Tariffs

Availability

Available to any member of the Cooperative who meets the eligibility criteria set forth herein and is located in the territory served by the Cooperative.

Applicability

Applicable to consumers supplied at a single location who meet the following requirements for service:

1. Customer shall apply to each large power member which owns and maintains substation transformation facilities at the point of delivery.
2. A three party Agreement will be required between member, RSE and Hoosier Energy.

Type of Service

Service shall be three phase, 60 hertz, at available standard voltages.

Monthly Rate

• Demand Charge: $17.10 per kw
• Energy Charges:
  • On-Peak: $0.06648 per kWh
  • Off-Peak: $0.05148 per kWh
• Excess Net kVARh charge: $0.01009 per kVARh

Billing Demand

Billing Demand shall be the highest consecutive 30-minute demand (the Non-Coincident Demand*) during the peak hours of the month expressed in kilowatts, but in no event less than 75 percent of the highest billing demand used in any of the preceding 11 months, or 500 kilowatts, whichever is greater Peak hours are defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily.

*Non-Coincident Demand is the highest kW demand for any fixed 30-minute period during the billing month.

Billing kWh

The billing kwh shall be the actual kwh used during the billing month.

Determination of Energy

On-Peak:

For the months of June through August, excluding Independence Day, On-Peak energy shall be all kilowatt-hours used during the period 2:00 p.m. to 8:00 p.m. E.S.T. – Monday through Friday.

For the months of December through February, excluding Christmas and New Years Day, On-Peak Energy shall be all kilowatt-hours used during the periods 7:00 a.m. to 10:00 a.m. E.S.T. and 6:00 p.m. to 9:00 p.m. E.S.T. – Monday through Friday.

Off-Peak:

Off-Peak Energy shall be all kilowatt-hours used during all hours other than on-peak hours as described above.

Power Factor

If the power factor (leading or lagging) at the time of the Non-Coincident Demand is determined to be less than 97%, the Non-Coincident Demand shall be adjusted separately by multiplying the Non-Coincident Demand by the ratio of the current target power factor percent 97% and the measured actual power factor percent at the time of the Non-Coincident Demand.

If the Average Monthly Power Factor (leading or lagging) is determined to be less than 95%, the “Excess Net kVARh” subject to the “Excess Net kVARh charge” is the difference between the actual measured Net kVARh amount and a calculated Net kVARh based upon the recorded kWh for the month and the targeted average monthly power factor of 95%. The Net kVARh calculation is based upon the standard Average Monthly Power Factor equation of:

Distribution Facilities Investment

The Distribution Facilities Investment is the investment (including any net replacements made from time to time) in electric plant facilities installed by the Cooperative for providing electric service to the consumer. Such facilities shall include both specific and reasonably allocable investment amounts directly associated with providing service to consumer.

Minimum Monthly Charge

The sum of the demand charge, the energy charge and excess Net kVARh.

Rate Adjustment and Non-Recurring Charges

This Rate Schedule is subject to a Wholesale Power Cost Adjustment (“WPCA”) Factor, as provided for in Schedule WPCA, all other applicable rate adjustment mechanisms, Riders, and all non-recurring charges set forth on “Appendix A” which may be amended from time to time in the sole discretion of the Board of Directors.

Terms & Conditions of Service

1. The Cooperative may require the member to enter into a written agreement stating the character of load, minimum contract period, minimum monthly charge, and other charges, if any.
2. In general, individual motors rated in excess of twenty (20) horsepower must be three-phase.
3. Any transformers and regulation equipment which may be required for incidental lighting shall be furnished by the consumer.
4. Electric Service provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules and Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
5. The rates and charges set forth in this Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.

Availability

This schedule is available to any wholesale generation equipment located within the territory served by RushShelby Energy (“Cooperative”). For purposes of this Rate Schedule, the term “Wholesale Generation and Energy Storage Equipment” shall mean equipment which is: (a) either located at a single contiguous site or located at multiple geographic sites and aggregated by a collector line or substation; (b) exclusively used to produce or store and discharge electric energy that will be sold at wholesale; (c) owned and/or operated by a qualified member of Midcontinent Independent System Operator, Inc. (“MISO”) or PJM Interconnection, L.L.C. (PJM); and (d) part of a facility or project that is subject to an Interconnection Agreement under the MISO Open Access Transmission Tariff (“OATT”) or PJM OATT. The Cooperative shall have the sole and exclusive right to determine if any particular equipment qualifies as Wholesale Generation and Energy Storage Equipment and if the operating characteristics and/or circumstances relating to such equipment are different than described in this definition.

Applicability

This schedule applies to energy used for operating Wholesale Generation and Energy Storage Equipment, and the net energy consumption by energy storage equipment, including losses, and the energy consumption and losses of buildings physically housing or containing Wholesale Generation and Energy Storage Equipment, which are used solely in the operation, maintenance, or repair of the facility (“Station Power”). Station Power does not include any energy used to power synchronous condensers, used for pumping at a pumped storage facility, for restoration-related or black start service or to energy that is normally supplied to facilities including, but not limited to buildings or structures on the site of such a Wholesale Generation and Energy Storage Equipment that are metered separately and served directly from the Cooperative’s distribution system.  The minimum monthly demand under this Rate Schedule shall be 500 kW.

Type of Service

Multi-phase, 60 Hertz, at the voltage specified in the Interconnection Agreement under the MISO or PJM OATT, or other voltage above 100 kV as might be mutually agreeable.

Monthly Rate

Demand Charge: $10.57 per kW

Energy Charges:

• On-Peak $ 0.0623 per kwh
• Off-Peak $ 0.0473  per kwh

Excess Net kVARh charge:  $ 0.01009 per kVARh

Metering

1. Cooperative will install or cause to be installed a meter (or parallel meter).
2. Metering will be installed at or loss compensated to the point of interconnection specified in the Interconnection Agreement under the MISO or PJM OATT, which can be on the low side of the transformer or can be on the high side depending on site issues/needs at the site.
3. In the case where there is failure of the Cooperative-owned metering, parallel meter data will be utilized (if available), or the best information on hand to be determined by Cooperative

Billing Demand

Billing Demand shall be the highest consecutive 30-minute demand (the Non-Coincident Demand*) during the peak hours of the month expressed in kilowatts, but in no event less than 75 percent of the highest billing demand used in any of the preceding 11 months, or 500 kilowatts, whichever is greater Peak hours are defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily.

*Non-Coincident Demand is the highest kW demand for any fixed 30-minute period during the billing month.

Billing kWh

The billing kwh shall be the actual kwh used during the billing month.

Determination of Energy

On-Peak:

For the months of June through August, excluding Independence Day, On-Peak energy shall be all kilowatt-hours used during the period 2:00 p.m. to 8:00 p.m. E.S.T. – Monday through Friday.

For the months of December through February, excluding Christmas and New Years Day, On-Peak Energy shall be all kilowatt-hours used during the periods 7:00 a.m. to 10:00 a.m. E.S.T. and 6:00 p.m. to 9:00 p.m. E.S.T. – Monday through Friday.

Off-Peak:

Off-Peak Energy shall be all kilowatt-hours used during all hours other than on-peak hours as described above.

Power Factor

If the power factor (leading or lagging) at the time of the Non-Coincident Demand is determined to be less than 97%, the Non-Coincident Demand shall be adjusted separately by multiplying the Non-Coincident Demand by the ratio of the current target power factor percent 97% and the measured actual power factor percent at the time of the Non-Coincident Demand.

If the Average Monthly Power Factor (leading or lagging) is determined to be less than 95%, the “Excess Net kVARh” subject to the “Excess Net kVARh charge” is the difference between the actual measured Net kVARh amount and a calculated Net kVARh based upon the recorded kWh for the month and the targeted average monthly power factor of 95%. The Net kVARh calculation is based upon the standard Average Monthly Power Factor equation of:

Minimum Monthly Charge

The sum of the demand charge, the energy charge and excess Net kVARh.

Other Wholesale Charges and Credits

In addition to the wholesale demand and energy charges which are included in the demand and energy charges of the monthly rate, the consumer shall pay all other charges including but not limited to the Power Cost Tracker, and receive all other credits billed the Cooperative by Hoosier Energy for service hereunder pursuant to Hoosier Energy's Industrial Power Tariff and which are not specifically covered by another provision of this schedule.

Wholesale Changes

Should there be any change in the Hoosier Energy Industrial Power Tariff under which the Cooperative purchases power for service hereunder, the charges and provisions of Schedule IPT-69 kV shall change correspondingly such that the change in wholesale power cost is passed through to the consumer.

Tax Adjustments

The amount computed at the above monthly rate as adjusted by the application of the rate adjustment clauses shall be subject to taxes, assessments, and surcharges imposed by any governmental authority.

Terms and Conditions of Services

1. The owner of the Wholesale Generation and Energy Storage Equipment shall become a member of the Cooperative and shall be subject to the articles of incorporation, bylaws, board-approved policies, and Service Rules & Regulations of the Cooperative as the same may be amended from time to time by the board of directors of the Cooperative.
2. The Cooperative shall not be liable for any interruption of service caused by defective wiring or Customer's appliances on the Customer's premises. Furthermore, the Cooperative shall not be liable for damages resulting to the Customer, or to third persons, from the use of electricity, interruption of service or supply, or the presence of the Cooperative's property on the Customer's premises, unless due to willful default or neglect on the part of the Cooperative.
3. Electric Service provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules & Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
4. Billing and Payment for electric Service provided under this Rate Schedule is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules & regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
5. The rates and charges set forth in this Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.

Terms of Payment

This Rate Schedule is subject to the charges set forth on the Cooperative’s Appendix A and all non-recurring charges which may be amended from time to time in the sole discretion of the Board of Directors.

Availability

Available to any member of the Cooperative located on or near its multi-phase lines and willing to participate in voluntary control of demand at system peak demand.

Type of Service

Alternating current, 60-cycle, multi-phase, 240 volts, 480 volts or other industry standard voltage mutually agreeable to the member and the Cooperative.

Monthly Rate

Connection Charge:  $150.00 per month

Demand Charge: $10.28 per on-peak kW

$ 3.98 per regular kW

Energy Charge: $0.0728 per kWh

Minimum Monthly Charge

The minimum monthly charge shall be the greater of:

1. The contract minimum.
2. The minimum monthly or annual charge as specified in any contract for service.
3. A charge of$1.00 per kVa of the consumer's required transformer

Rate Adjustment

The above rates are subject to a Wholesale Power Cost Adjustment ("WPCA'') Factor, as provided for in Schedule WPCA.

Determination of Billing Demand

This "on-peak" billing demand shall be the 60-minute  average  kilowatt load used by the member, as measured over the highest 15 consecutive minutes, corresponding to the period during which the Cooperative's wholesale supplier records the highest system demand during the month for which bill is rendered. This "on-peak" billing demand shall be imposed if the member is online, and the peak occurs between 6:00 a.m. and 9:00 a.m. any day in the months of October through April and the temperature is 35 degrees Fahrenheit or below. This "on-peak" billing demand shall also be imposed if the member is online, and the peak occurs between 4:00 p.m. and 9:00 p.m. any day in May, June, July, August, or September if the temperature is 85 degrees Fahrenheit or above.

Power Factor

The consumer agrees to maintain unity power factor as nearly as practical. The Cooperative reserves the right to measure such power factor at any time. Should such measurements indicate that the average power factor in the billing period is less than 97 percent, the demand for billing purposes shall be the demand as indicated or recorded by the demand meter multiplied by 97 percent and divided by the percent power factor.

Rate Adjustments and Non-Recurring Charges

This Rate Schedules subject to a Wholesale Power Cost Adjustment (“WPCA”) Factor, as provided for in Schedule WPCA, all other applicable rate adjustment mechanisms, Riders, and all non-recurring charges set forth on “Appendix A” which may be amended from time to time in the sole discretion of the Board of Directors.

Terms and Conditions of Service

The Cooperative may require the member to enter into a written agreement stating the character of load minimum contract period, minimum monthly charge, and other charges, if any.

2. Members may connect lighting to power circuits from the power The member shall furnish any additional transformers or regulating equipment, which may be required for such lighting.
3. In general, motor which have an individual capacity greater than 10 horsepower must be multi-phase. Where multi-phase service is not available, motors in excess of 10 horsepower may be connected at the discretion of the
4. All wiring, pole lines and other electrical equipment beyond the metering point is considered the distribution system of the member and shall be furnished and maintained by the member, unless otherwise agreed upon by the
5. Should the electricity energy furnished under this schedule for any reason be metered on the primary side of the service transformers, the Cooperative shall deduct 1Y, percent of the energy
6. Where the member requires underground primary or secondary service, it will be provided in accordance with the Cooperative's Underground Service Policy.
7. Combining of meter readings at several premises for billing purposes shall not be permitted.
8. At its discretion, the Cooperative shall perform inspections of load control devices installed by the Cooperative on the member's premises to verify the proper operation of such
9. The official source for the temperature in degrees Fahrenheit shall be the National Weather Service Station located at the Shelbyville Municipal
10. Electric Service provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules and Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
11. The rates and charges set forth in this Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.

Availability

Available to any member of the Cooperative who meets the eligibility criteria set forth herein and is located in the territory served by the Cooperative.

Applicability

Applicable to consumers supplied at a single location who meet the following requirements for service:

1. The consumer's monthly maximum demands must be at least 500 kW.
2. The consumer takes service directly from a Hoosier Energy supplied transmission-to-distribution substation.

Type of Service

Service shall be three phase, 60 hertz, at available standard voltages.

Monthly Rate

Connection Charge: $150.00      per month

Demand Charge:

Production:

Summer  - $ 8.14 per kW of Summer Coincident Peak Demand

Winter - $ 6.89 per kW of Winter Coincident Peak Demand

Transmission -  $ 6.13 per kW of Coincident Demand

Substation & Radial Line - $ 5.00 per kW of Billing Non-Coincident Demand

Energy Charges:

On-Peak  $  0.05709  per kwh

Off-Peak  $  0.03845  per kwh

Excess Net kVARh charge   $ 0.01009 per kVARh

Summer Coincident Demand

For the months of June through August, Summer Coincident Demand at RSE’s delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with Midcontinent Independent System Operator’s (MISO) system peak demand occurring during Load shall Control Periods within the On-Peak Demand Period, defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily. The Summer Coincident Demand shall be no less than 500 kW.

For the months of September through November, Summer Coincident Demand is the average of the Summer Coincident Demands for the preceding months of June through August.

Winter Coincident Demand

For the months of December through February, Winter Coincident Demand at RSE’s delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with MISO’s system peak demand occurring during Load shall Control Periods within the On-Peak Demand Period, defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily. The Winter Coincident Demand shall be no less than 500 kW.

For the months of March through May, Winter Coincident Demand is the average of the Winter Coincident Demands for the preceding months of December through February.

Coincident Demand

For the months of March – May and September – November the Coincident Demand at each delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with Hoosier Energy’s system peak demand, E.S.T., daily.

For the months of June – August and December – February the Coincident Demand at each delivery point in the month of billing shall be the delivery point’s clock-hour demand that is coincident with MISO’s estimated system peak demand, E.S.T., daily.

Non-Coincident Demand

Non-Coincident Demand at each delivery point in the month of billing shall be the delivery point’s highest kW demand for any fixed 30-minute period during the billing month.

Billing Non-Coincident Demand

Billing Non-Coincident Demand at each member delivery point in the month of billing shall be the delivery’s point non-coincident demand adjusted for the power factor as required.

Billing kWh

The billing kWh shall be the actual kwh used during the billing month or 328.5 times the monthly billing demand.

Determination of Energy

On-Peak:

For the months of June through August, excluding Independence Day as defined by the North American Electric Reliability Corporation (NERC), On-Peak energy shall be all kilowatt-hours used during the period 2:00 p.m. to 8:00 p.m. – Monday through Friday, E.S.T., daily.

For the months of December through February, excluding Christmas and New Years Day as defined by NERC, On-Peak Energy shall be all kilowatt-hours used during the periods 7:00 a.m. to 10:00 a.m. and 6:00 p.m. to 9:00 p.m. – Monday through Friday, E.S.T., daily.

Off-Peak:

Off-Peak Energy shall be all kilowatt-hours used during all hours other than on-peak hours as described above.

Power Factory

If the Average Monthly Power Factor (leading or lagging) at the time of the Non-Coincident Demand is determined to be less than 97%, the Non-Coincident Demand shall be adjusted separately by multiplying the Non-Coincident Demand by the ratio of the current target power factor percent (97%) and the measured actual power factor percent at the time of the Non-Coincident Demand.

If the Average Monthly Power Factor (leading or lagging) is determined to be less than 95% the “Excess Net kVARh” subject to the “Excess Net kVARh charge” is the difference between the actual measured Net kVARh amount and a calculated Net kVARh based upon the recorded kWh for the month and the targeted average monthly power factor of 95%. The Net kVARh calculation is based upon the standard Average Monthly Power Factor equation of:

Minimum Monthly Charge

The minimum monthly charge shall be the greater of:

1. $2,900 plus the energy charge.
2. The sum of the connection charge, demand charge, the energy charge and excess Net kVARh.

Rate Adjustment and Non-recurring Charges

This Rate Schedule is subject to a Wholesale Power Cost Adjustment (“WPCA”) Factor, as provided for in Schedule WPCA, all other applicable rate adjustment mechanisms, Riders, and all non-recurring charges set forth on “Appendix A” which may be amended from time to time in the sole discretion of the Board of Directors.

Terms and Conditions of Service

1. The applicant will be required to give satisfactory assurance by means of a written agreement as to the character, amount, and duration of the business offered.
2. In general, individual motors rated in excess of twenty (20) horsepower must be three-phase.
3. Any transformers and regulation equipment which may be required for incidental lighting shall be furnished by the consumer.
4. Electric Service provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules & Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
5. The rates and charges set forth in this Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.

Summary of Current Rates

General Service - Single Phase (GS - 1)

• Connection Charge: $55 per month
• Energy Charge
  • Winter Months (January to March): $0.0943 per kWh
  • Shoulder Months (April to May and October to December): $0.1005 per kWh
  • Summer Months (June-September): $0.1103 per kWh

General Service - Three Phase (GS-3)

• Connection Charge: $77 per month
• Energy Charge
  • All kWh per year: $0.13210 per kWh

Large Power Service (LP)

• Connection Charge: $95 per month
• Demand Charge
  • Summer Months (July to December): $14.38 per kW
  • Winter Months (January to June): $13.84 per kW
  • Energy Charge (All kWh per month): $0.0660 per kWh

Grain Drying and Irrigation Service (GD)

• Connection Charge: $95 per month
• Energy Charge
  • All kWh per year: $0.1583 per kWh

Collection Fees

When it is necessary for the personnel of RSE to go to a member’s premises to collect a delinquent bill, a collection fee of thirty ($30) dollars per trip shall be charged in lieu of disconnection. If the delinquent bill is not collection, disconnection of service may occur.

Disconnection Fees

When it is necessary for RSE to disconnect the electric service at a member’s premises, whether it is on the premises or by electronic means, and whether it is at the member’s request, because of a delinquent bill, involves speculation of meter and/or facility tampering, or any other reasonable cause as determined by RSE, a fee of thirty ($30) dollars shall be charged. Should disconnection result during a collection visit to the member’s premises, only one fee shall be charged.

Reconnections Fees

A member that has been disconnected shall be assessed a fee of thirty ($30.00) dollars for reconnection during regular business hours. Payment must be made by a credit or debit card over the phone or pay in the office with cash, certified check, or money order during regular business hours, prior to reconnection.

For delinquent bills, the member shall pay in full all amounts due up to and including date of disconnection and shall pay before service is reconnected.

The fee for a seasonal service reconnection shall be thirty ($30.00) dollars.

Overtime Reconnection Fees

Connection of electric service after hours, at the member’s request, will be assessed a reconnection fee as stated above, and an additional overtime fee of seventy-five ($75.00) dollars, both of which must be paid prior to reconnection of electric service.

Late Payment Fees

Bills shall be rendered and due monthly. If bills are not paid on or before the seventeenth day following the due date, the bill shall have late charges added as follows:

All net billing 3%.

Insufficient Funds Fee

When a payment received on a member’s account, in any form, is returned unpaid for any reason by a financial institution, the member shall be assessed a fee of thirty ($30.00) dollars.

Meter Testing Fee

When a member requests a meter test less than twelve months from their most recent meter test, whether such earlier test was by consumer or Cooperative request, the member shall be required to pay a thirty ($30.00) fee for the latest test.

New Account Fee

Any member requesting a new service or a service at an existing location transferred into their name shall pay a thirty ($30.00) dollar non-refundable fee for the account activation.

Deposit

All new accounts shall be subject to a deposit of one hundred fifty ($150) dollars or three hundred ($300) dollars based upon specific circumstances with a credit report obtained from either a third-party credit reporting agency or RSE credit history.

Availability

Available to any member of the Cooperative who meets the eligibility criteria set forth herein and is located in the territory served by the Cooperative.

Applicability

Applicable to consumers supplied at a single location who meet the following requirements for service:

1. The consumer's monthly maximum demands must be at least 2500 kW.
2. The consumer takes service directly from a Hoosier Energy supplied transmission-to-distribution substation.

Type of Service

Service shall be three phase, 60 hertz, at available standard voltages.

Monthly Rate

• Connection Charge: $150 per month
• Demand Charge: $18.46 per kW
• Energy Charges:
  • On-Peak: $0.06209 per kwh
  • Off-Peak: $0.04709 per kwh
• Excess Net kVARh charge: $0.01009 per kVARh

Billing Demand

Billing Demand shall be the highest consecutive 30-minute demand (the Non-Coincident Demand) during the Peak hours of the month expressed in kilowatts, but in no event less than 75 percent of the highest billing demand used in any of the preceding 11 months, or 500 kilowatts, whichever is greater, for purposes of calculating Billing Demand, Peak hours are defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily.

Billing kWh

The billing kwh shall be higher of the actual kwh used during the billing month or 328.5 times the monthly billing demand.

Determination of Energy

On-Peak:

For the months of June through August, excluding Independence Day, On-Peak energy shall be all kilowatt-hours used during the period 2 pm to 8 pm E.S.T. – Monday through Friday.

For the months of December through February, excluding Christmas and New Years Day, On-Peak Energy shall be all kilowatt-hours used during the periods 7 am to 10 am E.S.T. and 6 pm to 9 pm E.S.T. – Monday through Friday.

Off-Peak:

Off-Peak Energy shall be all kilowatt-hours used during all hours other than on-peak hours as described above.

Power Factor

If the power factor (leading or lagging) at the time of the Non-Coincident Demand is determined to be less than 97%, the Non-Coincident Demand shall be adjusted separately by multiplying the Non-Coincident Demand by the ratio of the current target power factor percent 97% and the measured actual power factor percent at the time of the Non-Coincident Demand.

If the Average Monthly Power Factor (leading or lagging) is determined to be less than 95%, the “Excess Net kVARh” subject to the “Excess Net kVARh charge” is the difference between the actual measured Net kVARh amount and a calculated Net kVARh based upon the recorded kWh for the month and the targeted average monthly power factor of 95%. The Net kVARh calculation is based upon the standard Average Monthly Power Factor equation of:

Minimum Monthly Charge

The minimum monthly charge shall be the greater of:

1. The minimum monthly or annual charge as specified in any contract for service.
2. The sum of the connection charge, demand charge, the energy charge and excess Net kVARh.

Rate Adjustments and Non-Recurring Charges

This Rate Schedule is subject to a Wholesale Power Cost Adjustment (“WPCA”) Factor, as provided for in schedule WPCA, all other applicable rate adjustment mechanisms, Riders and all non-recurring charges set forth on “Appendix A” which may be amended from time to time in the sole discretion of the Board of Directors.

Terms & Conditions of Service

1. The Cooperative may require the member to enter into a written agreement stating the character of load, minimum contract period, minimum monthly charge, and other charges, if any.
2. In general, individual motors rated in excess of twenty (20) horsepower must be three-phase.
3. Any transformers and regulation equipment which may be required for incidental lighting shall be furnished by the consumer.
4. Electric Service provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules & Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
5. The rates and charges set forth in this Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.

Availability

Available to any member of the Cooperative who meets the eligibility criteria set forth herein and is located in the territory served by the Cooperative.

Applicability

Applicable to consumers supplied at a single location who meet the following requirements for service:

1. The consumer's monthly maximum demands must be at least 5,000 kW to 50,000 kW. All above 50,000 kW will require a special contract.
2. The consumer takes service directly from a Hoosier Energy supplied transmission-to-distribution substation.

Type of Service

Service shall be three phase, 60 hertz, at available standard voltages.

Monthly Rate

• Connection Charge: $150 per month
• Demand Charge: $14.82 per kW
• Energy Charges:
  • On-Peak: $0.06209 per kWh
  • Off-Peak: $0.04709 per kWh
• Excess Net kVARh charge: $0.01009 per kVARh

Billing Demand

Billing Demand shall be the highest consecutive 30-minute demand (the Non-Coincident Demand) during the Peak hours of the month expressed in kilowatts, but in no event less than 75 percent of the highest billing demand used in any of the preceding 11 months, or 500 kilowatts, whichever is greater, for purposes of calculating Billing Demand, Peak hours are defined as those hours from 7:00 a.m. to 11:00 p.m., E.S.T., daily.

Billing kWh

The billing kWh shall be higher of the actual kWh used during the billing month or 328.5 times the monthly billing demand.

Determination of Energy

On-Peak:

For the months of June through August, excluding Independence Day, On-Peak energy shall be all kilowatt-hours used during the period 2:00 p.m. to 8:00 p.m. E.S.T. – Monday through Friday.

For the months of December through February, excluding Christmas and New Years Day, On-Peak Energy shall be all kilowatt-hours used during the periods 7:00 a.m. to 10:00 a.m. E.S.T. and 6:00 p.m. to 9:00 p.m. E.S.T. – Monday through Friday.

Off-Peak:

Off-Peak Energy shall be all kilowatt-hours used during all hours other than on-peak hours as described above.

Power Factor

If the power factor (leading or lagging) at the time of the Non-Coincident Demand is determined to be less than 97%, the Non-Coincident Demand shall be adjusted separately by multiplying the Non-Coincident Demand by the ratio of the current target power factor percent 97% and the measured actual power factor percent at the time of the Non-Coincident Demand.

If the Average Monthly Power Factor (leading or lagging) is determined to be less than 95%, the “Excess Net kVARh” subject to the “Excess Net kVARh charge” is the difference between the actual measured Net kVARh amount and a calculated Net kVARh based upon the recorded kWh for the month and the targeted average monthly power factor of 95%. The Net kVARh calculation is based upon the standard Average Monthly Power Factor equation of:

Distribution Facilities Investment

The Distribution Facilities Investment is the investment (including any net replacements made from time to time) in electric plant facilities installed by the Cooperative for providing electric service to the consumer. Such facilities shall include both specific and reasonably allocable investment amounts directly associated with providing service to consumer.

Minimum Monthly Charge

The minimum monthly charge shall be the greater of:

1. The contract minimum.
2. The sum of the demand charge, the energy charge and excess Net kVARh.

Rate Adjustment and Non-Recurring Charges

This Rate Schedule is subject to a Wholesale Power Cost Adjustment (“WPCA”) Factor, as provided for in Schedule WPCA, all other applicable rate adjustment mechanisms, Riders, and all non-recurring charges set forth on “Appendix A” which may be amended from time to time in the role discretion of the Board of Directors.

Terms & Conditions of Service

1. The Cooperative may require the member to enter into a written agreement stating the character of load, minimum contract period, minimum monthly charge, and other charges, if any.
2. In general, individual motors rated in excess of twenty (20) horsepower must be three-phase.
3. Any transformers and regulation equipment which may be required for incidental lighting shall be furnished by the consumer.
4. Electric Services provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules and Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
5. The rates and charges set forth in this Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.

Availability

Available to any member of the Cooperative who meets the eligibility set forth herein and is located in the territory served by the Cooperative where 120 volt service exists ahead of the meter loop for the use of Security Lighting.

Character of Service

Dusk-to-dawn lighting service, using photo-electrically controlled equipment, mast arm, street light type luminaire with lamp. Maintenance of the complete assembly and the cost of its electrical operation are included in this service. Any additional investment required by the extension of secondary lines or hanging of a transformer or installation of poles, for the sole purpose of this service will require a contribution by the member.

Monthly Rate

The monthly charge for each Security Light shall be as follows:

• Type Lamp
  • 175 watt or lower: $11.00 per month
  • 176 watt or higher: $17.00 per month

Termination of Service

The consumer may request termination of service at his option and the Corporation will remove its property upon such notice with reasonable diligence. The Corporation may remove its fixture and cancel Security Lighting service when:

1. Bills are unpaid.
2. When the service is no longer made available.
3. Whenever such action is necessary to protect the Corporation from fraud or abuse.

Rate Adjustments and Non-Recurring Charges

This Rate Schedule is subject to applicable rate adjustment mechanisms, Riders and all non-recurring charges set forth on “Appendix A” which may be amended from time to time in the sole discretion of the Board of Directions.

Terms and Conditions of Service

1. Electric Service provided hereunder is subject to the provisions set forth in the Cooperative’s Bylaws, Service Rules and Regulations, and Policies, as may be amended from time to time in the sole discretion of the Board of Directors.
2. The rates and charges set forth in the Rate Schedule are subject to change at any time in the sole discretion of the Board of Directors.

Availability

Listed under existing schedule

Metering & Billing

Listed under existing schedule

Character of Service

Listed under existing schedule

Monthly Rate

Listed under existing schedule

Energy Credit For energy supplied by Customer (Credits): $0.04 per kWh

Minimum Monthly Charges

Listed under existing schedule

Terms & Conditions of Service

Listed under existing schedule

Rate Adjustment

Listed under existing schedule

DG System Requirements

The Member’s DG System must meet the following requirements:

1. The nameplate rating of Member’s DG System must not greater than 49 kW.
   1. Exception to the 49 kW could be approved by Hoosier Energy and RushShelby Energy.
2. The DG System must be owned and operated by the Member and must be located on the Member’s premises.
3. The Member’s DG System must be intended primarily to offset part or all of the Member’s requirements for electricity.
4. The DG System must operate in parallel with the Cooperative’s distribution facilities; and
5. The DG System must satisfy the Cooperative’s Interconnection Standards as the same may be amended from time to time.

Interconnection Requirements; Terms & Conditions of Service

1. The Member shall make such application and enter into such interconnection agreements as the Cooperative shall require from time to time.
2. Any characteristic of the Member’s DG System or interconnection facilities that degrades or otherwise compromises the quality of service provided by the Cooperative to other Members will not be permitted.
3. The Member shall agree that the Cooperative shall at all times have immediate access to the Member’s metering, control, and protective equipment.
4. The Member shall install, operate and maintain the DG System and interconnection facilities in accordance with the manufacturer’s suggested practices for safe, efficient and reliable operation in parallel with the Cooperative’s system.
5. The Cooperative may, at its own discretion, isolate any DG System if the Cooperative has reason to believe that continued interconnection creates or contributes to a system emergency.
6. A disconnecting device must be located at the point of common coupling for all interconnections. The disconnecting device must be accessible to Cooperative personnel at all times and be suitable for use by the Cooperative as a protective tagging location. The disconnecting device shall have a visible open gap when in the open position and be capable of being locked in the open position. The cost and maintenance of the main disconnect switch shall reside with the Member.
7. The Cooperative reserves the right to have a representative present during compliance testing at the time of installation and maintenance testing of the interconnection system for compliance with these conditions of service.
8. The Member is responsible for establishing a program for and performing annual periodic scheduled maintenance on the Member’s DG System and interconnection facilities (relays, interrupting devices, control schemes and batteries that involve the protection of the Cooperative’s distribution system). A periodic maintenance program is to be established in accordance with the requirements of IEEE 1547. The Cooperative may examine copies of the periodic test reports or inspection logs associated with the periodic maintenance program. Upon the Cooperative’s request, the Cooperative shall be informed of the next scheduled maintenance and be able to witness the maintenance performed and any associated testing.
9. The interconnection system hardware and software design requirements must be intended to assure protection of the Cooperative’s distribution system. Any additional hardware and software necessary to protect the Cooperative’s distribution system and equipment is solely the responsibility of Member to determine, design, acquire and install.
10. The Member shall agree that the Cooperative shall not be liable for any damage to or breakdown of the Member’s equipment operated in parallel with the Cooperative’s electric system.
11. The Member shall agree to release, indemnify, and hold harmless the Cooperative from any and all claims for injury to persons or damage to property due to or in any way connected with the operation of Member-owned equipment and/or generators.
12. Any DG System used by a Member pursuant to the Rate shall meet all applicable safety and performance standards established by the National Electric Code, The Institute of Electrical and Electronics Engineers and Underwriters Laboratories, including, but not limited to IEEE 1547. The Cooperative shall have right to require additional safety features at the cost of the Member.
13. The Member must obtain, at his or her expense, all necessary inspections and approvals required by codes prior to being authorized by the Cooperative to connect the Member’s DG System to the Cooperative’s distribution system. The Member will supply the Cooperative with certification that DG System has received all necessary code approvals and that it meets, or exceeds, all applicable safety and performance standards.
14. The Member’s DG System when operated in parallel with the Cooperative’s system must be designed and capable of immediately and automatically ceasing interconnected operation during any outages on the Cooperative’s system and during other emergency or abnormal conditions as specified by applicable codes and standards. The Member must cease parallel operation of its DG System immediately upon notification by the Cooperative if such operation is deemed unsafe or interferes with the supply of service to others or interferes with system operation or maintenance. The Cooperative accepts no responsibility for damage or injury to any person or property caused by the failure of the Member to operate in compliance with the Cooperative’s or any other requirements.
15. Failure of the Member to comply with any of these requirements shall result in disconnection of service to the Member from the Cooperative’s system. The Cooperative will be under no obligation to reconnect the Member until the Member’s DG System either complies with the requirements or is disconnected from any parallel operation with Cooperative’s system.

System Modifications

If it is necessary for the Cooperative to modify portions of its existing system to provide larger capacity facilities or metering to accommodate the purchase of electricity from the Member pursuant hereto, the Member will be responsible for the entire cost of said upgrades. Should system modification be necessary, the Cooperative, at the Member’s expense, shall perform all work on the Cooperative’s side of the meter.

Application

The interpretation of, or the application by Cooperative of, all rates, rules and regulations included in its tariff or adopted by the Cooperative shall be subject to review and interpretation by the Board of Directors of the Cooperative.