer’s renewable generation facilities.
(F) Upon reasonable advance notice to the customer, the utility shall have access to any interconnected renewable generation facilities to perform on-site inspections to verify that the installation and operation of the renewable generation facilities comply with the requirements of this section and to verify the proper installation and continuing safe operation of the renewable generation facilities. The utility shall also have at all times immediate access to breakers or any other equipment that will isolate the renewable generation facilities from the utility’s electric system. The utility shall not be responsible for any costs the customer may incur as a result of such inspection(s). The utility shall have the right and authority to isolate approved interconnected renewable generation facilities at the utility’s sole discretion if the utility believes that: (a) continued interconnection and parallel operation of the renewable generation facilities with the utility’s electric system creates or contributes (or will create or contribute) to a system emergency on either the utility’s or the customer’s electric facilities; (b) the renewable generation facilities are not in compliance with the requirements of this section; or (c) the renewable generation facilities interfere with the operation of the utility's electric system. In non-emergency situations, the utility shall give the customer reasonable notice prior to isolating the renewable generation facilities.
(G) Customer shall procure and keep in force during all periods of parallel operation of the renewable generation facilities with the utility's electric system, homeowners, commercial, or other insurance to protect the interests of the utility as a named insured, with insurance carriers acceptable to the utility, and in amounts not less than those reasonably determined by the utility to be necessary taking into consideration the nameplate capacity, configuration and type of the renewable generation facilities. The customer shall indemnify and hold harmless the utility, the City of Greendale, its employees, representatives, agents and subcontractors from and against all claims, liability, damages and expenses, including attorney’s fees, based on any injury to any person, including the loss of life, or damage to any property, including the loss of use thereof, arising out of, resulting from, or connected with, or that may be alleged to have arisen out of, resulted from, or connected with, an act or omission by the customer, its employees, agents, representatives, successors or assigns in the construction, ownership, operation or maintenance of the customer’s renewable generation facilities. If the utility is required to bring an action to enforce its rights under this division, either as a separate action or in connection with another action, and said rights are upheld, the customer shall reimburse the utility for all expenses, including attorney’s fees, incurred in connection with such action.
(H) If a customer owning or leasing a renewable generation facility produces more energy from such facility than the customer’s electric load at that meter, then the excess energy shall be purchased from the customer by IMPA pursuant to the terms of a separate power purchase agreement between the customer and IMPA.
(I) It shall be unlawful for any person or entity to connect or maintain the connection of a renewable generating facility to the utility’s grid without obtaining the utility’s approval of an interconnection application. Any person or entity found to be in violation of this section shall be fined not less than $500, nor more than $2,500 for each such violation, plus costs. In addition to the foregoing fines and at the utility's sole discretion, property where a renewable generating facility is unlawfully connected to the utility’s grid may be disconnected from the utility’s grid until an interconnection application is approved. Every day that a violation of this section occurs shall constitute a separate offense.
(Ord. 2019-26, passed 12-11-2019)
EMERGENCY CURTAILMENT OF ELECTRIC SERVICE
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