ARKANSAS PUBLIC SERVICE COMMISSION 13th Revision Sheet …

ARKANSAS PUBLIC SERVICE COMMISSION

14th Revision Sheet No. TC-1 Replacing 13th Revision Sheet No. TC-1

Ozarks Electric Cooperative Corporation Name of Company

Kind of Service: Electric Class of Service: All

Title: TABLE OF CONTENTS PSC File Mark Only

THIS SPACE FOR PSC USE ONLY

SCHEDULE NO. SCHEDULE NAME SHEET EXEMPT Exemption Schedule ...................................................................................................... 1 SYMBOLS Tariff Revision Symbols ................................................................................................. 2 GS-1 General Service Single-Phase < 50 KVA ..................................................................... 3 EF-1 TOU Energy Flex Plan TOU…………………………………………..…….…… 3.1 GS-3 General Service Three-Phase < 50 KVA ..................................................................... 4 LCR Rider for Load Control on GS-1 and GS-3 .................................................................... 5 EVR Electric Vehicle Rider……………………………………………………………..………...7.1 LP <350 KVA Large Power 50-350 KVA .............................................................................................. 8 LP >350 KVA Large Power Over 350 KVA ....................................................................................... 9.2 LP-OFF Large Power Off-Peak ................................................................................................. 10 LP-OFF-CF Large Power Off-Peak – City of Fayetteville ............................................................... 13 LTG-MUN Street Lighting – Municipal .......................................................................................... 14 LTG Security Lights ............................................................................................................. 15 ADJ Billing Adjustments ................................................................................................... 21.4 CHARGES Charges Related to Customer Activity ........................................................................ 22 EXT-PB #34 Single-Phase Line Extension (up to 50 kVA) .............................................................. 24 NST Notice of Suspension to Tenants ................................................................................ 26 LEVEL Levelized Billing Plan I ................................................................................................. 27 LEVEL Levelized Billing Plan II ............................................................................................. 27.2 LEVEL Pre-Pay Electric Service Program ............................................................................ 27.3 POLES Pole Identification ........................................................................................................ 28 TESTS Meter Test Programs ................................................................................................... 29 NOM-VOLT Standard Nominal Voltage........................................................................................... 30 Ext. Ab.P.P. Extended Absence Payment Plan ............................................................................... 31 Ext. D.D.P. Extended Due Date Plan ............................................................................................. 32 VOLT Voltage Verification Plan ............................................................................................. 35 EXT-PB #30 Three-Phase and Over 50 kVA Single-Phase Line Extension .................................... 36 EXT-PB #45 Subdivision Line Extension.......................................................................................... 38 NET Net Metering ........................................................................................................... 44.1a SURGE Surge Help® Insurance ..................................................................................... 45 ELCCP Emergency Load Conservation and Curtailment Plan ................................................. 48 O.N.E. SOLAR Ozarks Natural Energy Solar Program ........................................................................ 49

APSC FILED Time: 12/15/2021 8:00:19 AM: Recvd 12/14/2021 5:19:44 PM: Docket 21-106-TF-Doc. 5

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Replacing 1 st Revision SheetNo. 1


Kind of Service: Electric Class of Service: All Classes

Schedule No.: Exempt

Title: EXEMPTION SCHEDULE

F" c nLLD

PSC File Mark Only

LATE PAYMENT CHARGES AND DUE DATES CT / RT

Ozarks Electric Cooperative Corporation (OECC) currently has an exemption to Rule 5.05 of Arkansas Public Service Commission General Service Rules. The current exemption is referenced in Docket No. 86- 162-U, page 3. The original exemption for the stated reference is found in Docket No. 81-186-U.

The exemption basically states that OECC may impose a late charge of $4.93 per month upon each customer who fails to pay his or her bill prior to fifteen (15) days after the mailing date of the bill.

TRANSFERRING PAST DUE BALANCES TO OTHER ACCOUNTS, GSR 5.21

Ozarks Electric Cooperative Corporation (OECC) currently has an exemption from Rule 5.21 as stated in the following paragraph:

The exemption to the rule exists when OECC receives a written request from any customer, of any class, to have a balance transferred to the requesting customer's account, and when the following information is stated in the request:

(1)

(2) (3)

Name and account number of the customer requesting that a balance is to be transferred to their account; Name and account number of the customer whose balance is to be transferred; and A statement that the requesting customer understands that their own service may be terminated for non-payment if the transferred balance is not paid in full in accordance with any agreed upon payment arrangements.


1 Revision SheetNo. 2 Replacing Oriainal Sheet No. 2



Schedule No.: Svmbols

Title: TARIFF REVISION SYMBOLS

(DR) (AT) (RT)

PSC File Mark Only

Discontinued rate Additions to text Removal of text

TARIFF REVISION SYMBOLS

Listed below are tariff revision symbols that will be used when Ozarks Electric Cooperative Corporation (OECC) files any revisions to this original tariff filing.

These symbols shall appear in the margin opposite the change or revision that is proposed by OECC.

Change in rate Change in practice Change in text New rate

I (c) I A correction I

- - . L"d ARKANSAS PUBLlC SER\IICE Cc_>fi, APPROVED


7th Revision Sheet No. 3_ Replacing 6th Revision Sheet No. 3_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: GS-1 Schedule No.: GS-1 Title: GENERAL SERVICE SINGLE-PHASE < 50 KVA

PSC File Mark Only


AVAILABILITY: Available to all General Service customers for all uses served single-phase, subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission (PSC) and to the rules of the PSC. The capacity of the individual motors served under this schedule shall not exceed 10 HP. The total load shall not exceed 50 kVA.

TYPE OF SERVICE: Single-phase, 60 cycles, at available secondary voltage. MONTHLY RATE: Service Availability Charge $22.00 May - October Billing Cycle: All kWh, per kWh $0.08990 November - April Billing Cycle: First 1000 kWh, per kWh $0.07990 Over 1000 kWh, per kWh $0.06990

TERMS OF PAYMENT: Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC’s billing adjustment schedule.

MINIMUM MONTHLY CHARGES:

The minimum monthly charge shall be the higher of the following charges plus Energy Cost Adjustment and Debt Cost Adjustment charges if any: 1. Service Availability charge of $22.00. ; or 2. The minimum monthly charge specified in the contract.

APSC FILED Time: 5/19/2016 4:12:24 PM: Recvd 5/19/2016 4:10:03 PM: Docket 87-159-U-Doc. 196

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1st Revision Sheet No. 3.1_ Replacing: Original


Kind of Service: Electric Class of Service: GS-1

Schedule No.: EF-1 TOU

Title: ENERGY FLEX PLAN TOU PSC File Mark Only


AVAILABILITY:

Available to all General Service customers for all uses served single-phase, subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission (PSC) and to the rules of the PSC. The capacity of the individual motors served under t his schedule shall not exceed 10 HP. The total load shall not exceed 50 kVA. This rate is offered on an experimental basis with participation limited to 1,000 members.

TYPE OF SERVICE:

Single-phase, 60 cycles, at available secondary voltage.

MONTHLY RATE: Service Availability Charge $ 22.00 June-September Billing Cycle:

Energy Flex Plan On Peak Usage (3:00 pm to 7:00 pm) First 100 kWh per kWh $0.0899 Excess kWh per kWh $0.4000

Energy Flex Plan Off Peak (7:01 pm to 2:59 pm) $0.0650

October-May Billing Cycle: All kWh $0.0650

BEST BILL PROVISION: At the conclusion of one year of service under this tariff, the member’s billing will be compared to billing for the same period under the General Service 1-Phase rate. If the amount actually paid by the member is higher than what would have been paid under the General Service 1-Phase rate, the member will receive a credit for the full amount of the difference. This provision will only be applied at the end of the initial year of service and will not be available in ensuing years.

TERMS OF PAYMENT:

Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC’s billing adjustment schedule.

APSC FILED Time: 11/17/2021 2:11:26 PM: Recvd 11/17/2021 1:51:13 PM: Docket 21-106-TF-Doc. 2

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1st Revision Sheet No. 3.2_ Replacing: Original



Schedule No.: EF-1 TOU

Title: ENERGY FLEX PLAN TOU PSC File Mark Only


MINIMUM MONTHLY CHARGES:

The minimum monthly charge shall be the higher of the following charges plus Energy Cost Adjustment and Debt Cost Adjustment charges if any:

1. Service Availability charge of $22.00; or2. The minimum monthly charge specified in the contract.

TERM OF SERVICE:

The initial term of service for this tariff is one year. After the initial term, the member will automatically continue service under this tariff until the member selects another tariff by giving a 30-day notice to the Cooperative. If the thirtieth day of the notice period does not fall on the last day of the month, service will continue under this tariff through the next billing period. If a member terminates service under this tariff, the member will not be eligible to receive service under this tariff for a period of twelve (12) revenue months from the termination date.


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6th Revision Sheet No. 4_ Replacing 5th Revision Sheet No. 4_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: GS-3 Schedule No.: GS-3 Title: GENERAL SERVICE THREE-PHASE < 50 KVA

PSC File Mark Only


AVAILABILITY: Available to all General Service customers for all uses served three-phase, subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission (PSC) and to the rules of the PSC. The total load shall not exceed 50 kVA.

TYPE OF SERVICE: Three-phase, 60 cycles, at available secondary voltage.

MONTHLY RATE: Service Availability Charge $50.00 May - October Billing cycle: First 2000 kWh, per kWh $0.10920 Over 2000 kWh, per kWh $0.09730 November - April Billing Cycle: First 2000 kWh, per kWh $0.10070 Over 2000 kWh, per kWh $0.08730

TERMS OF PAYMENT: Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC’s billing adjustment schedule.


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1’‘ Revision SheetNo. 5 Replacing Oriainal SheetNo. 5



Schedule No.: LCR

Title: RIDER FOR LOAD CONTROL ON GS-1 AND GS-3 PSC File Mark Onlv

AVA I LAB I LlTY: CT Available only to existing customers of the Cooperative who (1) are supplied electric service by the Cooperative under standard rate schedules GS-1 (General Service Single-phase) and GS-3 (General Service Three-phase), and (2) currently participate and comply with the special conditions as stated below.

MONTHLY RATE: CT On bills computed for only the three revenue months of July, August and September (generally, bills mailed during those three months), a credit calculated as follows shall be allowed from the monthly billing otherwise established under the standard rate schedules GS-1 and GS-3, except that this credit shall not reduce the amount of the minimum bill.

Credit (if billed under either the GS-1 or GS-3 rate schedule): $5.00 per month per air conditioner connected for three months, but not to exceed thirty percent (30%) of the customer’s bill, excluding the Customer Charge and taxes, before application of the credit.

SPECIAL CONDITIONS: CT / AT The following provisions must be met in order for the customer to be billed under this special rider:

The customer shall have installed a central air condition system with an electrically-driven compressor rated at 36,000 Btu or more, in good operating condition and in regular use for air conditioning during the summer season.

1.

2. The Cooperative or its authorized agents shall be permitted to install control devices and other required facilities on the customer’s premises and on the customer’s air conditioning compressor. The facilities furnished by the Cooperative shall remain the property of the Cooperative.

3. The Cooperative shall be permitted without notice or restraint to interrupt electric service to the air conditioning compressor for periods of approximately seven and one half (7.5) minutes of each thirty (30) minute period during peak load periods (generally periods with an ambient temperature of 93 degrees F. and above) from June 1 through September 30.


ARKANSAS PUBLIC SERVICE CC" " " "

1'' Revision Replacing Oriainal

SheetNo. 6 Sheet No. 6



Schedule No.: LCR

Title: RIDER FOR LOAD CONTROL ON GS-1 AND GS-3 PSC File Mark Onlv

4. The customer shall give authorized agents of the Cooperative permission to enter the customer's premises at all reasonable times to install, maintain, repair, test, or remove its control devices and other required facilities.

5. The customer shall be responsible for the maintenance and repair of the air conditioning system to ensure proper operation of the system.

6. The Cooperative shall not be responsible for the repair or maintenance of the customer's air conditioning unit. The Cooperative shall only be responsible for the repair and maintenance of the installed control unit. Upon removal of the control unit by the Cooperative, the air conditioning unit shall be returned to its "as found" condition by the Cooperative, excluding normal wear that would have occurred irrespective of installation of the control device.

7 . Any alteration of the Cooperative's control device or other required facilities by other than the Cooperative's authorized agents shall be considered tampering. If there is evidence of tampering, the customer shall reimburse the Cooperative for the cost of all repairs or replacement of its control devices and other required facilities; and shall also repay the credit applied to the customer's bill in accordance with Rule 5.19 of the PSC's General Service Rules. In such cases, the Cooperative may, at its option and without prior written notice, cancel the agreement and remove its control devices and other required facilities.

8. In the event the customer requests the removal of the control device during the billing months of July, August or September, the customer shall pay to the Cooperative the amount of any credit previously made on the customer's bill during said billing months of the current year.

9. In the event the customer is not the owner of the building and/or the air conditioning unit(s), the customer shall furnish the Cooperative written consent of the owner of said unit(s) for the installation of the control device prior to installation.

10. The customer shall promptly notify the Cooperative of the removal, replacement and/or damage to the air conditioning unit(s) or the control device.

1 st Revision SheetNo. 7 Replacing Oriuinal SheetNo. 7


Kind of Service: Electric Class of Service: AI1 Classes

Schedule No.: LCR

Title: RIDER FOR LOAD CONTROL ON GS-1 AND GS-3

OTHER PROVISIONS:

PSC File Mark Only

RT All provisions of the standard rate schedules for General Service Single-phase (GS-1) and General Service Three-phase (GS-3) and terms and conditions of service that are not specifically changed by this Rider shall remain in full force and effect.



First Revision Sheet No. 7.1_ Replacing: Original


Kind of Service: Electric Class of Service: GS-1 and GS-3

Schedule No.: EVR

Title: ELECTRIC VEHICLE RIDER PSC File Mark Only


AVAILABILITY:

Available to all General Service customers for Electric Vehicle Charging. All members taking service under this rider must have a Cooperative approved Level 2 charger with time-clock charging capability. To remain eligible, the Level 2 charger must remain programmed to charge during the Electric Vehicle Charging period defined below. The cooperative will periodically verify that the programming remains in compliance and notify customer of non-compliance. A second instance of non-compliance will result in termination of eligibility.

TYPE OF SERVICE:

Single-phase or three-phase, 60 cycles at secondary voltage.

MONTHLY RATE:

The standard General Service rate shall be applicable for all periods during the month other than the Electric Vehicle Charging period.

The Electric Vehicle Charging Period shall be defined as the period from 10:00 pm to 5:00 am daily. During the Electric Vehicle Charging Period the following rate shall apply:

EV Energy Charges First 400 kWh per month $0.050 per kWh All Excess kWh At the Standard Rate

TERMS OF PAYMENT:

Bills rendered under this schedule will be adjusted as appropriate for changes listed under OECC’s billing adjustment schedule.


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6th Revision Sheet No. 8_ Replacing 5th Revision Sheet No. 8_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: Large Power Schedule No.: LP <350 KVA Title: LARGE POWER 50-350 KVA

PSC File Mark Only


AVAILABILITY: Available to customers located on or near the Cooperative’s distribution lines for all types of usage where the installed transformer capacity exceeds 50 kVA, but is less than 350 kVA, subject to the tariffs of the Cooperative as approved by and filed with the PSC and to the Rules of the PSC.

TYPE OF SERVICE: Single-phase or three-phase, 60 cycles, at Cooperative’s standard voltages.

MONTHLY RATE: Service Availability Charge $100.00 NCP Demand - $/NCP kW $3.00 First 150 kWh per kW $0.10180 Excess kWh per kW $0..05220 DETERMINATION OF NCP BILLING DEMAND: The NCP billing demand shall be the maximum kilowatt demand established by the customer for any period of fifteen (15) consecutive minutes during the month for which the bill is rendered as indicated or recorded by a demand meter and adjusted for power factor as provided below, but not less than the maximum billing demand established by the customer during the previous four (4) month summer season of June, July, August and September.


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1 st Revision Replacing Oriclinal

Kind of Service: Electric Class of Service: Larue Power

Schedule No.: LP ~ 3 5 0 KVA

Title: LARGE POWER 50-350 KVA

Sheet No. 9 Sheet No. 9

PSC File Mark Only

APR 26 IO 44 AM ’01

- g I ) . b 5 fr. t . Ern* *u


POWER FACTOR ADJUSTMENT:

CT

AT The customer agrees to maintain unity power factor as nearly as practicable. The demand will be adjusted to correct for power factors lower than ninety percent (90%). Such adjustments will be made by multiplying the metered demand by ninety percent (90%) and dividing by the actual power factor metered to determine billing demand.

MINIMUM MONTHLY CHARGE: The minimum monthly charge shall be the highest of the following charges:

The minimum monthly charge specified in the contract for service; A charge of $1 .OO per kVA of installed transformer capacity; or The demand charge determined by the billing demand above.

1. 2. 3.

SERVICE P R O V E IONS : 1. Delivery Point. If service is furnished at secondary voltages, the delivery point shall be the

metering point, unless otherwise specified in the contract for service. All wiring, pole lines, and other electric equipment on the load side of the delivery point shall be owned and maintained by the customer.

If the service is furnished at the Cooperative’s primary line voltage, the delivery point shall be the point of attachment of the Cooperative’s primary line to customer’s transformer structure, unless otherwise specified in the contract for service. All wiring, pole lines, and other electric equipment (except metering equipment) on the load side of the delivery point shall be owned and maintained by the customer.

2. Primary Service. At the option of the customer, there will be a discount of three percent (3%) of the kilowatt-hour charge only on all monthly bills, provided service is supplied at the Cooperative’s primary distribution voltage (12.5 kV or above) and the customer furnishes and maintains all necessary transformation beyond this point.


ARKANSAS PUBLIC SERVICE COMMISSION APPROVE0

ARKANSAS PUBLIC SERVICE CC

Oriainal Sheet No. 9.1 Replacing Sheet No.


Kind of Service: Electric Class of Service: Larae Power

Schedule No.: LP e350 KVA

Title: LARGE POWER 50-350 KVA PSC File Mark Only CT

TERMS OF PAYMENT: Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC's Billing Adjustment Schedule.


ARKANSAS PUBLlC SERVICE COMMISSIOh APPROVED


5th Revision Sheet No. 9.2_ Replacing 4th Revision_ Sheet No. _9.2_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: Large Power Schedule No.: LP >350 KVA Title: LARGE POWER OVER 350 KVA

PSC File Mark Only


AVAILABILITY: Available to customers located on or near the Cooperative’s distribution lines for all types of usage where the installed transformer capacity exceeds 350 kVA, subject to the tariffs of the Cooperative as approved by and filed with the PSC and to the Rules of the PSC.

TYPE OF SERVICE: Single-phase or three-phase, 60 cycles, at Cooperative’s standard voltages.

MONTHLY RATE: Service Availability Charge $260.00 NCP Billing Demand - $/NCP kW $3.00 First 150 kWh per kW $0.09490 Excess kWh per kW $0.05160 DETERMINATION OF NCP BILLING DEMAND: The NCP billing demand shall be the maximum kilowatt demand established by the customer for any period of fifteen (15) consecutive minutes during the month for which the bill is rendered as indicated or recorded by a demand meter and adjusted for power factor as provided below, but not less than the maximum billing demand established by the customer during the previous four (4) month summer season of June, July, August and September.


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I Title: LARGE POWER OVER 350 KVA

I Kind of Service: Electric Class of Service: Larae Power

I PSC File Mark Only

Schedule No.: LP ~ 3 5 0

NR

POWER FACTOR ADJUSTMENT: The customer agrees to maintain unity power factor as nearly as practicable. The demand will be adjusted to correct for power factors lower than ninety percent (90%). Such adjustments will be made by multiplying the metered demand by ninety percent (90%) and dividing by the actual power factor metered to determine billing demand.

MINIMUM MONTHLY CHARGE: The minimum monthly charge shall be the highest of the following charges:

The minimum monthly charge specified in the contract for service; A charge of $1 .OO per kVA of installed transformer capacity; or The demand charge determined by the billing demand above.

1. 2. 3.

S E RVlC E PROVE IONS : 1. Delivery Point. If service is furnished at secondary voltages, the delivery point shall be the

metering point, unless otherwise specified in the contract for service. All wiring, pole lines, and other electric equipment on the load side of the delivery point shall be owned and maintained by the customer.

If the service is furnished at the Cooperative’s primary line voltage, the delivery point shall be the point of attachment of the Cooperative’s primary line to customer’s transformer structure, unless otherwise specified in the contract for service. All wiring, pole lines, and other electric equipment (except metering equipment) on the load side of the delivery point shall be owned and maintained by the customer.

2. Primary Service. At the option of the customer, there will be a discount of three percent (3%) of the kilowatt-hour charge only on all monthly bills, provided service is supplied at the Cooperative’s primary distribution voltage (12.5 kV or above) and the customer furnishes and maintains all necessary transformation beyond this point.


ARKANSAS PUBLIC SERVICE COMMISSION APPROVED

APR302001 ORON 112 99-25O-U



Kind of Service: Electric Class of Service: Larae Power

Schedule No.: LP >350

Title: LARGE POWER OVER 350 KVA PSC File Mark Only NR

TERMS OF PAYMENT: Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC's Billing Adjustment Schedule.




9th Revision Sheet No. 10_ Replacing 8th Revision_ Sheet No. _10_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: Large Power Schedule No.: LP OFF_ Title: LARGE POWER OFF-PEAK

PSC File Mark Only


AVAILABILITY: This rate schedule is available to all existing Large Power Off Peak customers as of the date of approval of this tariff and new customers requiring 300 kVA or less of transformer capacity with a monthly load factor of 30% or higher located along or near the Cooperative’s existing distribution lines. This rate reflects the current conditions with regard to system load characteristics and therefore the cooperative reserves the right to discontinue this tariff at any time by making a tariff filing with the Commission. However, existing Agreements for electric service will continue for the term set forth in the Agreement. TYPE OF SERVICE: Three-phase or single phase, 60 Hertz, at the Cooperative’s standard voltages. MONTHLY RATE: Service Availability Charge $198.00 NCP Billing Demand - $/NCP kW $3.00 On-Peak Billing Demand - $/On-Peak kW $13.25 Energy Charge - $/kWh $0.04570 DETERMINATION OF NCP BILLING DEMAND: The NCP billing demand shall be the maximum kilowatt demand established by the customer for any period of fifteen (15) consecutive minutes during the month for which the bill is rendered as indicated or recorded by a demand meter and adjusted for power factor as provided below, but not less than the maximum billing demand established by the customer during the previous four (4) month summer season of June, July, August, and September.


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ARKANSAS PUBLIC SERVICE CI

5th Revision Sheet No. 11 Sheet No. 11 Replacing 4th Revision

The on-peak billing demand shall be the highest demand established by the customer coincident with each AECC monthly coincident peak during the most recent months of June, July, August and September as indicated or recorded by a demand meter and adjusted for power factor as indicated


CT

Kind of Service: Electric Class of Service: Large Power

Schedule No.: LP-OFF

Title: LARGE POWER OFF-PEAK PSC File Mark Only


The customer agrees to maintain unity power factor as nearly as practicable. The demand will be adjusted to correct for power factors lower than ninety percent (90%). Such adjustments will be made by multiplying the metered demand by ninety percent (90%) and dividing by the actual power factor metered to determine billing demand.

MINIMUM MONTHLY CHARGE:

The minimum monthly charge shall be the highest of the following charges:

1.

2.

3.

The minimum monthly charge specified in the contract for service;

A charge of $1 .OO per kVA of installed transformer capacity; or

The demand charge determined by the billing demand above.

SERVICE PROVISION:

1. Delivery Point. If service is furnished at secondary voltage, the delivery point shall be the metering point, unless otherwise specified in the contract for service. All wiring, pole lines, and other electric equipment on the load side of the delivery point shall be owned and maintained by the customer.

If the service is furnished at the Cooperative’s primary line voltage, the delivery point shall be the point of attachment of the Cooperative’s primary line to the customer‘s transformer structure, unless otherwise specified in the contract for service. All wiring, pole lines, and other electric equipment (except metering equipment) on the load side of the delivery point shall be owned and maintained byth u tom r

WhtANiiAS PUBLIC SERVICE COMMISSION APPROVED

MAY 3 1 2006 OHDM 2 . 0 6 0 3 5 T F

ARKANSAS PUBLIC SERVICE C1

5th Revision Sheet No. 12 Sheet No. 12 Replacing 4th Revision


Kind of Service: Electric Class of Service: Large Power

Schedule No.: LP-OFF

Title: LARGE POWER OFF-PEAK PSC File Mark Only

2. Primary Service. At the option of the customer, there will be a discount of three percent (3%) of the kilowatt-hour charge only on all monthly bills, provided service is supplied at the Cooperative's primary distribution voltage (1 2.5 kV or above) and the customer furnishes and maintains all necessary transformation beyond this point.

CONTRACT PERIOD:

As set forth in the Agreement for Electric Service. I AT

TERMINATION OF SERVICE:

If service is terminated at the request of the consumer or through non-payment for service, all on-peak billing demand charges previously established that would have been billed had service continued shall be due and payable upon such termination.

AT

TERMS OF PAYMENT:

Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC's Billing Adjustment Schedule.

ARKANSAS PUBLIC SERVICE COMMlSSlON APPROVED

MAY 3 1 2006 O K U ~ K 2 . 0 6 0 3 5


4th Revision Sheet No. 13_ Replacing 3rd Revision_ Sheet No. ____ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: Large Power Schedule No.: LP-OFF - CF_ Title: LARGE POWER OFF-PEAK – City of Fayetteville

PSC File Mark Only


AVAILABILITY: This rate schedule is available to the City of Fayetteville’s West Side Waste Water Treatment Facility and Hamstring Sewer Lift Station in Washington County, Arkansas. TYPE OF SERVICE: Three-phase or single phase, 60 Hertz, at the Cooperative’s standard voltages. MONTHLY RATE: Service Availability Charge $260.00 NCP Billing Demand - $/NCP kW $4.00 On-Peak Billing Demand - $/On-Peak kW $13.50 Energy Charge - $/kWh $0.04730 DETERMINATION OF NCP BILLING DEMAND: The NCP billing demand shall be the maximum kilowatt demand established by the customer for any period of fifteen (15) consecutive minutes during the month for which the bill is rendered as indicated or recorded by a demand meter and adjusted for power factor as provided below, but not less than the maximum billing demand established by the customer during the previous four (4) month summer season of June, July, August, and September. DETERMINATION OF ON-PEAK BILLING DEMAND: The on-peak billing demand shall be the highest demand established by the customer coincident with each AECC monthly coincident peak during the most recent months of June, July, August and September as indicated or recorded by a demand meter and adjusted for power factor as indicated below.


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ARKANSAS PUBLIC SERVICE COMMISSION- .; :Mi.f.

,. I ., I ;3 33 A8 '08 Otiainal Sheet No. 13.1 indI I


Kind of Service: Electric Class of Service: Lame Power - * - . . L e

Schedufe No.: LP-OFF- CF

Title: LARGE POWER OFF-PEAK - City of FayettevilIe PSC File Mark OnIy


The customer agrees to maintain unity power factor as nearIy as practicabIe. The demand will be adjusted to correct for powerfactors lower than ninety percent (90%). Such adjustments will be made by multiplying the metered demand by ninety percent(90%) and dividing by the actual power factor metered to determine billing demand.

M 1 N 1 MUM MONTHLY CHARGE: The minimum monthly charge shall be the highest of the following charges:

1. The minimum monthly charge specified in the contract for service; 2. A charge of $1 .OO per kVA of installed transformer capacity; or 3. The demand charge determined by the biIling demand above.

SERVICE PROVISION:

1. Delivery Point. If service is furnished at secondary voltage, €he delivery point shall be the metering point, unless otherwise specified in the contract for service. AI! wiring, pole lines, and other electric equipment on €he load side of the delivery point shall be owned and maintained by the customer.

If the service is furnished at the Cooperative's primary line voltage, the delivery point shall be the point of attachment of the Cooperative's primary line to the customer's tFansformer structure, unless otherwise specified in the contract for service. All wiring, pole lines, and other electric equipment (except metering equipment) on the load side of the delivery point shall be owned and maintained by the customer.

2. Primary Service. At the option of the customer, there will be a discount of three percent (3%) of the kilowatt-hour charge only on all monthly bills, provided senrice is supplied at the Cooperative's primary distribution voltage (1 2.5 kV or above) and the customer furnishes and maintains all necessary fransfomation beyond this point.

THE SPACE FOR PSC US€ ONLY


Orisinal Sheet No. 13.2


1 13 K1’fll

.-. . , , -.: ij . -L

I 1 Kind of Service: Electric Class of Service: Larqe Power

I Schedule No.: LP-OFF- CF

Title: LARGE POWER OFF-PEAK - City of Fayeffeville PSC File Mark Only

TERMINATION OF SERVICE:

If service on this rate is terminated at the request ofthe consumer or through non-payment for service, all on-peak billing demand charges previously established that would have been billed had senrice continued shall be due and payable upon such termination. Service may be provided under the applicable standard rate schedule after termination of service on this rate. Service under this rate scheduIe shall not be available for twelve months after termination of service on this rate.

TERMS OF PAYMENT: Bills rendered for sewice under this schedule will be adjusted as appropriate for charges listed under OECC’s Billing Adjustment Schedule.



JUN - 2 2008 ORDER 2 0 8 080 - P


6th Revision Sheet No. 14_ Replacing 5th Revision__ Sheet No. _14_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: Municipal Schedule No.: LTG-MUN_ Title: STREET LIGHTING - MUNICIPAL

PSC File Mark Only


AVAILABILITY: This rate schedule is available for municipal street lighting service in any community in which the Cooperative has a franchise for the generation, distribution and sale of electric energy. TYPE OF SERVICE: The Cooperative will furnish, install, own, operate, and perform normal and reasonable maintenance on the street lights contracted for and the customer will receive and pay for this service according to the schedule below. The lights shall burn every night from dusk to daylight. MONTHLY RATE:

250 Watt High Pressure Sodium Cobra $8.10

400 Watt High Pressure Sodium Cobra $12.75

6,800 Nominal Lumens - 175 Watt MVL (Closed) $6.40

11,000 Nominal Lumens - 250 Watt MVL (Closed) $8.10

20,000 Nominal Lumens - 400 Watt MVL (Closed) $11.75 The Cooperative will invest up to but not exceed the following amounts per lamp:

6,800 Nominal Lumens $110.00

11,000 Nominal Lumens $125.00

20,000 Nominal Lumens $165.00 The customer will be responsible for reimbursement to OECC for investment for facilities in excess of the above-stated amount. TERMS OF PAYMENT: Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC’s Billing Adjustment Schedule.


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6th Revision Sheet No. 15_ Replacing 5th Revision__ Sheet No. _15_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: LTS_ Title: SECURITY LIGHTS

PSC File Mark Only


AVAILABILITY: Available to all customers for security light service. TYPE OF SERVICE: Single-phase, 60 cycles, from existing facilities. MONTHLY RATE:

175 Watt MVL (Closed) $6.40

100 Watt HPS $6.40

250 Watt HPS Cobra $8.10

400 Watt HPS $16.55

400 Watt HPS Cobra $12.75

1000 Watt HPS $31.65

400 Watt metal Halide $16.55

1000 Watt Metal Halide $31.65

100 Watt HPS Equivalent LED $6.40

Additional Pole Charges - 30ꞌ Class 6 Pole $5.00


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3rd Revision Sheet No. 15.1_ Replacing 2nd Revision__ Sheet No. _15.1_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: LTG-MV_ Title: SECURITY LIGHTS –

PSC File Mark Only


The Cooperative will invest up to, but not exceed, the following amounts per lamp: 45,000 Nominal Lumens $330.00 125,000 Nominal Lumens $475.00 The Cooperative will invest up to, but not exceed, the following amounts per pole: 30ꞌ Class 6 Pole $185.00 Excess Investment Charge: Cooperative-approved investment in excess of the above –stated amounts will be charged at the rate of 1.75% per month multiplied by the amount of the excess investment. CONDITIONS OF SERVICE: 1. The Cooperative will furnish and install at no expense to the customer afixture and pole at a

location within 70' of existing facilities suitable to both parties, will make all necessary electrical connections, and will furnish electricity for the unit which will be controlled by a photo cell. 2.The Cooperative will maintain the unit and replace the lamp when necessary. The customer will notify the nearest office when bulb replacement is required or when the fixture requires repair. Bulb replacement will be made within a reasonable time after the report is received.

3. The customer hereby agrees to furnish the location for the unit, to permit any tree trimming required for the conductors or unit installation or maintenance, and agrees that the unit, together with the poles and conductors, may be removed at any time upon failure to pay the charges set forth herein.

4. Further, the customer agrees to protect the unit from unusual damage. In the event of vandalism, the customer will be responsible for the cost of repairs or the contract will be terminated.

5. It is mutually agreed that the area lighting system, as installed, remains the property of the Cooperative and no customer-owned facilities can be attached to cooperative poles.

6. It is mutually agreed that the unit, as installed, remains the property of the Cooperative and will be removed at the request of the customer upon the anniversary date of the Agreement. The minimum such period shall be one year, for which the customer agrees to pay as set forth herein. The contract is automatically renewed for each year unless terminated by either party during the anniversary month.

TERMS OF PAYMENT:


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3rd Revision Sheet No. 15.1_ Replacing 2nd Revision__ Sheet No. _15.1_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: LTG-MV_ Title: SECURITY LIGHTS –

PSC File Mark Only


Bills rendered for service under this schedule will be adjusted as appropriate for charges listed under OECC’s Billing Adjustment Schedule.


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6th Revision Sheet No. 16_ Replacing 5th Revision__ Sheet No. _16_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: _ Title:

PSC File Mark Only


RESERVED FOR FUTURE USE.


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5th Revision Sheet No. 17_ Replacing 4th Revision_ Sheet No. _17_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: _ Title:

PSC File Mark Only




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5th Revision Sheet No. 18_ Replacing 4th Revision_ Sheet No. _18_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: _ Title:

PSC File Mark Only




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ARKANSAS PUBLIC SERVICE Cc

2nd Revision SheetNo. 19 Replacing 1 st Revision Sheet No. 19

Orarks Electric Cooperative Corporation Name of Company

Kind of Service: Electric Class of Service:

Schedule No.:

Title:


MMISSION#~~ b * 12 12 PM '

FILED

PSC File Mark Only

12

DR


ARKANSAS PUE3LlC SERVtCE COMMISSION APPROVED

N O V 2 5 2002 0B.R 12 02- 1 92 -T f

ARKANSAS PUBLIC SERVICE C

2nd Revision Sheet No. 20 Replacing 1 st Revision SheetNo. 20



Schedule No.:

Title:

WMlSSlON Mflv s 12 12 PP

%ED

PSC File Mark Only


'02

DR


ARKANSAS PUBLtC SERVICE COMMISSION APPROVE0

3rd Revision SheetNo. 21 Replacing 2nd Revision SheetNo. 21



Schedule No.:

Title: PSC File Mark Only


DR



MOV252002 ORDER 2 0 2 - 1 92-TF

ARKANSAS PUBLIC SERVICE C 1 Revision Sheet No. 21.1

Replacing Oriainal Sheet No. 21.1



Schedule No.:



I

DR



NOV252002 ORDER 12 02-1 92-Tf


1 Revision Sheet No. 21.2 Replacing Oriclinal Sheet No. 21.2



Schedule No.:

Title: I

MMlSSlO L IC ) - 1

PSC File Mark Only

FILED


'2

DR


ARKANSAS PWBLfC SERVtCE COMMISSION APPROVED

NOV252002 ORDER 12 02-1 92-TF

ARKANSAS PUBLIC SERVICE C 2nd Revision Sheet No. 21.3

Replacing 1 st Revision Sheet No. 21.3



Schedule No.:



I '02

DR


ARKANSAS PUBUC SERVICE COMMISSION APPROVED


5th Revision Sheet No. 21.4_ Replacing 4th Revision_ Sheet No. ______



Schedule No.: ADJ

Title: BILLING ADJUSTMENTS PSC File Mark Only


The Cost of Energy Adjustment excludes customers served under tariffs providing direct billing of wholesale power cost to customers. The factor shall be calculated monthly.

COST OF ENERGY ADJUSTMENT:

If the cost per kilowatt-hour (kWh) of energy to the Cooperative changes from the base cost of 39.118 mills per kWh purchased embedded in the Cooperative’s rates, the Cooperative shall increase or decrease its retail rates by an amount sufficient to compensate for the change. Such cost per kWh of energy shall include the per-kWh charges by its suppliers, the fuel cost adjustments and the AECC billing for TO/RTO charges billed by the Cooperative by its suppliers. No other costs shall be included in this adjustment. Any costs associated with the EMA and the City of Fayetteville net-metering facility proposed in Docket No. 19-003-U will not be included in the Energy Cost Adjustment before the demand savings are included in future base rates.

AT

APSC FILED Time: 5/31/2019 8:51:41 AM: Recvd 5/31/2019 8:50:10 AM: Docket 19-018-P-Doc. 27

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4th Revision Sheet No. 21.5_ Replacing 3rdd Revision_ Sheet No. ______ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: ADJ Title: BILLING ADJUSTMENTS

PSC File Mark Only


OZARKS ELECTRIC COOPERATIVE CORPORATION

UNIFORM ENERGY COST ADJUSTMENT FACTOR (UECAF) REPORT FORM

Billing Month of _________________________ Formula Total

A. kWh Purchased:

1 AECC

2 Other

3 Other

4 Total A1 + A2 + A3

B. Less: Line Losses:

1 Line Loss Percent (%)

2 kWh Losses A4 x B1

C. Cooperative's Own Use - kWh

D. Monthly kWh Sold:

1 Estimated kWh Sold A4 - B2 - C

2 Actual kWh Sold, Prior Months (per Ledgers)

3 Actual kWh Sold, This Month

E. Energy Cost - Current Month:

1 Energy (Total kWh Charges) $_________

2 Fuel (Total Fuel Adjustment Adders) $_________

3 EC1 Credit $_________

4 TO/RTO Rider Costs $_________

5 Total E1 + E2 + E3 + E4 $_________

F. Base Cost of Power:

1 kWh Purchased A4

2 Base Cost of Per kWh Purchased (Tariff) $0.039118

3 Base Power Cost F1 x F2 $_________

G. Over/Under Collections from Prior ECA:

1 Amount to be Recovered H (Prior Month) $_________

2 ECA Factor per kWh Sold I (Prior Month) $_________

3 Actual kWh Sold (Prior Month) D2

4 ECA Recovered (Prior Month) G2 x G3 (or Ledger Amt) $_________

5 Over/Under Recovery for Prior Period G1 - G4 $_________

H. Amount to Recover (This Month) E5 - F3 + G5 $_________

I. ECA Factor per kWh Sold (This Month) H / D1, or D3 $_________

Prepared by: _______________________________ Phone No. ____________________


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1st Revision l Sheet No. 21.6_ Replacing __Original__________ Sheet No. ______ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: Schedule No.: Title:

PSC File Mark Only


RESERVED FOR FUTURE USE


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1st Revision l Sheet No. 21.7_ Replacing __Original__________ Sheet No. ______ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: ADJ Title: BILLING ADJUSTMENTS

PSC File Mark Only


COST OF DEBT ADJUSTMENT AND FORM COST OF DEBT ADJUSTMENT: If the cost of debt to the Cooperative changes from the annual interest of $6,005,146 embedded in the Cooperative’s base rates, then the Cooperative shall increase or decrease its retail rates by an amount sufficient to compensate for the change. A factor shall be computed quarterly and shall be applied monthly as a line item on each customer’s bill and shall be reported to the Commission through the “Quarterly Cost of Debt Adjustment Report.” The calculation of the factor shall be based on estimated kWhs for the billing quarter over to the next quarter’s factor determination.


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Replacing Sheet No.

Ozarks Electric Cooperative Corporation


Schedule No.: ADJ

Name of Company


COST OF DEBT ADJUSTMENT (CODA) FORM

Submitted by: OZARKS ELECTRIC COOPERATIVE CORPORATION

Address: PO Box 848, Fayetteville, Arkansas 72702

1 Date of Report

2

3

4

Adjustment Rate to Apply to Consumer's Bills dated

Calculations Based on Cost of Debt for Quarter Ended

Outstanding Long-Term Debt and Cost of Debt this Quarter:

(5) (6) (7) (8) Total

Type of Outstanding Annual Annual - Debt Debt Balance - Rate - cost

% $ $

$ % $

Less CFC Performance Discount $

$

Less CFC Volume Discount $ $

$

Less Amortization of Fees per RUSlCFC Debt Conversion $

Less CFC Collateral Discount

Plus CFC Forward Rate Lock Premium

$ Totals

(9) Total

Cost of Debt Paid This Quarter

$

CT

CT


ARWNSAS PUBUC SERVICE COMMISSION APPROVED


1st Revision Sheet No. 21.9_ Replacing _Original ___________ Sheet No. ______ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: ADJ Title: BILLING ADJUSTMENTS

PSC File Mark Only


10 Total Company Cost of Debt Paid this Quarter (Col. 9 Total): $____________ 11 Total Company Cost of Debt Paid Adjusted for Arkansas Jurisdiction (L10 * 82.91%) $____________ 12 Arkansas Jurisdiction Cost of Debt in Base Rates $6,005,146 13 Arkansas Jurisdiction Cost of Debt in Base Rates (L12 x (Days in Qtr/365)) 14 Arkansas Jurisdiction Cost of Debt Adjustment this Quarter (L11 - L13) $____________ 15 L14 x TIER Level of 2.10: $____________ 16 Arkansas Jurisdiction Cost of Debt Adjustment Authorized for Collection prior to Quarter $____________ 17 Arkansas Jurisdiction Less Cost of Debt Adjustment Collected prior Quarter $____________ 18 Arkansas Jurisdiction Over/Under Collected Cost of Debt Adjustment previous authorized $____________ 19 Total Cost of Debt Adjustment Authorized for Collection this Quarter (L15 +/- L18) $____________ 20 Estimated kWh Sales for Billing Quarter _____________ 21 Cost of Debt Adjustment Rate for This Quarter (L19 / L20) $_______ / kWh

Notes: (a) Number of days in quarter in which adjustment is to occur: __________________________________________ ______________________________ Person Completing Report Telephone Number


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Original Sheet No. 21.10_ Replacing ____________ Sheet No. ______ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: ADJ Title: BILLING ADJUSTMENTS

PSC File Mark Only


LIGHTING RATES In calculating the billing adjustments for the Lighting Rates, the following kilowatt-hours shall be used: 100 Watt HPS 8,500 nominal lumens = 42 kWh / Month 100 Watt HPS Equivalent LED 5,000 nominal lumens = 20 kWh / Month 175 Watt MVL 6,800 nominal lumens = 75 kWh / Month 250 Watt MVL 11,000 nominal lumens = 107 kWh / Month 400 Watt HPS 45,000 nominal lumens = 164 kWh / Month 400 Watt MVL 20,000 nominal lumens = 171 kWh / Month 1000 Watt HPS 126,000 nominal lumens = 390 kWh / Month


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1st Revisions Sheet No. 21.11_ Replacing __Original__________ Sheet No. ______ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: ADJ Title: BILLING ADJUSTMENTS

PSC File Mark Only


TAX ADJUSTMENTS: The Cooperative shall add as separate lines on the bill any sales, excise, license, privilege, or franchise taxes (excludes ad valorem and income taxes) that the Cooperative may have to pay or collect according to ordinances or laws. Such adjustments shall be collected in the same manner in which they are incurred and shall be applied only within jurisdictional boundaries of the taxing bodies. The tax rates applied by each taxing authority are shown in Attachment A to this tariff. Attachment A will be revised and provided to the APSC as necessary to reflect new or modified tax rates. Changes in the rate of tax adjustment will be filed with the Arkansas PSC.


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Effective: 6/1/2016 Attachment A to Sheet No. 21.11


Attachment A

Tax Adjustments Table of Taxing Authority Rates

Municipal Tax by City

ELKINS FRANCHISE TAX 2.00% ELM SPRINGS FRANCHISE TAX 2.00% FARMINGTON FRANCHISE TAX 4.25% FAYETTEVILLE FRANCHISE TAX 3.00% FAYETTEVILLE LP FRANCHISE TAX 1.00% GOSHEN FRANCHISE TAX 3.00% GREENLAND FRANCHISE TAX 2.00%

JOHNSON FRANCHISE TAX 2.00% LINCOLN FRANCHISE TAX 4.25% PRAIRIE GROVE FRANCHISE TAX 4.25% SPRINGDALE FRANCHISE TAX 4.00% SPRINGDALE LP FRANCHISE TAX 1.00% ST PAUL FRANCHISE TAX 2.00% TONTITOWN FRANCHISE TAX 2.00% WEST FORK FRANCHISE TAX 4.25%

Arkansas Gross Receipts (Sales) Taxes

STATE OF ARKANSAS 6.50% BENTON COUNTY TAX 1.00%

CRAWFORD COUNTY TAX 1.75% FRANKLIN COUNTY TAX 1.50% MADISON COUNTY TAX 2.00% WASHINGTON COUNTY TAX 1.25% ELKINS TOWN TAX 2.75% ELM SPRINGS TOWN TAX 1.00% FARMINGTON TOWN TAX 2.00% FAYETTEVILLE TOWN TAX 2.00% GREENLAND TOWN TAX 2.00%

JOHNSON TOWN TAX 2.00% LINCOLN TOWN TAX 2.00%

PRAIRIE GROVE TOWN TAX 2.25% SPRINGDALE TOWN TAX 2.00% TONTITOWN TOWN TAX 2.00% WEST FORK TOWN TAX 2.00%


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1st Revision Sheet No. 21.12_ Replacing Original____________ Sheet No. ______ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: ADJ Title: BILLING ADJUSTMENTS

PSC File Mark Only


TERMS OF PAYMENT: Bills are due within fourteen (14) days of the mailing date. If not paid by the due date, a late charge of $4.93 per bill will be require d to cover increased costs due to the late payment.


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4th Revision Sheet No. 22_ Replacing 3rd Revision Sheet No. _22_ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: CHARGES Title: CHARGES RELATED TO CUSTOMER ACTIVITY

PSC File Mark Only

1. Membership Fee:

Each corporation, partnership, individual firm, or individual shall register to become a member of the Cooperative in advance of receiving service. There is no fee associated with membership.

2. Non-negotiable Check Fee:

A fee will be assessed to any account for which a check which is not negotiable has been tendered to the Cooperative for payment of charges owed. The fee shall be the maximum collection fee amount permitted under Arkansas Statute 4-60-103.

3. Collection Fee: $40.00

The Cooperative will charge a fee when the last day to pay, as printed on the most recent shut-off notice, has passed and an OECC employee either accepts payment at the premises under PSC GSR 6.09.B(1) or visits the premises at the customer’s request to collect.

4. Reconnect Fee: $40.00

The Cooperative will charge a fee when a customer that has been disconnected for non- payment requests an OECC employee to reconnect service during the normal working hours between 8:00 a.m. and 4:00 p.m., Monday through Friday.

5. After Hours Reconnect Fee: $60.00

The Cooperative will charge a fee when a customer that has been disconnected for non- payment requests an OECC employee to reconnect service during other than normal working hours or on a holiday.

6. Trip Fee: $40.00

The Cooperative will charge a fee when a customer requests a service trip by an OECC employee to the consumer’s premises. In the event the OECC facilities are the cause of the service request, no such charge shall be made.

CR CT CT

C


APSC FILED Time: 2/18/2014 8:23:02 AM: Recvd 2/17/2014 1:06:20 PM: Docket 14-016-TF-Doc. 1

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No.

- 2

I ARKANSAS PUBLIC SERVICE COMMI&&~N .-..C% i t l l .

Title: CHARGES RELATED TO CUSTOMER ACTIVITY

3rd Revision Sheet No. 23 Replacing 2"d Revision Sheet N o . 3



Schedule No.: CHARGES

PSC File Mark Only

7. After Hours Trip Fee: $60.00 CR The Cooperative will charge a fee when a customer requests an OECC employee to investigate a service problem, during other than normal working hours, if the OECC facilities are not the cause of the service problem.

8. Meter Readinn Charae: $25.00 CR The Cooperative will charge a fee when an OECC employee is sent to a customer's premises for the purpose of reading a meter after two consecutive estimated readings due to an inaccessible meter.

9. Meter Test Trip Fee: $25.00 A fee will be charged when a special test is requested by the customer and the meter is found to be in error by less than:

Watt-hour Meter 2% average error Demand Register Pulse Recorder Time-of-Use Meter 15 minutes

4% of full scale value 2% of kWh registration; 2 minutes per day

10. Meter Reseal Fee: $25.00 CR A charge will be assessed the customer when a seal at the service entrance is found to be disturbed, and a new seal must be installed. The meter will be changed for testing unless the secondary seal is determined to be undisturbed.

11. Deposits: In accordance with Rule 4.01 of the PSC's General Service Rules, under certain conditions the Cooperative may require a deposit from an applicant for service.


First Revision Replacing Original


Sheet No. 23.1 Sheet No. 23.1



Schedule No.: CHARGES

Title: CHARGES RELATED TO CUSTOMER ACTIVITY PSC File Mark Only

12.

13.

14.

15.

16.

17.

18.

19.

Deposit: In accordance with Rule 4.02 of the PSC’s General Service Rules, under certain conditions the Cooperative may require a new or increased deposit from a customer.

Customer Account Record Change: No Charge

Energv Consumption Statement Charge: No Charge

Meter Reading Report Charqe: No Charge

Delaved Pavment Agreement Finance Charae: No Interest Charge

Late Pavment Charge: Bills are due within fourteen 14) days of the mailing date. If not paid by the due date, a late charge of $4.93 per bill will be required to cover increased costs due to the late payment.

Levelized Billinq Plan Withdrawal Fee: No Charge

Return Trip Fee - New Construction: $50.00 NR AT A return trip fee of $50 shall be required for each trip necessary to complete construction as a result of any of the following:

1) Failure by the member to provide meter loop at the site, constructed in accordance with required specifications and on the agreed upon schedule date.

2) Failure by the member to provide trenching, backhoe, and equipment operator in accordance with required specifications on the agreed upon schedule date. Any scheduling conflicts that are not a direct result of member negligence such as inclement weather or rescheduling as a result of cooperative issues will not result in a trip charge.

3) Any requests by the member to change a previously designed location or the electrical parameters of the members service extension. This charge will only be assessed provided that the staking technician had already physically met the member at the site and discussed these details. In the event that a design is requested to be changed without having ever met the member in the field (which sometimes occurs due to difficulties in members being available to meet a staking technician during normal business hours), the trip charge will not be assessed unless a third trip is ultimately required.


II. p u -b.., J, N

A R O l r z t . . * ! .

Q M M . I,.

e??-*. " - - ARKANSAS PUBLIC SERVICE COMMlSSlOY

0 57 AH '03 Sheet No 24 Sheet No 24 Replacing 1" Revision

Title: SINGLE-PHASE LINE EXTENSION (up to 50 kVA) I PSC File Mark Only


CT

?- e i( .m. E


Schedule No.: EXT-PB #34

POLICY BULLETIN #34

SUBJECT: Single-phase Line Extensions

OBJECTIVES: C

1. To provide a uniform policy of single-phase service extensions on an equitable basis for the applicants and the customers of the Cooperative that are not part of a subdivision, and require 50 kVA or less of transformer capacity.

c 2. To aid the Cooperative in keeping cost of service to applicants within a reasonable investment

DESIGN AND CONSTRUCTION STANDARDS:

I. The Cooperative will be guided by the provisions of the National Electrical Code, the National Electrical Safety Code, and standards recommended by State and Federal regulations, including the Rural Utilities Service, and other such codes imposed for the area by local governmental entities. For each extension, the Cooperative will be guided by the standards and regulations in effect at the time construction begins.

2. Distance will be measured by the Cooperative based on the most economically feasible route from the nearest point of connection from an existing line to the applicant's point of delivery, consistent with sound engineering design for the Cooperative's system. To minimize interference with land uses, as far as practical, electric distribution lines and service lines will be located adjacent to public roads, along fence lines, section lines, lot lines, private drives, or in access ways designated in platted areas for utility use.

3. The Cooperative will not ordinarily provide underground secondary service from a secondary pedestal, pad-mounted transformer, or pole. These services will normally be provided by the customer at hidher own expense. An exception would be a situation where increased distance and/or load require larger than normal secondary, but the economic feasibility of providing a primary service extension is unjustifiable. The feasibility of such extensions will be decided by the cooperative on a case-by-case basis, using sound engineering and accounting principles. Adequate trenching, conduit (installed), and backfill in these situations remain the responsibility of the applicant.


ARKANSAS PUBLIC SERVICE COMMISSN Sheet No. 25

Revision, Sheet No. 25




Title: SINGLE-PHASE LINE EXTENSION (up to 50 kVA) PSC File Mark Only CT

DEFINITIONS:

1. Contribution in Aid of Construction: A non-refundable amount paid by the applicant before construction begins that is based on the applicant's share of the cost of providing the extension.

2. Permanent Service: Any load that will remain connected for a length of time sufficient to recover the investment required to extend service to the load. A permanent installation will retain year-round electric service and residency. To qualify as a permanent installation, a building or mobile home used as a dwelling must have a permanent water supply and an approved sewage disposal system, or other such proof of permanent residency. The applicant shall, upon request, provide proof of at least a leasehold interest in the site where the electric service extension is to be provided.

3. Temporary and Low Usage Service: Those installations which are not expected to retain and use electric service on a year-round basis or will not remain connected for a length of time sufficient to recover the investment required to extend the service. These installations typically may include, but not be limited to, the following: A. Modular and mobile homes not qualifying as a permanent installation as defined in

Permanent Service below. B. Service to seasonal loads not expected to retain year-round service such as tents and

water-pump installations where the pumping requirements are of a temporary nature. C. Temporary service for construction loads where electric facilities are to be removed upon

completion of construction. D. Temporary service for one-time or transient events such as carnivals, fairs, firework

stands, and road shows. E. Service to loads that will not provide enough revenue to recover the required investment.

Services that fall within this category typically may include, but are not limited to: shops, barns, boat docks, cabins, hunting and fishing camps, fuel pumps, fence chargers, single- family well pumps, etc. This includes, but is not limited to, any service projected to have an annual usage of 2000 kWh or less.

4. Direct Cost: Any expense associated with building distribution lines that would include but not be limited to:


ARKANSAS PUBLIC SERVICE COMM!P?fCN APPROVED

JUL 2 2003 1 03 0 8 9 T F

ARKANSAS PUBLIC SERVICE COMMtSSlON Revision Sheet No. 251

Replacing Zd Revision Sheet No. 25-1


I 1 ' . . m i r SI :.v.~.UrVl .: q YI~SUH

' I' cwn. ..

Kind of Senrice: Electric Class of Service: All Classes

Schedule No.: W - P B 834

ZODB AUG 21 A ID I

F ILED Title: SINGLE-PHASE LINE EXENSION (UP to 50 kVA) I PSC Hle Mark Only

I

A. Labor costs to build (and in some cases also retire) distribution facilities or clear right-of-way. B. Materials such as pole line hardware, primary conductor, underground vaultslpadslpedestals,

transformers, metering, service wire, etc., less salvagevalue of any facilities retired in conjunction wilh the extension.

5. Subdivision: Any tract of land that is divided into no less than three lots for the construction of residences, businesses, manu fachiring facililies, etc.

6. DisfribufionSystem: Electn'cfacilifies conslsting of primary cables, transformers, secondary cables, and necessary accessories and appurtenances for the furnishing of electric power and energy at u€ilization voltage to electric consumers.

PROVISIONS FOR ACCOMPLISHMENT: I .

2.

3.

Temporary and Low Usage Service: An applicant requiring facilities extension, which by its very nature Is atemporarylnon-permanent service, ora law usagesewiceshall make aContribution in Aid of Construction to the Cooperative for estimated installation and removal cost, less salvage value. This value is in addition to regular usage rates.

CR PerrnanentSenrice:The Cooperativeruill contribute up toS3,UOO ofthe dlreclcosttfo extend facilities to asingte permanent service. For multi-family dwelling unlts, the Coopem€ive will contribufe asurn equal to the above figure multiplied by the number of dwelling units. Any additional direct costs in excess of the Cooperalive's contribution wilt be paid by fhecustomerasanon-refundable Contribution in Aid &Construction.

Stipu1ations:The ownership oftheline, indudlng any extensions, remains with the Cooperative.The Cooperative resenresthe rightfo connect others and to determine all consfruction specifications and distances, The Coopem€ive will have the sole responsibility to defermhe the permanency or classification of each service.



SEP 1 5 2008ORDER I 0 8 1 2 2 - T F

1" Revision Replacing Original




Title: SINGLE-PHASE LINE EXTENSION (up to 50 kVA) PSC File Mark Only CT

EXTENSION OF SERVICE CONSIDERATIONS:

1.

2.

3.

4.

5.

6.

7.

8.

A line extension may not be built until sufficient work has been completed at a construction site to assure that a permanent residence or other permanent installation will be built.

The applicant shall secure authorization to extend service from affected property owners to facilitate the acquisition of right-of-way easements for the extension.

The applicant shall provide the Cooperative with an accessible entrance to the site suitable for construction and maintenance equipment.

Applicant must install, or have installed, a standard meter loop suitable for the type of installation required. See OECC's standard meter loop specifications.

An applicant requesting a primary underground extension must provide adequate trenching, conduit (installed), and backfill.

If the Cooperative sizes facilities in excess of the applicant's requirements for service, any cost to be paid by the applicant will be adjusted to reflect only the cost of his service requirements.

If the applicant requests a line extension to a service location where facilities have been previously removed at the request of the applicant, the line extension will require a Contribution in Aid of Construction equal to the total estimated cost of the line extension, less the cost of transformers, meters, and other salvageable materials.

If an individual, group, or organization requests the relocation of existing facilities, the relocation will require a Contribution in Aid of Construction equal to the total estimated cost of the relocation, less the salvageable cost of transformers, meters, and other salvageable materials.



JUL 22003 oIpp6EI 1 03 089 xfi - . , . x

r i I ; , ) ! ARKANSAS PUBLIC SERVICE COMMISSION

Z~ Revision Sheet No. 25.3 Replacing lo' Revision Sheet No. 25.3



Schedule No.: UCT-PB #34

Title: SINGLE-PHASE LINE EXTENSION (up tu 50 kVA)

I 2 A 11: 25

.- d4ED

PSC Ftk Mark Only CT

MULTIPLE APPLlCANTS FOR SERVICE FROM THE SAME EXTENSION: Any Contribution in Aid of Construction required under this policy will be paid by the extension on the basis of a proportionate share. Proportionate share will be Cooperative on a cost-per-foot basis.

RESPONSIBILITY: It shall be the responsibility of the PresidentCEO to see that this policy is PresidentCEO may under unusual or extenuating conditions partially or fully waive Aid of Construction in cases where the extension will benefit the Cooperative.

e e

he in

Date Adopted: 5- a 0 0 (# Attested:

T THIS SPACE FOR PSC USE ONLY

ARKANSAS PUBLIC SERVICE COMMISSION . . APPROVED

N O V 2 9 2 0 0 4 ORDER 1 0 4 1 5 6 T F

Oriainal Replacing

Sheet No. 26 Sheet No.

k p ~ & 10 46 @! '01


Kind of Service: Electric Class of Service: Residential

Schedule No.: NST

Title: NOTICE OF SUSPENSION TO TENANTS PSC File Mark Only

OECC has developed procedures for registering accounts of Landlord / Tenant arrangements where electric service is included with the lease or rent payments. Registration forms are available in each OECC office and are mailed to known parties for identification and explanation of responsibilities of all parties as stated in the Arkansas PSC General Service Rules. In addition, OECC attempts to identify Landlord / Tenant accounts during the application process.


ARKANSAS PLijBL\C SERVICE COMMISSION APPROVED

* , ,~ :: 2Cr I I .

ARKANSAS PUBLIC SERVICE COMMISSIOY';~ , ,: .. 'fb ,ngv I _ - OWM. I

3"' Revision Replacing 2"d Revision

Sheet No. 27 Sheet No. -

Ozarks E I ecfric Cooperative Corporation Name of Company


Schedule No.: LEVEL

F L E D

I rile: LtVtLlZED BlLLlNG PLAN I 1 PSC Flle Mark Only

AVAILIBILITY:

The Levetized Billing Plan I (Plan I) is being offered to OECC Arkansas applicants and customers to assist in levelizing or budgeting payments for electric service on a monthly basis.

TERMS AND CONDITIONS:

1.

2.

3.

4.

5.

6.

7.

This plan is available upon request to all Arkansas residential GS-1 applicants. DT

The rates charged under the Plan will be the approved rates on file with and regulated by the Arkansas PSC.

The average monthly payment under the Plan will be determined by dividing the annual billing estimate by 12.

The annual billing estimate will be adjusted on each anniversary date based on the past 12 months.

At each anniversary date, the customer may request a refund by check of any accumulated credit for the past 12 months. The customer shall also have the option of paying any accumulated amount due with the billing for the anniversary month. If the customer dies not choose these refund or payment options for the 12 months' accumulated difference at the anniversary date, the difference will be applied to future Levelized billing by inclusion in the annual billing estimate for the next 12 months.

The monthly bills will reflect the current billing, the average payment for the month and any over or under payment (accumulated balance), The average payment will be due 15 days after the mailing date shown on the bill.

OECC will add a late payment charge pursuant to the billing adjustment schedule to any payments made after the due date. OECC reselves the right to terminate this agreement and return to regular billing procedures immediately upon suspension of service. Upon suspension, all indebtedness to OECC will become due and payable in full; however, i f qualified, the customer may enter into a delayed payment agreement for the indebtedness.



APR 3 0 2008ORDER 1 0 8 0 7 1 - T F

Sheet No. 27.1 Sheet No. -

Kind of Service: Electric Class of Service: AI1 Classes

Schedule No.: LEVEL

Title: LEVELlZED BILLING PIAN I


PSC Rle Mark Only

8. When an electric service account is closed, all debit balances become immediately due and payable to OECC. Credit balances wilt be applied to the final bill with the remaining credit refunded to the customer.

9. This agreement automatically terminates upon a finding of misrepresentation, unauthorized use, or tampering.

10. This plan will remain in effect for current members already on the plan and who choose to stay.



APR 3 0 2OOti ORDER I

. s - - s:.: ,!* 4 R K F . : , '. , .O:, . 9

'CL , A d V o!m. ARKANSAS PUBLIC SERVICE COMMISSION

I Revision Sheet No. 27.2 Replacing Oriqinat Sheet No. -

Schedule No.: LEVEL

TitIe: LEVELIZED BILLING PLAN I1


PSC FIle Mark Only

Kind of Service: EIectric Class of Service: All Classes

AVAllABl LtTY:

The Levelized Billing Plan II (Plan 11) is being offered to OECC Arkansas applicants and customers to assist in leveking or budgeting payments for electric service on a monthly basis.

TERMS AND CONDITIONS:

1. This plan is available upon request to all Arkansas residential GS-1 applicants. DT

2. The rates charged under the Plan will be the approved rates on fiIe with and regulated by the Arkansas PSC.

3. The average monthly payment under the Plan will be determined by dividing the annual billing estimate by 12.

4. The billing will be adjusted monthly based on fhe past I 1 months plus the current month amount, plus or minus the balance after the last month payment, divided by 12. Thus a rolling 12 month average.

5. The monthly bills will refIect the current billing, the average payment for the month and any over or under payment (accumulated balance). The average payment will be due 15 days after the mailing date shown on the bill.

6. OECC will add a late payment charge pursuant €0 the billing adjustment schedule to any payments made after the due date. OECC reserves the right to terminate this agreement and return to regular billing procedures immediatdy upon suspension of service. Upon suspension, all indebtedness to OECC will become due and payable in full; however, if qualified, the customer may enter into a delayed payment agreement for the indebtedness.

7. When an electric service account is closed, all debit balances become immediately due and payable to OECC. Credit balances will be applied to the final bill with the remaining credit refunded to the customer.

8. This agreement automatically terminates upon a finding of misrepresentation, unauthorized use, or tampering.



APR 3 0 2008 ORDER 1 0 8 0 7 1 - T F


Original Sheet No. 27.3 Replacing ___________ Sheet No. _____ Ozarks Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: All Classes Schedule No.: PREPAY Title: PRE-PAY ELECTRIC SERVICE PROGRAM

PSC File Mark Only


AVAILIBILITY: Available to all Consumers who receive single-phase service under General Service Single-Phase < 50KVA (Rate GS-1). The Pre-Pay Electric Service Program will be offered on a strictly voluntary basis upon election by any eligible consumer desiring to participate in the program. APPLICATION: Any eligible new or existing Consumer may request participation in the pre-pay program. A new Consumer requesting the pre-pay program will not be required to pay a security deposit. Any accrued security deposit on an existing consumer’s account at the time of entry to the pre-pay program will be applied to the Consumer’s account balance, and any remainder will be refunded or used to purchase energy, at the Consumer’s preference. Any balance remaining after application of any accrued security deposit will be paid with 50% of Consumer’s future purchase power payments until the remaining balance is paid in full. A credit of $20.00 will be required to begin pre-pay service. A reconnection fee will not be assessed to Consumers participating in Pre-Pay Electric Service Program when service is stopped due to a lack of prepayment and then reinstated after purchase is made. Consumers taking standard service who have been disconnected for non-payment and elect to reconnect under the Pre-Pay Electric Service Program will be assessed a reconnection fee.

NR

APSC FILED Time: 11/21/2011 11:33:53 AM: Recvd 11/21/2011 11:28:36 AM: Docket 11-164-tf-Doc. 1

krhude

11-164-TF


2nd Revision Sheet No. 27.4 Replacing 1st Revision_____ Sheet No. 27.4



Schedule No.: PREPAY

Title: PRE-PAY ELECTRIC SERVICE PROGRAM PSC File Mark Only


PROVISIONS:

Power may be purchased during normal business hours at any Cooperative office in any increments equal to or exceeding a $20.00 minimum purchase amount. Consumers may purchase power in any increment by internet, interactive voice response, payment kiosk, or mobile device at any time.

Standard provisions of the Cold Weather rule and Elderly and Handicapped rules are applicable under this service.

Medical certification will be honored per the provisions of Arkansas Public Service Commission’s General Service Rules – Rule 6.17

Consumers will not be disconnected on weekends, Cooperative holidays, or after normal business hours. Consumer must purchase power by 10:00 a.m. on the following business day to avoid disconnection.

Consumers will not receive a paper bill.

The Cooperative will monitor usage of participating pre-pay consumers and send purchase requirement notifications via electronic mail when their balance reaches the credit balance of $12.00, unless modified by the Consumer. Participating consumers can also monitor their balance with the MyOzarks phone application or by calling the Cooperative office.

OTHER:

Except as modified herein, all other provisions of General Service Single-Phase shall apply.

APSC FILED Time: 6/7/2016 10:39:06 AM: Recvd 6/7/2016 10:37:41 AM: Docket 16-029-TF-Doc. 4

Ark

. Pub

lic S

erv.

Com

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--A

PP

RO

VE

D--

-06/

08/2

016

Doc

ket:

16-0

29-T

F O

rder

No.

- 2

Replacing Sheet No.



Schedule No.: POLES

Title: POLE IDENTIFICATION

IDENTIFICATION OF POLES: OECC will identify all its poles by either having a branded label “OECC” burned into the pole at the treatment facility or by attaching a metallic identification label approximately three and one-half inches long by three-fourths inch wide with the initials “OECC” stamped in the metal and attached with two nails. The metallic or the branded label will be in a prominent place located between four and six feet above ground level on the pole.

Each pole used by OECC will have a manufacturer’s brand on the pole, showing the month, year of treatment, the class, and height of the pole. This brand is located on the pole approximately five feet above ground level and branded on the pole by the pole supplier.

This statement is to advise the Arkansas PSC of the methods used in marking poles as required in Rule 5.02 of the Special Rules - Electric.


Oriuinal Sheet No. 29 Replacing Sheet No.



Schedule No.: TESTS

Title: METER TEST PROGRAMS PSC File Mark Only

NEW METERS: OECC tests one hundred percent (100%) of the new meters purchased to determine that their accuracy of registration is in accordance with good practice and within the tolerances set by the rules and regulations of the Arkansas PSC in Rule 7.05.B of the Special Rules - Electric.

IN-SERVICE METERS:

Also in compliance with Rule 7.08.B of the Special Rules - Electric, the following periodic testing of watt- hour metering is done by the Cooperative.

1. All single-phase watt-hour meters are to be tested not to exceed 16 years.

2. Self-contained polyphase meters are to be tested not to exceed 16 years.

3. Block interval demand meters are to be tested not to exceed 12 years.

4. In-service pulse recorders are compared monthly to the meter registration. If the registration agrees within the I O/O tolerance outlined in Rule ANSI C 12.1 - 1982, Section 8.2.3.1, the pulse recorded is scheduled for testing not to exceed a 16-year cycle.

a. If the recorder-meter registration checks do not agree within the 1 % tolerance, the demand metering equipment is tested.


ARKANS.4S PUBUC SERVtCE COMMISSION APPROVED

Is[ Revision SheetNo. 30 Replacing Original SheetNo. 30

I Orarks Electric Cooperative Corporation Name of Company

p , , 'L :,dV.CUflL ,. :: W S r n :OK?!.


Schedule No.: NOM-VOLT

Title: STANDARD NOMINAL VOLTAGE PSC File Mark OnIv

STANDARD NOMINAL VOLTAGE: CT The following secondary voltages are available from the Cooperative to its customers depending on the customer's size, applicatlon, and location on !he Cooperative's distribution system:

1 Single-Phase 1201240 volts wilh a mpirnurn transformar size of I 67 kVA in areas where threeghase servlce 1s available. In areas where it is not feasible to extend fhret-phase service, iargercapaclties may be considend on a case-&-case basis,

2 Three-phase 1201240 volt deltaservice,wllh maximum fransrormerdzesof 2-75 and 1-100 kVA(250 kVA total).

3. Three-phase 2081120 volt wye service wih a maximum tmnsformer capacity of 1,000 kVA, Larger fransformersin thisvoltage are mrelyused in #e industry and are nota normal stockitem. If the member requires a larger transformer, the member may be required io contribute the cost of purchase of a spare.

4. Three-phase4801277 volt wye service with a maximum single Imsformer capacity of 2,500 kVA and total senice capacity of 5,000 kVA. If the member requires a larger transformer, Ihe member may be required to contribute the cast of purchase of a spare.

Primary service at 12,470/7,200 volts or 24,940114,400 volts {depending on substation serving) will normally be available at any capacity reasonably available along existing distribution tines. If the projected loading is less than 2,500 kVA, the member may be required to pay metering costs over and above that required for secondary metering.

Three-phase overhead 120i208 volt and 2n/480 volt services will be limited lo a total of 1,000 kVA transformer capacity.

At fhe discretion of the cooperative, motor sizes on single-phase lines may be limited to 10 HP nominal. This includes 'roto-phase" converters. On three-phase lines, any mofor over 50 HP may be required fa have "soft staff capability.

It shall be the responsibility of any member with a multi-phase service fo provide self-protection against loss of phase.

The maximum total harmonic distortion allowable will be in compliance with lEEE 51 9 sfandards. Industrial consumers should exercise due diligence when installing variable frequency drives SO they will not adversely affect the quality of service of other consumers,



Oriainal Sheet No. 31 Replacing Sheet No.


IPR 2b: IO 46 AM '01


Schedule No.: Ext. Ab.P.P.

Title: EXTENDED ABSENCE PAYMENT PLAN PSC File Mark Onlv

EXTENDED ABSENCE PAYMENT PLAN (General Service Rule 5.1 1)

1. The following options are available to residential customers to avoid suspension of service during extended absences.

A. Bills coming due during the customer's absence may be paid in advance. The amount of the advance payment will be based on the customer's average monthly bill for the most recent 12 months. If less than 12 months' usage history is available, the advance payment will be based on the number of months of usage history available. If the advance payment is rnore than the actual bill for service, the overpayment will be credited to the customer's account. If the advance payment is less than the actual bill for service, the balance due will be carried forward each month until the customer returns. Delayed payment agreements will be available for any underpayments.

B. The customer will be given the opportunity to enroll in OECC's Bank Draft Plan whereby the monthly service bill will be paid automatically through the customer's checking or savings account.

C. The customer can arrange to have bills coming due during the period of the absence mailed to an alternate address or third party during the absence.

2. The customer must notify OECC in order to take advantage of any of these extended payment plans.



ORDlft 112 99-250-U

1'' Revision Replacing Original


Kind of Service: Electric Class of Service: As Applicable

Schedule No.: EA. D.D.P.

Title: EXTENDED DUE DATE PLAN PSC File Mark Only

EXTENDED DUE DATE PLAN (General Service Rule 5.08)

The Extended Due Date Plan is available to qualifying residential customers and is intended to enable OECC to change a customer's bill payment due date, at the customer's request, to coincide with or follow the customer's receipt of his or her income as listed below. Customers who qualify under this plan and pay by the new due date will not be considered late on their payment.

AVAILABILITY:

Customers whose income is not normally received by the regular bill due date are eligible for an extended due date. Customers may request an extension of their due date based on any of the following:

1. Persons whose income is not received by the regular bill due date and who request a new due date:

2. Persons who receive multiple bills with multiple due dates, and request all bills due on the same date.

APPLICATION:

1. Customers shall become plan participants upon either written or verbal application to OECC. Participation will continue each month thereafter, regardless of account location, as long as the customer's account remains active and customer has not violated any of the provisions of reasons for removal from the plan. Verification of income being received by the customer may be required.

2. After acceptance of a customer by OECC as a participant in the Extended Due Date Plan, the customer shall supply OECC the requested new due date, which will become a permanent part of the customer's record.

3. During the billing procedure each month, the new due date will replace the customer's normal due date.

4. OECC will impose the presently filed late payment charge on plan participants who do not pay by the extended due date.


R T

R T

C T

CT/ RT

A T

A T

CT

CT

M T

ARKANSAS PUBLIC SERVICE COMA

1’’ Revision’ Sheet No. 33 Replacing Oriqinal Sheet No. 33


Kind of Service: Electric Class of Service: As Applicable

Schedule No.: Ext. D.D.P.

Title: EXTENDED DUE DATE PLAN PSC File Mark Onlv I

5. If payments are not received by the close of business on the extended due date, OECC will follow the established notification process established by the Arkansas PSC which could ultimately result in termination of service.

REMOVAL FROM THE PLAN:

A customer who violates any of the following provisions will de removed from the plan:

1. The customer pays after the extended due date two times in a row, or any three times in the last 12 months.

2. The customer is disconnected for non payment.

OECC will notify the customer in writing when the customer has been removed from the plan under this provision.

REINSTATEMENT IN THE PLAN:

1. Customers may be reinstated upon request after twelve months with no violations of provisions for removal.


M T

R T

A T

R T 1 CT

A T

M T

A T

Replacinq

Title: RESERVED FOR FUTURE USE

Sheet No. Sheet No.

PSC File Mark Only

34 i i p R 2b



Schedule No.:


ARKANSAS PUBLIC SERViCE COMMlSSlON APPROVED

nl, 5 . ~ L *I.

- 2 c

-A l i NRF. *

E , 1 nrJIbl. ARKANSAS PUBLIC SERVICE COMMISSION ...+F,

lST Revision Replacing Oriqinal




Schedule No.: LEVEL

Title: VOLTAGE VERIFICATION PLAN PSC File Mark Only - . _

ELECTRIC VOLTAGE VERIFICATION PLAN:

The Cooperative has installed at each of its distribution substations, voltmeters that verify voltage levels by recording continual voltage readings.

CT

__ THIS S P E m K C U S E ONLY

ARKANSAS P U5L IC S ERVl C E C 0 M M I SS 10 N APPROVED

0 7 - 0 6 9 T F

I st Revision Replacing Oriainal

~~

SheetNo. 36 Sheet No. 36




Title: THREE-PHASE AND OVER 50 KVA SINGLE-PHASE LINE EXTENSIONS

PSC File Mark Only

POLICY BULLETIN #30

SUBJECT: Three-phase and Over 50 kVA Single-phase Line Extensions

OBJECTIVES:

CT

AT 1. To provide a uniform policy of extension of three-phase and Over 50 kVA single-phase service on

an equitable basis for applicants and customers of the Cooperative that are not part of a subdivision. Apartment complexes on a single tract of land will be considered under this policy.

2. To aid the Cooperative in keeping cost of service to applicants within a reasonable investment range.

DESIGN AND CONSTRUCTION STANDARDS: AT 1.

2.

3.

The Cooperative will be guided by the provisions of the National Electrical Code, the National Electrical Safety Code, the standards recommended by State and Federal regulations, including the Rural Utilities Service, and other such codes imposed for the area by local governmental entities. For each extension, the Cooperative will be guided by the standards and regulations in effect at the time that construction begins.

Distance will be measured by the Cooperative based on the most economically feasible route from he nearest point of connection from an existing line to the applicant's point of delivery, consistent with sound engineering design for the Cooperative's system. To minimize interference with land uses, as far as practical, electric distribution lines and service lines will be located adjacent to public roads, along fence lines, section lines, lot lines, private drives, or in access ways designated in platted areas for utility use.

The Cooperative will not ordinarily provide underground secondary service from a secondary pedestal, pad-mounted transformer, or pole. These services will normally be provided by the customer at hidher own expense. An exception would be a situation where increased distance and/or load require larger than normal secondary, but the economic feasibility of providing a primary service extension is unjustifiable. The feasibility of such extensions will be decided by the cooperative on a


ARKANSAS PURL!C SERL'iCE COMMISSION APPROVED

APR302001 ORDER 112 9 9 - 2 5 Q m U

1 st Revision Replacing Original






Apa 2b 19 46 AM '01

PSC File Mark Only

CT

case-by-case basis, using sound engineering and accounting principles. Adequate trenching, conduit (installed), and backfill in these situations remain the responsibility of the applicant.

DEFINITIONS: AT 1.

2.

3.

4.

5.

6.

Direct Cost: The cost of distribution or transmission facilities necessary to provide electric service to the customer, determined by estimating all necessary expenditures, including, but not limited to, distribution facilities, transformers, labor, right-of-way, contract costs, metering and rearrangement or conversion of existing electrical facilities. This cost includes only the cost of the above-mentioned facilities that are necessary to provide service to the particular customer requesting service and does not include the costs of facilities necessary to meet future anticipated load growth, or to improve the service reliability in the general area for the benefit of existing and future customers.

System Cost: Cooperative's average allocated investment costs and rate base items associated with transmission backbone facilities, distribution substation facilities, and distribution backbone facilities as determined from the Cooperative's most recent cost of service.

Annual Revenue: Annual revenue from the customer computed using estimated billing units less the estimated annual cost of purchased power.

Return Factor: The fixed charge rate, including O&M, Depreciation, Taxes and a return on investment, necessary to convert an annual revenue stream to the total revenue associated with the life of the project.

Contribution in Aid of Construction: A non-refundable amount paid by the applicant before construction begins that is based on the applicant's share of the cost of providing the extension.

Permanent Service: Any load that will remain connected for a length of time sufficient to recover the investment required to extend service to the load. A permanent installation will retain year-round electric service and residency. To qualify as a permanent installation, a building must have a permanent water supply and a sewage disposal system, or other such proof of permanency. The


ARKANSAS PUBLIC SERVJCE COMMISSION APPROVED

APR302001 ORMR 112 99-25O-U

Replacing Sheet No.




Title: THREE-PHASE AND OVER 50 KVA SINGLE-PHASE ~ LINE EXTENSIONS

PSC File Mark Only

CT

applicant must also have at least a leasehold interest in the site where the electric service extension is to be provided.

7 . Temporary and Low Usage Service: Those installations which are not expected to retain and use electric service on a year-round basis or will to remain connected for a length of time sufficient to recover the investment required to extend the service. These installations typically may include, but not be limited to, the following: A. Service to seasonal loads not expected to retain year-round service such as irrigation-pump

installations where the pumping requirements are of a temporary nature. B. Temporary service for construction loads where electric facilities are to be removed upon

completion of construction. C. Temporary service for one-time or transient events such as carnivals, fairs, and road shows. D. Any other service to loads that will not provide enough revenue to recover the required

investment.

8. Subdivision: Any tract of land that is divided into three lots or more for the construction of residences, businesses, manufacturing facilities, etc.

9. Distribution System: Electric facilities consisting of primary cables, transformers, secondary cables, and necessary accessories or appurtenances for the furnishing of electric power and energy at utilization voltage to electric consumers.

PROVISIONS FOR ACCOMPLISHMENT: AT 1. Temporary and Low Usage Service: An applicant requiring facilities extension which by its very

nature is a temporary / non-permanent service, or a low load factor service, or a low usage load service shall make a Contribution in Aid of Construction for estimated installation and removal cost, less salvage value. This value is in addition to regular usage rates.

2. Permanent Three-phase Service Requiring 50 kVA or Less Transformer Capacity: The Cooperative will contribute up to $5,700 of the direct cost to extend facilities to a permanent three-









PSC File Mark Only

CT

phase service requiring 50 kVA or less transformer capacity. Any additional direct costs in excess of the Cooperative’s contribution will be paid by the customer as a Contribution in Aid of Construction.

3. Permanent Services Requiring Over 50 kVA Transformer Capacity: The Cooperative will determine if a Contribution in Aid of Construction for provision of electric service is required. The amount of the customer’s contribution, if any, shall be determined by the following formula. If the amount calculated below is zero or negative, no Contribution in Aid of Construction is required for provision of electric service.

Cooperative’s Allowable Investment = Annual Revenue I Return Factor Total Project Cost = Direct Cost + System Cost Customer’s Contribution = Total Project Cost - Cooperative’s Allowable Investment

EXTENSION OF SERVICE CONSIDERATIONS: AT 1.

2.

3.

4.

5.

6.

A line extension may not be built until sufficient work has been completed at a construction site to assure that a permanent residence or other permanent installation will be built.

The applicant shall secure authorization to extend service from affected property owners to facilitate the acquisition of right-of-way easements for the extension.


Applicant must install, or have installed, a standard meter loop suitable for the type of installation required. See OECC’s standard meter loop specifications.

An applicant requesting a primary underground extension must provide adequate trenching, conduit (installed), and backfill.

If a Contribution in Aid of Construction will be required in order to extend service to the applicant, the applicant shall pay the full amount of this contribution before construction begins.


ARKANSAS PU8LIC SERVICE COMMISSION APPROVED

Orisinal Sheet No. 37.3 Replacina Sheet No.



Schedule No.: EXT-PI3 #30


7.

8.

9.

10.

PSC File Mark Only

CT

If the Cooperative sizes facilities in excess of the applicant's requirements for service, any cost to be paid by the applicant will be adjusted to reflect only the cost of his service requirements.

If the applicant requests a line extension to a service location where facilities have been previously removed at the request of the applicant, the line extension will require a Contribution in Aid of Construction equal to the total estimated cost of the line extension, less the cost of transformers, meters, and other salvageable materials.

If an individual, group, or organization requests the relocation of existing facilities, the relocation will require a Contribution in Aid of Construction equal to the total estimated cost of the relocation, less the salvageable cost of transformers, meters, and other salvageable materials.

If gang type meter sockets are desired in an apartment complex, the cost of said sockets will be the responsibility of the Developer.

MULTIPLE APPLICANTS FOR SERVICE FROM THE SAME EXTENSION: AT Contributions in Aid of Construction required for a multi-applicant extension under this policy will be paid by the participants in the extension on the basis of proportionate share. Proportionate shares will be calculated by the Cooperative on a cost-per-foot basis.

RESPONSIBILITY: AT It shall be the responsibility of the PresidentCEO to see that this policy is carried out. The PresidenKEO may under unusual or extenuating conditions partially or fully waive the Contribution in Aid of Construction in cases where the extension will benefit the CooDerative.



1 st Revision Sheet No. 38 Replacing Oriainal Sheet No. 38




Title: SUBDIVISION LINE EXTENSION

POLICY BULLETIN #45

SUBJECT: Extensions to and within Subdivisions

OBJECTIVES:

PSC File Mark Only CT

AT 1. To provide a uniform policy of service extensions on an equitable basis for the developers of

subdivisions.

2. To aid the Cooperative in keeping cost of service to subdivisions within a reasonable investment range.

DESIGN AND CONSTRUCTION STANDARDS: AT 1. The Cooperative will be guided by the provisions of the National Electrical Code, the National

Electrical Safety Code, the standards recommended by State and Federal regulations, including the Rural Utilities Service, and other such codes imposed for the area by local governmental entities. For each extension, the Cooperative will be guided by the standards and regulations in effect at the time that construction begins.

2. Distance will be measured by the Cooperative based on the most economically feasible route from he nearest point of connection from an existing line to the applicant’s point of delivery, consistent with sound engineering design for the Cooperative’s system. To minimize interference with land uses, as far as practical, electric distribution lines and service lines will be located adjacent to public roads, along fence lines, section lines, lot lines, private drives, or in access ways designated in platted areas for utility use.

DEFINITIONS: AT / RT 1. Contribution in Aid of Construction: A non-refundable amount paid by the applicant before

construction begins that is based on the applicant’s share of the cost of providing the extension.

2. Direct Cost: Any expense associated with building distribution lines that would include by not be limited to:


ARKANSAS PUB116 SERVICE COMMfSSlOM APPECVEU

ARKANSAS PUBLIC SERVICE CC ~~ -

1" Revision SheetNo. 39 Replacing Oriainal Sheet No. 39



Schedule No.: EXT-PB W5


4.

5.

6.

PSC File Mark Only I CT

A. Labor costs to build (and in some cases also retire) distribution facilities or clear right-of-way. B. Materials such as pole line hardware, primary conductor, vaults, pads, pedestals, conduit,

transformers, metering, service wire, etc., less salvage value of any facilities retired in conjunction with the extension.

Subdivision: Any tract of land that is divided into three lots or more for the construction of residences, businesses, manufacturing facilities, etc.

Point of Delivery: The point at which the applicant takes responsibility for his or her service. For residential underground subdivisions, this point is the lot line.

Distribution System: Electric facilities consisting of primary cables, transformers, secondary cables, and necessary accessories and appurtenances for the furnishing of electric power and energy at utilization voltage to electric consumers.

CONDITIONS: AT 1.

2.

3.

4.

The Cooperative will only extend service under this policy desired by the developer or applicant for service only if, in the Cooperative's judgment, it is feasible to construct, own, operate, maintain, and replace facilities at the particular location taking into account the size and type of load. Otherwise, any new service will be considered under Policy Bulletin 30 or 34, whichever is appropriate.


All right-of-way clearing and rough-site grading must be completed by the developer and final grade established prior to installation of any electric facilities.

The Cooperative shall have the right to excavate as necessary to locate, repair, or upgrade the facilities at the Cooperative's discretion.


ARKANSAS PUBLIC SERVICE COMMISSJON APPROVED

1 Revision Replacing Oriuinal APR 26 10 46 ’01 SheetNo. 40

Sheet No. 40



Schedule No.: EXT-PI3 #I45

PSC File Mark Only Title: SUBDIVISION LINE EXTENSION I

5.

6.

7 .

8.

9.

10.

The Cooperative shall not be liable for payment or for repair of any damage to the consumer’s lawn, yard, shrubbery, fence, walk, patio, driveway, or other areas resulting from the necessary installation or maintenance of underground service.

Unless determined otherwise by the Cooperative, any subdivision or development to be served under this policy shall consist of a single tract of land so arranged and situated that either an overhead or underground electric distribution system and associated service connections will be the only type of electric service provided by the Cooperative within the subdivision or development.

To the maximum extent practicable, the Cooperative will work out an agreement with the affected telephone and/or cable companies to install electric cables in the same trench with due care being taken to conform to the National Electrical Code and all applicable local codes and specifications. No water, gas, or sewer pipes shall be installed in the same trench with the Cooperative’s electric cables.

The type of construction, character of service, and location of the electric system will be at the option of the Cooperative. The ownership of the line, including any extensions, remains with the Cooperative. The Cooperative reserves the right to connect others and to determine all construction specifications and distances. Should the developer desire changes in either the location, character of service, or type of construction, such installation will be made only upon the developer’s paying the Cooperative the estimated additional cost incurred thereby.

Any adjustments, relocations, and requests for services within a subdivision where distribution facilities have been already established shall follow guidelines established in Policy Bulletins 30 and 34, whichever is appropriate.

Any construction upgrades or conversion required to extend facilities to the tract of land being subdivided will be calculated and added to the total cost of the project. The applicant shall secure authorization to extend service from affected property owners to facilitate the acquisition of right-or- way easements for the extension.


ARKANSAS P UBUC SERVICE COMMlSSlON APPROVED

APR 30 2001

~ ~~

1 ’‘ Revision SheetNo. 41 Replacing Oriuinal Sheet No. 41



Schedule No.: EXT-PI3 #45

Title: SUBDIVISION LINE EXTENSION PSC File Mark Only CT

11. The developer or builder shall provide the secondary conductor and conduit from the Cooperative’s facility located on lot line to each meter. Metering may be on a pedestal at the lot line or on the building exterior and in accordance with prevailing electrical codes. A properly sized and approved service disconnect or breaker shall be installed on the load side of the meter. If the meter is located on the building, the disconnect may be on the building interior. If the main disconnect is located on the building interior, the conductor between the disconnect and the meter socket shall be in conduit and the disconnect located no greater than three feet from the meter. All connections to the load side of the meter shall be made and approved by the local inspection authority prior to the installation of the meter. Connections between member’s facilities and the Cooperative shall be made by the Cooperative.

DEVELOPER’S / APPLICANT’S RESPONSIBILITY: CT / MT I.

2.

3.

4.

5.

Developer should submit an application to the Cooperative as early in the planning stage as possible and before plat easements and bill of assurance are filed for record.

Developer will furnish to the Cooperative, before being recorded, a plat showing the location and nature of the tract of land to be developed.

Developer will, at no cost to the Cooperative, provide and record all easements and rights-of-way required within the subdivision by the Cooperative and will execute, or cause to be executed, all other contracts and agreements required by the Cooperative.

Developer will notify all purchasers of lots, residences or buildings of all provisions of the easements and rights-of-way or other agreements granted to, or executed with, the Cooperative by incorporating same in the bill of assurance, plat of easements and other documents which shall be filed for record prior to the sale of any lot and/or residence or building.

It will be the responsibility of the Developer to maintain the trench cover and make repair and/or replacement of damage to any shrubs, trees, sod or paved areas. Developed will hold the Cooperative or its subcontractors harmless against any claims for damage.


ARKANSAS PUBLIC SERVICE COMMtSSlON APPROVED

’. ‘Lf iMIA. ARKANSAS PUBLIC SERVICE C O M M E ~ ~ I ~ *

1 st Revision Sheet No. 42 Replacing Oriainal Sheet No. 42



Schedule No.: EXT-PB ##45


10 4s A4 ‘01


6. The Developer of a mobile home park shall provide a suitable structure at each mobile home location for the meter installation. See OECC’s meter pedestal specification.

7 . The Developer will provide appropriate conduit under roads or other paved areas, or planned paved areas at the appropriate depth as necessary within the development. A Cooperative representative will coordinate the location and size of these crossings with the Developer.

COOPERATIVE’S RESPONSIBILITY: CT / MT 1. The Cooperative will furnish all material and equipment and will construct, install, own, and maintain

the complete electric system to the point of delivery.

2. If the Cooperative sizes facilities in excess of the subdivision’s requirements for service, any cost to be paid by the Developer will be adjusted to reflect only the facilities necessary to serve the development.

CHARGES: 1. The Cooperative will contribute up to 50% of the direct cost to extend facilities to and within a

subdivision, if feasible. The remainder of the direct cost will be paid by the Developer as a Contribution in Aid of Construction to the Cooperative.

2. The Cooperative will periodically calculate the Cooperative’s appropriate percentage contribution based on the Cooperative’s allowable investment per service, and average fill rates of subdivisions in Cooperative territory.

3. Special conditions that incur additional cost shall be at the Developer’s expense and shall not be reimbursable. These include, but are not limited to, rock trenching, select material bedding, tunneling, shoring, boring, dewatering, etc.

UNDERGROUND STREET LIGHTS: 1. Where the Cooperative’s standard underground street lights are to be installed in a subdivision, the

Developer shall pay the Cooperative the total estimated cost to install said lights. The Cooperative



1 st Revision Sheet No. 43 Replacing Original Sheet No. 43





APR 26 io 47 AI4 ‘01

FELID


will make every effort to place street lighting cable in a common trench with the distribution cable to reduce costs, provided lights are requested in conjunction with distribution facilities.

2. Where Developer desires underground street lighting other than the Cooperative’s standard lights, the Developer shall provide a suitable structure at each desired location for a meter installation to serve these non-standard lights. Any service location other than at a Cooperative-owned pad- mounted transformer or secondary pedestal shall be considered under Policy Bulletin 34. The Cooperative will not be responsible for the maintenance of any lights or equipment beyond this point.

RESPONSIBILITY: AT It shall be the responsibility of the PresidentCEO to see that this policy is carried out. The PresidenUCEO may under unusual or extenuating conditions partially or fully waive the Contribution in Aid of Construction in cases where the extension will benefit the CooDerative.

Attested: Date Adopted: 3-280/




_1st Revision____ Sheet No. 44_ Replacing ____ ____ Original Sheet No. __ _


Kind of Service: Electric Class of Service All

Schedule No.: NET

Title: NET-METERING PSC File Mark Only


TABLE OF CONTENTS Tariff Provisions .............................................................................................................. Page 44 Preliminary Interconnection Site Review Request ............................................................. Page 44.3

Standard Information .................................................................................. Page 44.3 Terms and Conditions ................................................................................. Page 44.4

Standard Interconnection Agreement for Net-Metering Facilities ....................................... Page 44.5 Standard Information .................................................................................. Page 44.5 Interconnection Agreement Terms and Conditions ....................................... Page 44.6

Disclaimer ....................................................................................................................... Page 44.11

1. NET-METERING

1.0 DEFINITIONS

1.0.1 Avoided Cost: As defined in ACA 23-18-603(1) 1.0.2 Net Metering: As defined in ACA 23-18-603(6) 1.0.3 Net Metering Customer: As defined in ACA 23-18-603(7) 1.0.4 Net Metering Facility: As defined in ACA 23-18-603(8) 1.0.5 Electric Utility: As defined in ACA 23-18-603(3) 1.0.6 Net Excess Generation: As defined in ACA 23-18-603(5) 1.0.7 Renewable Energy Credit: As defined in ACA 23-18-603(10) 1.0.8 Quantifiable Benefits: As defined in ACA 23-18-603(9)

1.1 AVAILABILITY

1.1.1 To any residential or any other customer who takes service under standard rate schedules GS-1, GS-3, LP<350 KVA, LP>350 KVA, LP-OFF, is a Net-Metering Customer as defined, and has obtained a signed Standard Interconnection Agreement for Net-Metering Facilities with an Cooperative. The generating capacity of Net-Metering Facilities may not exceed the greater of: 1) twenty-five kilowatts (25 kW) or 2) one hundred percent (100%) of the Net-Metering Customer’s highest monthly usage in the previous twelve (12) months for Residential Use. Net-Metering is intended primarily to offset part or all of the customer’s energy use. The generating capacity of Net-Metering Facilities may not exceed one thousand kilowatts (1,000 kW) for non-residential use unless otherwise approved by the Cooperative. Approval of a Net-Metering Facility greater than 1,000 kW for a non-residential customer will be determined on a case-by-case basis and may be granted if it can be determined that the interconnection of such facility has no adverse impact on the cooperative’s distribution system and the customer’s load requirements are sufficient to consume not less than 90% of the customer’s net-metered generation.

The provisions of the customer’s standard rate schedule are modified as specified herein.

APSC FILED Time: 3/2/2021 9:10:39 AM: Recvd 3/2/2021 9:09:31 AM: Docket 16-027-R-Doc. 588

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_2nd Revised ____ Sheet No. 44.1.._ Replacing ____ __1st Revised__ Sheet No. __ _



Schedule No.: NET



Net-Metering Customers taking service under the provisions of this tariff may not simultaneously take service under the provisions of any other alternative source generation or co-generation tariff except as provided in the Net-Metering Rules.

1.2 MONTHLY BILLING

1.2.1 The Cooperative shall separately meter, bill, and credit each Net-Metering Facility even if one (1) or more Net-Metering Facilities are under common ownership.

1.2.2 On a monthly basis, the Net-Metering Customer shall be billed the charges applicable under the currently effective standard rate schedule and any appropriate rider schedules. Under Net-Metering, only the kilowatt hour (kWh) units of a Net–Metering Customer’s bill are netted.

1.2.3 If the kWhs supplied by the Cooperative exceeds the kWhs generated by the Net-Metering Facility and fed back to the Cooperative during the Billing Period, the Net-Metering Customer shall be billed for the net billable kWhs supplied by the Cooperative in accordance with the rates and charges under the Net-Metering Customer’s standard rate schedule.

1.2.3a For Net-Metering Customers who receive service under a rate that does not include a demand component, the Cooperative shall credit a Net-Metering Customer with the amount of any accumulated Net Excess Generation as measured in kWh or kWh multiplied by the applicable rate in the next billing period and base the billing of the Net-Metering Customer on the net amount of electricity as measured in kWh or kWh multiplied by the applicable retail rate that the Net-Metering Customer has received from or fed back to the Cooperative during the billing period.

1.2.3b For Net_Metering Customers who receive service under a rate that includes a demand component with a generating capacity of 1,000 kW or less, the Cooperative shall credit the Net-Metering Customer with any accumulated Net Excess Generation as measured in kWh in the next applicable billing period and base the bill of the Net-Metering Customer on the net amount of electricity as measured in kWh that the Net-Metering Customer has received from or fed back to the Cooperative during the billing period.

1.2.3c For Net-Metering Customers who receive service under a rate that includes a demand component with a generating capacity over 1,000 kW and up to 20 MW and who receive approval to exceed statutory limits under Ark. Code Ann. § 23-18-604(b)(9), the Cooperative shall credit a Net-Metering Customer with the amount of any accumulated Net Excess Generation as measured in kWh in the next applicable billing period and base the bill of the Net-Metering Customer on the net amount of electricity as measured in kWh that the Net-Metering Customer has received from or fed back to the Cooperative during that period.


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_Original____ Sheet No. 44.1a_ Replacing ____ ___ Sheet No. __ _



Schedule No.: NET



The Cooperative shall also bill the Net Metering Customer a grid charge.

Grid charge rate: $0.00

1.2.4 If the kWhs generated by the Net-Metering Facility and fed back to the Cooperative during the Billing Period exceed the kWhs supplied by the Cooperative to the Net-Metering Customer during the applicable Billing Period, the Cooperative shall credit the Net-Metering Customer with any accumulated Net Excess Generation in the next applicable Billing Period.

1.2.5 Net Excess Generation shall first be credited to the Net-Metering Customer’s meter to which the Net-Metering Facility is physically attached (Generation Meter).

1.2.6 After application of 1.2.5 and upon request of the Net-Metering Customer pursuant to 1.2.8, any remaining Net Excess Generation shall be credited to one or more of the Net-Metering Customer’s meters (Additional Meters) in the rank order provided by the Net-Metering Customer.


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_First Revision____ Sheet No. 44.2.._ Replacing ____ __Original__ Sheet No. __ _



Schedule No.: NET



1.2.7 Net Excess Generation shall be credited as described in 1.2.5 and 1.2.6 during subsequent Billing Periods; the Net Excess Generation Credits remaining in a Net-Metering Customer’s account at the close of a billing cycle shall not expire and shall be carried forward to subsequent billing cycles indefinitely. For Net Excess Generation Credits older than twenty-four (24) months, a Net-Metering Customer may elect to have the Cooperative purchase the Net Excess Generation Credits in the Net-Metering Customer’s account at the Cooperative’s avoided cost for wholesale energy if the sum to be paid to the Net-Metering Customer is at least one hundred dollars ($100). The Cooperative shall purchase at the Cooperative’s avoided costs any Net Excess Generation Credits remaining in a Net-Metering Customer’s account when the Net-Metering Customer: 1) ceases to be a customer of the Cooperative; 2) ceases to operate the Net-Metering Facility; or transfers the Net-Metering Facility to another person.

When purchasing Net Excess Generation Credits from a Net-Metering Customer, the Cooperative shall calculate the payment based on its annual average avoided energy costs in the applicable Regional Transmission Organization for the current year.

1.2.8 Upon request from a Net-Metering Customer the Cooperative shall apply Net Excess Generation to the Net-Metering Customer’s Additional Meters provided that:

(a) The Net-Metering Customer must give at least 30 days’ notice to the Cooperative.

(b) The Additional Meter(s) must be identified at the time of the request. Additional Meter(s) shall be under common ownership within a single Cooperative’s service area; shall be used to measure the Net-Metering Customer’s requirements for electricity; may be in a different class of service

than the Generation Meter; shall be assigned to one, and only one, Generation Meter; shall not be a Generation Meter; and shall not be associated with unmetered service.

However, the common ownership requirement shall not apply if more than two customers that are governmental entities or other entities that are exempt from state and federal income tax defined under 23-18-603(7)© co-locate at a site hosting the Net-Metering Facility.

(c) In the event that more than one of the Net-Metering Customer’s meters is identified, the Net-Metering Customer must designate the rank order for the Additional Meters to which excess kWhs are to be applied. The Net-Metering Customer cannot designate the rank order more than once during the Annual Billing Cycle.

1.2.9 Any Renewable Energy Credit created as the result of electricity supplied by a Net-Metering Customer is the property of the Net-Metering Customer that generated the Renewable Energy Credit.

1.2.10 Grandfathering shall be governed by ACA 23-18-604(b)(10).


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__2nd Revised ____ Sheet No. 44.3_ Replacing ____ ___1st Revised_ Sheet No. _



Schedule No.: NET



PRELIMINARY INTERCONNECTION SITE REVIEW REQUEST

I. STANDARD INFORMATION

Section 1. Customer Information Name: Contact Person: _________________________________________________ Mailing Address: City: State: Zip Code: Facility Location (if different from above): Daytime Phone: Evening Phone: E-Mail Address: _______________________Fax: ______________________ If the requested point of interconnection is the same as an existing electric service, provide the electric service account number:______________________________ Additional Customer Accounts (from electric bill) to be credited with Net Excess Generation: ____________________________________________________ Annual Energy Requirements (kWh) in the previous twelve (12) months for the account physically attached to the Net-Metering Facility and for any additional accounts listed (in the absence of historical data reasonable estimates for the class and character of service may be made):_____________________________________________ Type of Facility (circle one) Customer Owned Leased Service Agreement

Section 2. Owner Information Name: Contact Person: Mailing Address: City: State: Zip Code: Daytime Phone: Evening Phone: E-Mail Address: Fax:

Section 3. Generation Facility Information System Type: Solar Wind Hydro Geothermal Biomass Fuel Cell Micro Turbine Energy Storage Device (circle all that apply) Generator Rating (kW): DC Inverger Rating (kW):______________________ AD Capacity Factor: __________________________________________ Expected annual production of electrical energy (kWh) of the facility calculated using industry recognized simulation model (PVWatts, etc): _______________________

Section 4. Interconnection Information Attach a detailed electrical diagram showing the configuration of all generating facility equipment, including protection and control schemes. Requested Point of Interconnection:___________________________________ Customer-Site Load (kW) at Net-Metering Facility location (if none, so state): ________________________________ Interconnection Request: Single Phase:___________ Three Phase:_____________

Section 5. Signature

I hereby certify that, to the best of my knowledge, all the information provided in this Preliminary Interconnection Site Review is true and correct.

Net Metering Customer Signature: _________________________________ Date: ____________________ Owner Signature (if different from Owner): ___________________________ Date: ____________________


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__2nd Revision ____ Sheet No. 44.4_ Replacing ____ ___1st Revision_ Sheet No. _



Schedule No.: NET



II. TERMS AND CONDITIONS

Section 1. Requirements for Request For the purpose of requesting that the Cooperative conduct a preliminary interconnection site review for a proposed Net-Metering Facility pursuant to the requirement of Rule 2.06.B.4, or as otherwise requested by the customer, the customer shall notify the Cooperative by submitting a completed Preliminary Interconnection Site Review Request. The customer shall submit a separate Preliminary Interconnection Site Review Request for each point of interconnection if information about multiple points of interconnection is requested. Part 1, Standard Information, Sections 1 through 4 of the Preliminary Interconnection Site Review Request must be completed for the notification to be valid. If mailed, the date of notification shall be the third day following the mailing of the Preliminary Interconnection Site Review Request. The Cooperative shall provide a copy of the Preliminary Interconnection Site Review Request to the customer upon request.

Section 2. Utility Review Following submission of the Preliminary Interconnection Site Review Request by the customer the Cooperative shall review the plans of the facility interconnection and provide the results of its review to the customer, in writing, within 30 calendar days. If the customer requests that multiple interconnection site reviews be conducted the Cooperative shall make reasonable efforts to provide the customer with the results of the review within 30 calendar days. If the Cooperative cannot meet the deadline it will provide the customer with an estimated date by which it will complete the review. Any items that would prevent Parallel Operation due to violation of safety standards and/or power generation limits shall be explained along with a description of the modifications necessary to remedy the violations.

The preliminary interconnection site review is non-binding and need only include existing data and does not require the Cooperative to conduct a study or other analysis of the proposed interconnection site in the event that data is not readily available. The Cooperative shall notify the customer if additional site screening may be required prior to interconnection of the facility. The customer shall be responsible for the actual costs for conducting the preliminary interconnection site review and any subsequent costs associated with site screening that may be required.

Section 3. Application to Exceed 1,000 kW Net-Metering Facility Size Limit This Preliminary Interconnection Site Review Request and the results of the Cooperative’s review of the facility interconnection shall be filed with the Commission with the customer’s application to exceed the 1,000 kW facility size limit pursuant to Net Metering Rule 2.06.B.4.

Section 4. Standard Interconnection Agreement The preliminary interconnection site review does not relieve the customer of the requirement to execute a Standard Interconnection Agreement prior to interconnection of the facility.


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__2nd Revised ____ Sheet No. 44.5_ Replacing ____ __1st Revised_ Sheet No. _



Schedule No.: NET



STANDARD INTERCONNECTION AGREEMENT FOR NET-METERING FACILITIES

I. STANDARD INFORMATION

Section 1. Customer Information Name: Mailing Address: City: State: Zip Code: Facility Location (if different from above): ____ Daytime Phone: Evening Phone: Utility Customer Account Number (from electric bill) to which the Net-Metering Facility is physically attached:

Type of Facility (circle one): Customer Owned Leased Service Agreement

Section 2. Owner Information Name: Contact Person: Mailing Address: City: State: Zip Code: Daytime Phone: Evening Phone: E-Mail Address: Fax:

Section 3. Generation Facility Information System Type: Solar Wind Hydro Geothermal Biomass Fuel Cell Micro Turbine Energy Storage Device (circle all that apply) Generator Rating (kW): DC Inverter Rating (kW): ______________________ _ AC Describe Location of Accessible and Lockable Disconnect (If required):

Inverter Manufacturer: Inverter Model: Inverter Location: Inverter Power Rating: Expected Capacity Factor: _____________________________________________________________________________________ Expected annual production of electrical energy (kWh) calculated using industry recognized simulation model (PVWatts, etc.): _____________________________

Section 4. Installation Information Attach a detailed electrical diagram of the Net-Metering Facility. Installed by: ________________________ Qualifications/Credentials: Mailing Address: City: State: Zip Code: Daytime Phone: Installation Date:

Section 5. Certification The system has been installed in compliance with the local Building/Electrical Code of City/County) Signed (Inspector): Date: (In lieu of signature of inspector, a copy of the final inspection certificate may be attached.)

The system has been installed to my satisfaction and I have been given system warranty information and an operation manual, and have been instructed in the operation of the system.

Signed (Net-Metering Customer): Date: Signed (Owner if different from Customer): Date:


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__2nd Revised ____ Sheet No. 44.6_ Replacing ____ __1st Revised__ Sheet No. __ _



Schedule No.: NET



Section 6. E-mail Addresses for parties Customer’s e-mail address: Owner’s e-mail address (if different from Customer): _ Utility’s e-mail address: _________________________________ (To be provided by utility.)

Section 7. Utility Verification and Approval Facility Interconnection Approved: Date: Metering Facility Verification by: Verification Date:

II. INTERCONNECTION AGREEMENT TERMS AND CONDITIONS

This Interconnection Agreement for Net-Metering Facilities ("Agreement") is made and entered into this day of , 20 , by ("Cooperative") and ("Customer"), a (specify whether corporation or other), and (“Owner”) a

(specify whether corporation or other), each hereinafter sometimes referred to individually as "Party" or collectively as the "Parties". In consideration of the mutual covenants set forth herein, the Parties agree as follows:

Section 1. The Net-Metering Facility The Net-Metering Facility meets the requirements of Ark. Code Ann. § 23-18-603(8) and the Arkansas Public Service Commission's Net-Metering Rules.

Section 2. Governing Provisions The Parties shall be subject to the provisions of Ark. Code Ann. § 23-18-604 and the terms and conditions set forth in this Agreement, the Commission’s Net-Metering Rules, the Commission’s General Service Rules, and the Cooperative's applicable tariffs.

Section 3. Interruption or Reduction of Deliveries The Cooperative shall not be obligated to accept and may require Customer to interrupt or reduce deliveries when necessary in order to construct, install, repair, replace, remove, investigate, or inspect any of its equipment or part of its system; or if it reasonably determines that curtailment, interruption, or reduction is necessary because of emergencies, forced outages, force majeure, or compliance with prudent electrical practices. Whenever possible, the Utility shall give the Customer reasonable notice of the possibility that interruption or reduction of deliveries may be required. Notwithstanding any other provision of this Agreement, if at any time the Utility reasonably determines that either the facility may endanger the Cooperative's personnel or other persons or property, or the continued operation of the Customer's facility may endanger the integrity or safety of the Utility's electric system, the Cooperative shall have the right to disconnect and lock out the Customer's facility from the Cooperative's electric system. The Customer's facility shall remain disconnected until such time as the Cooperative is reasonably satisfied that the conditions referenced in this Section have been corrected.


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__2nd Revised____ Sheet No. 44.7_ Replacing ____ ___1st Revised_ Sheet No. __ _



Schedule No.: NET



Section 4. Interconnection Customer shall deliver the as-available energy to the Cooperative at the Cooperative's meter.

Cooperative shall furnish and install a standard kilowatt hour meter. Customer shall provide and install a meter socket for the Cooperative's meter and any related interconnection equipment per the Cooperative's technical requirements, including safety and performance standards.

The customer shall submit a Standard Interconnection Agreement to the Cooperative at least thirty (30) days prior to the date the customer intends to interconnect the Net-Metering Facilities to the utility's facilities. Part I, Standard Information, Sections 1 through 6 of the Standard Interconnection Agreement must be completed be valid. The customer shall have all equipment necessary to complete the interconnection prior to such notification. If mailed, the date of notification shall be the third day following the mailing of the Standard Interconnection Agreement. The Cooperative shall provide a copy of the Standard Interconnection Agreement to the customer upon request.

Following submission of the Standard Interconnection Agreement by the customer, the utility shall review the plans of the facility and provide the results of its review to the customer, in writing, within 30 calendar days. Any items that would prevent Parallel Operation due to violation of applicable safety standards and/or power generation limits shall be explained along with a description of the modifications necessary to remedy the violations.

If the Cooperative’s existing facilities are not adequate to interconnect with the Net-Metering Facility, the Customer shall pay the cost of additional or reconfigured facilities prior to the installation or reconfiguration of the facilities.

To prevent a Net-Metering Customer from back-feeding a de-energized line, the customer shall install a manual disconnect switch with lockout capability that is accessible to utility personnel at all hours. This requirement for a manual disconnect switch will be waived if the following three conditions are met: 1) The inverter equipment must be designed to shut down or disconnect and cannot be manually overridden by the customer upon loss of utility service; 2) The inverter must be warranted by the manufacturer to shut down or disconnect upon loss of utility service; and 3) The inverter must be properly installed and operated, and inspected and/or tested by utility personnel.

Customer, at customer’s expense, shall meet all safety and performance standards established by local and national electrical codes including the National Electrical Code (NEC), the Institute of Electrical and Electronics Engineers (IEEE), the National Electrical Safety Code (NESC), and Underwriters Laboratories (UL).

Customer, at customer’s expense, shall meet all safety and performance standards adopted by the utility and filed with and approved by the Commission that are necessary to assure safe and reliable operation of the Net Metering Facility to the utility's system.

.


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_2nd Revised ____ Sheet No. 44.8_ Replacing ____ __1st Revised__ Sheet No. __ _



Schedule No.: NET



Customer shall not commence Parallel Operation of the Net-Metering Facility until the Net Metering Facility has been inspected and approved by the Cooperative. Such approval shall not be unreasonably withheld or delayed. Notwithstanding the foregoing, the Cooperative's approval to operate the Customer's Net-Metering Facility in parallel with the Utility's electrical system should not be construed as an endorsement, confirmation, warranty, guarantee, or representation concerning the safety, operating characteristics, durability, or reliability of the Customer's Net-Metering Facility

Section 5. Modifications or Changes to the Net-Metering Facility Described in Part 1, Section 2

Prior to being made, the Customer shall notify the Cooperative of, and the Cooperative shall evaluate, any modifications or changes to the Net-Metering Facility described in Part 1, Standard Information, Section 2 of the Standard Interconnection Agreement for Net-Metering Facilities. The notice provided by the Customer shall provide detailed information describing the modifications or changes to the Utility in writing, including a revised Standard Interconnection Agreement for Net-Metering Facilities that clearly identifies the changes to be made. The Cooperative shall review the proposed changes to the facility and provide the results of its evaluation to the Customer, in writing, within thirty (30) calendar days of receipt of the Customer's proposal. Any items that would prevent Parallel Operation due to violation of applicable safety standards and/or power generation limits shall be explained along with a description of the modifications necessary to remedy the violations.

If the Customer makes such modification without the Cooperative’s prior written authorization and the execution of a new Standard Interconnection Agreement, the Cooperative shall have the right to suspend Net-Metering service pursuant to the procedures in Section 6 of the Commission’s General Service Rules.

A Net-Metering Facility shall not be modified or changed to generate electrical energy in excess of the amount necessary to offset all of the Net-Metering Customer requirements for electricity.

Section 6. Maintenance and Permits The customer shall obtain any governmental authorizations and permits required for the construction and operation of the Net-Metering Facility and interconnection facilities. The Customer shall maintain the Net-Metering Facility and interconnection facilities in a safe and reliable manner and in conformance with all applicable laws and regulations.

Section 7. Access to Premises The Cooperative may enter the Customer's premises to inspect the Customer's protective devices and read or test the meter. The Cooperative may disconnect the interconnection facilities without notice if the Cooperative reasonably believes a hazardous condition exists and such immediate action is necessary to protect persons, or the Cooperative's facilities, or property of others from damage or interference caused by the Customer's facilities, or lack of properly operating protective devices.


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__2nd Revised ____ Sheet No. 44.9_ Replacing ____ __1st Revised__ Sheet No. __ _



Schedule No.: NET



Section 8. Indemnity and Liability The following is Applicable to Agreements between the Cooperative and to all Customers and Owners except the State of Arkansas and any entities thereof, local governments and federal agencies:

Each Party shall indemnify the other Party, its directors, officers, agents, and employees against all loss, damages, expense and liability to third persons for injury to or death of persons or injury to property caused by the indemnifying party's engineering, design, construction, ownership, maintenance or operations of, or the making of replacements, additions or betterment to, or by failure of, any of such Party's works or facilities used in connection with this Agreement by reason of omission or negligence, whether active or passive. The indemnifying Party shall, on the other Party's request, defend any suit asserting a claim covered by this indemnity. The indemnifying Party shall pay all costs that may be incurred by the other Party in enforcing this indemnity. It is the intent of the Parties hereto that,where negligence is determined to be contributory, principles of comparative negligence will be followed and each Party shall bear the proportionate cost of any loss, damage, expense and liability attributable to that Party’s negligence. Nothing in this paragraph shall be applicable to the Parties in any agreement entered into with the State of Arkansas or any entities thereof, or with local governmental entities or federal agencies. Furthermore, nothing in this Agreement shall be construed to waive the sovereign immunity of the State of Arkansas or any entities thereof. The Arkansas State Claims Commission has exclusive jurisdiction over claims against the state.

Nothing in this Agreement shall be construed to create any duty to, any standard of care with reference to or any liability to any person not a Party to this Agreement. Neither the Cooperative, its officers, agents or employees shall be liable for any claims, demands, costs, losses, causes of action, or any other liability of any nature or kind, arising out of the engineering, design, construction, ownership, maintenance or operation of, or the making of replacements, additions or betterment to, or by failure of, the Customer's facilities by the Customer or any other person or entity.

Section 9. Notices The Net-Metering Customer shall notify the Cooperative of any changes in the information provided herein.

All written notices shall be directed as follows:

Attention: President/CEO Ozarks Electric Cooperative Corporation P.O. Box 848 Fayetteville, AR 72702]

Attention: [Customer] Name: Address: City: E-Mail: Customer notices to Cooperative shall refer to the Customer's electric service account number set forth in Section 1 of this Agreement.


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__2nd Revised ____ Sheet No. 44.10_ Replacing ____ _1st Revised___ Sheet No. __ _



Schedule No.: NET



Section 10. Term of Agreement The term of this Agreement shall be the same as the term of the otherwise applicable standard rate schedule. This Agreement shall remain in effect until modified or terminated in accordance with its terms or applicable regulations or laws.

Section 11. Assignment This Agreement and all provisions hereof shall inure to and be binding upon the respective Parties hereto, their personal representatives, heirs, successors, and assigns. The Customer and/or Owner shall not assign this Agreement or any part hereof without the prior written consent of the Cooperative, and such unauthorized assignment may result in termination of this Agreement.

Section 12. Net-Metering Customer and Owner Certification I hereby certify that all of the information provided in this Agreement is true and correct, to the best of my knowledge, and that I have read and understand the Terms and Conditions of this Agreement.

Signature (Customer): ________________________________________________ Date: __________________

Signature (Owner if different from Customer): ______________________________ Date: __________________

IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their duly authorized representatives.

Dated this day of , 20__.

Customer: Cooperative: Ozarks Electric Cooperative Corporation

By: By: Title: Title: Mailing Address: Mailing Address:

P.O. Box 848 Fayetteville, AR 72702

E-mail Address: E-mail Address: _________________ __________ ___________________________

Third-Party Owner (if applicable):

By: Title:

Mailing Address:

E-mail Address:


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_2nd Revised ____ Sheet No. 44.11_ Replacing ____ __1st Revised__ Sheet No. __ _



Schedule No.: NET



STANDARD INTERCONNECTION AGREEMENT FOR NET-METERING FACILITIES

Disclaimer POSSIBLE FUTURE RULES OR RATE CHANGES, OR BOTH

AFFECTING YOUR NET-METERING FACILITY

The following is a supplement to the Interconnection Agreement you signed with Ozarks Electric Cooperative Corporation.

1. Electricity rates, basic charges, and service fees, set by Ozarks Electric Cooperative Corporation andapproved by the Arkansas Public Service Commission (Commission), are subject to change.

2. I understand that I will be responsible for paying any future increases to my electricity rates, basiccharges, or service fees from Ozarks Electric Cooperative Corporation.

3. My Net-Metering System is subject to the current rates of Ozarks Electric Cooperative Corporation, andthe rules and regulations of the Commission. Ozarks Electric Cooperative Corporation may change itsrates in the future with approval of the Commission or the Commission may alter its rules and regulations,or both may happen. If either or both occurs, my system will be subject to those changes.

By signing below, you acknowledge that you have read and understand the above disclaimer. ___________________________________

Name (printed) ___________________________________

Signature (Customer) ___________________________________

Date


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ARKANSAS PUBLIC SERVICE COMMISSIONAPSC FILED Time: 10/1/2015 1:45:38 PM: Recvd 10/1/2015 1:43:52 PM: Docket 15-090-TF-Doc. 5

Original Sheet No. 45 _ Replacing Sheet No. _



Schedule No.: SURGE

Title: Surge HELP® Insurance PSC File Mark Only


DESCRIPTION OF SERVICE

As a service to members, the Cooperative will provide access to the Surge HELP® Program. This insurance program provides participants with their desired level of insurance coverage for losses associated with damage caused by transient voltage surges. Transient voltage surges are typical on any electrical, telephone or television system. They can occur as a result of lightning strikes, switching of equipment or other reasons. Transient voltage surges cannot be totally eliminated from any system.

AVAILABILITY

Surge HELP® Insurance is an optional enhanced service available upon request of the customer. Insurance is limited to single-phase customers and is subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission and the rules of the Commission

PROGRAM

Upon receiving an executed Surge HELP® Insurance Agreement, the Cooperative will enroll new customers in the Surge HELP® Insurance Program at their desired level of coverage.

Customers, who previously participated in the Safeguard Pro Program may continue to utilize their current surge protection equipment installed by the Cooperative. The Cooperative will continue to support this equipment until the warranty expires. These existing customers will also be enrolled in the Surge HELP® Insurance Program for coverage of $2,000 at no cost to these existing customers. Any and all initial claims will first be processed through the Surge HELP® Insurance Program. If the damage exceeds $2,000 then the Cooperative will process the remainder of the claim.

FEE FOR SERVICE

The fee for the above described service shall be as follows and will be included as an additional specified monthly charge on the customer’s regular monthly electric bill.

Monthly Service Fee:

New Customers: $3.95-$11.95/month for enrollment at the customer’s desired level of coverage.

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Schedule No.: SURGE



AGREEMENT FOR SERVICE

The Customer will request service by completing and signing a Surge HELP® Insurance Agreement.

TERM

The customer shall agree to receive Surge HELP® Insurance on a month-to-month basis.

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Schedule No.: SURGE



SURGE HELP® INSURANCE AGREEMENT

MEMBER INFORMATION:

Date Name

Address

City State Zip

Account No.

Phone No.

(home) (work)

The undersigned member hereby purchases from Ozarks Electric Cooperative Corporation (Ozarks) the following:

Surge HELP®: PRICE

SURGE HELP® - $1,000/YEAR $3.95





Insurance is leased on a month-to-month basis and can be canceled at any time.

WARRANTY

OZARKS EXPRESSLY DISCLAIMS ALL WARRANTIES OF ANY KIND, INCLUDING THE WARRANTIES OF MERCHANTABILITY AND FITNESS FOR PARTICULAR PURPOSE. THE MANUFACTURER’S WARRANTY SHALL BE THE EXCLUSIVE REMEDY AVAILABLE. OZARKS SHALL NOT BE LIABLE FOR INCIDENTAL OR CONSEQUENTIAL DAMAGES RESULTING FROM ANY DEFECT OR FAILURE OF THIS PRODUCT.

MEMBER’S SIGNATURE DATE:

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ARK. PUBLlC SEW. COHH ARKANSAS PUBLIC SERVICE COMMISSION __

Original



Schedule No: ELCCP

Title: Emergency Load Conservation and Curtailment Plan

PSC File Mark Only

CP EMERGENCY LOAD CONSERVATION AND CURTAILMENT Policy

1. INTRODUCTION

Ozarks Electric Cooperative (Cooperative) and the Electric Cooperatives of Arkansas' (ECOA) function together to design and maintain an Emergency Load Consewation and Curtailment Plan (ELCCP).

The ECOA are subject to the mandatory reliability standards of the North American Electric Reliability Corporation (NERC) as approved by the Federal Energy Regulatory Commission. The NERC Reliability standards and Southwest Power Pool (SPP) criteria call for the establishment of plans and procedures to provide load relief and minimize the probability of network collapse during major system contingencies. The SPP Criteria 7.3 outlines a recommended method for the reduction of load during a major emergency contingency and the orderly restoration of load while maintaining system stability following a contingency. SPP Criteria 7.3 also calls for these plans to be coordinated between pool member companies to insure efforts to minimize system impact are sufficient and restoration is orderly.

The load relief measures in the ELCCP are design4 to preserve the integrity of the transmission grid in the case of an extreme emergency. The implaentation of these measures is intended only to o c a once all other operational means have been exhausted. Due to the critical nature and time constraints involved in the implementation of these measures may require immediate action. These measures can be implemented at any time and for any period of time necessary.

Arkansas Electric Cooperative Corporation, Arkansas Valley Electric Cooperative Corp. (Ozark, Arkansas); AshIey-Chicot 1

Electric Cooperative, Inc. (Hamburg, Arkansas); C&L Electric Cooperative Cop. (Star City, Arkansas); Carroll Electric Cooperative Corp. (BerryvllIe, Arkansas); Clay County Electric Coqmative Corp. (Corning, Arkansas); Craighead Electric Cooperative Corp. (Jonesboro, Arkansas); Farmers Electric Cooperative Corporation (Newport, Arkansas); First Electric Cooperative Corp. (Jacksonville, Arkansas); Mississippi County Electric Cooperative, Inc. (Blythevilk, A r b s ) ; North Arkansas Electric Cooperative, Inc. (Salem, Arkansas); Ouachita Electric Cooperative Corp. (Camden, Atkansas); Ozarks Electric Cooperative Corp. (Fayetteville, Arkansas); Petit Jean Electtic Cooperative Cow. (Clinton, Arkansas); Rich Mountain Electric Cooperative, Inc. (Mem Arkansas); South Central Arkansas Electric Cooperative, Inc. (Arkadelphia, Arkansas); Southwest Arkansas Ekctric CoOpaative Corp. (Texarkana, Arkansas); and Woodruff Electric Cooperative C q . ( F o m t city, Arkansas).


KRHUDE

10-059-U

Oriqinal Sheet No. 48.1 Replacing Sheet No.


Kind of Service: Electric Class of Service: &ll

Schedule No: ELCCP

‘ : t f : - I H i t L UI Y”

??\r) r ~ p 28 A 9: 49

. I-* 13

PSC Fib Mark Only

Title: Emergency Load Conservation and Curtailment Ptan

When called upon by Arkansas Electric Cooperative Corporation (AECC), the Reliability Coordinator or the Transmission Operator, AECC and Cooperative will implement the ELCCP to achieve the necessary load reduction.

2. ELCCP PLAN OVERVIEW

ECOA’s ELCCP is comprised of two major plans to address the two levels of intervention as described in SPP Criteria 7.3. The first addresses the automatic load shedding and is referred to as the Under- frequency Plan (UFP). The second plan addresses the manual load shedding level of intervention and is called the Manual Load Shedding Plan (MLSP).

The UFP is maintained by AECC. The UFP is an automatic scheme utilizing under-frequency relaying to respond to system disturbances. These relays react to a system disturbance without human intervention. These relays react in a critical period of system frequency excursion. AECC’s UFP is designed to meet AECC’s obligations under SPP Criteria 7.3.

The MLSP calls for load reduction during times of prolonged system limitations or contingencies. System emergencies that require implementation of the MLSP involve severe system disturbances creating a situation where automatic systems and n o d operator actions are not enough to maintain system integrity thus requiring load reductions either voluntarily or through manually shedding.

The MLSP includes a number of load cunservation measures that can be implemented. These measures are comprised of voluntary and prearranged load relief efforts that can be utilized before manual load shedding is implemented.

The MLSP consists of seven (7) levels of interruption as follows. The following lists the levels of the MLSP in the normal order of implementation. During an emergency the actual order could vary depending on the nature of the emergency and the time available before relief is necessary.


KRHUDE

10-059-U

- rF'C?ETARY QF r p ; ~ Otisinal Sheet No. 48.2

Replacing Sheet No.



Schedule No: ELCCP

: : p-J . -A .*

PSC File Mark OnIy

Title: Emergency load Consewation and Curtailment Plan

LEVEL 1 Intemptible Loads (IC) Served Under an IC Rider

Level 1 includes the interruption of Cooperative and other AECC member cooperative IC loads, as necessary, subject to AECC's IC Rider.

LEVEL 2 Reduce Any Ron-Essential Cooperative Facilities

Level 2 calls for an appeal from AECC to its member cooperatives, including Cooperative, to reduce electricity usage in the Cooperative's facilities.

Examples: Lighting loads, non-essential equipment, adjusting thermostats (80 degrees in summer and 65 degrees in winter), and turning heating or cooling systems off.

LEVEL 3 Voluntary Reductions (General)

Level 3 calls for public appeals for voluntary reductions and includes issuing news releases to TV, radio, newspapers and other media requesting reductions.

After evaluating the possible scope and duration of the load curtailment event, AECC a d o r Cooperative shall make appropriate and reasonable efforts to provide the public with information regarding the event. Prior to the even& Cooperative shdI have designated certain employees to communicate with the public and appropriate media outlets.

LEVEL 4 Voluntary Reductions (Prearranged)

Level 4 is an appeal h m AECC to its member cooperatives for any prearranged retail, commercial, or industrial loads which have the flexibility to voluntarily reduce their load.


KRHUDE

10-059-U

ARKANSAS PUBLIC SERVICE COMMISSION ARK. PUBLIC SERV. COMH


Kind of Service: Electric Class of Service: &ll

Schedule No: ELCCP

Title: Emergency Load Conservation and Curtailment Plan

LEVEL 5 Use of Cooperative and Other ECOA Load Management Systems

Level 5 is an appeal h m AECC to Cooperative and other AECC member cooperatives, as necessary, for the emergency implementation of any load management systems they may have available.

LEVEL 6 Reduce Voltage

Level 6 is an appeal h AECC for the reduction of system voltage by its member cooperatives that are capable of impIemmting voltage reduction. Voltage reduction is set forth in SPP Criteria 7.3 as a possible step to reduce load.

LEVEL 7 Manual Switching

Level 7 calls for manual load shedding. Cooperative, in coordination with AECC, has selectsd certain distribution circuits which will be switched out on a rotating basis.

In making that selection, AECC and Cooperative take into account the need to maintain critical loads essential to the health, safety and welfare of the community.

3. REPORTING PROCEDURES

Upon implementation of the ELCCP, the Arkansas Public Service Commission (APSC) and other appropriate governmental agencies shall be notified by either AECC a d o r Cooperative. As soon as practical or as required, AECC andlor Cooperative will file necessary follow-up reports to meet APSC andor otha governmental agency requirements.


KRHUDE

10-059-U


Original Sheet No. 49.0 Replacing Sheet No.



Schedule No.: O.N.E. SOLAR

Title: OZARKS NATURAL ENERGY SOLAR PROGRAM PSC File Mark Only


AVAILABILITY:

The Ozarks Natural Energy (O.N.E.) Solar Program is available on a voluntary basis to metered Arkansas Residential and Commercial Members taking service under Rate Schedules GS-1 and GS-3, or any successor(s) to those schedules, who enter into a O.N.E. Program Agreement with Ozarks Electric Cooperative Corporation, Inc., (Ozarks Electric) included as Attachment A to this tariff (Eligible Member).

DESCRIPTION

O.N.E. is a renewable energy program that includes a one megawatt solar facility located in Springdale, Arkansas (Solar Facility). As part of the program members may purchase shares of the Solar Facility that entitle the Member to the output of the facility equal to 0.0245% per share of the total production of the Solar Facility on a monthly basis. The Member’s account will be credited based on the Share Credit as described below. Total shares available for purchase from this Solar Facility are limited to 4,080 shares.

PURCHASE PRICE PER SHARE

The initial Purchase Price Per Share effective through April 2017 is $340.00, thereafter the Purchase Price per share shall be reduced by 4% each calendar year.

LIMITED PURCHASE QUANTITY

Shares may be purchased in quantities ranging from 1 to 100. The energy produced by the Member’s purchased shares is not intended to exceed the total annual usage of the participating account.

TERM

Each share shall be active after the enrollment period set forth by Ozarks Electric for a Term ending May 2041 or until terminated pursuant to the terms of the License Agreement.

SHARE CREDIT

During each monthly billing period, a Share Credit will be provided to the Member based on the actual energy produced by the Member’s purchased shares multiplied by an Energy Rate Credit Factor (ERCF) per kWh included in Attachment B to this tariff. The Share Credit shall be calculated as follows:

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1st Revision Sheet No. 49.1 Replacing Original Sheet No.



Schedule No.: O.N.E. SOLAR

Title: OZARKS NATURAL ENERGY SOLAR PROGRAM

PSC File Mark Only


Share Credit = A * B * C Where,

A = Total energy output of the entire solar array facility for the prior month, as measured by appropriate metering devices

B = Energy Rate Credit Factor in $/kWh C = The percentage of purchased shares owned by the Member

In the event that the credit for share ownership surpasses consumption of an assigned account, the credit will be carried forward to Member’s subsequent bills for the account. If at the end of the calendar year credits from shares remain, the credits will become property of Ozarks Electric.

ANNUAL REDETERMINATION

On or before March 15, annually, the Cooperative shall file a re-determined ERCF with the Commission. The re-determined ERCF shall be determined by application of the ERCF formula set out in Attachment B to this schedule. Each such revised ERCF shall be filed in the same docket and shall be accompanied by a set of work papers sufficient to fully document the calculations of the revised ERCF.

The ERCF so determined shall be effective, after Commission approval, for bills rendered on and after the first billing cycle of May of the filing year and shall remain in effect until the last billing cycle of April of the following year.


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Attachment A Rate Schedule O.N.E. Solar

Page 1 of 3


Ozarks Natural Energy Program Agreement

Ozarks Electric Cooperative

Contract Number ____________________

This Agreement is made and entered into this _____ day of _________, 20___ by and between Ozarks Electric Cooperative Corporation, Inc., (Ozarks Electric), with its principal place of business at 3641 Wedington Drive, Fayetteville, Arkansas 72704, and its mailing address at P.O. Box 848, Fayetteville, Arkansas 72702, and the Member, identified as follows:

Member Name: _____________________________________________________

Account Number: __________________________________________________

Street Address: ______________________________________________________

Service Address: ____________________________________________________ If different than street address

City: ______________________ State: ________ Zip Code: ____________

Telephone Number: ___________________________________________________

SHARE OWNERSHIP:

Subject to the terms and conditions set forth, Ozarks Electric hereby grants to the above mentioned Member ________ number of shares of the total production of Ozarks Natural Energy (O.N.E.) Unit #1. These shares shall be credited to the Member’s account based on 0.0245% per share of the total production of O.N.E. Unit #1 on a per-month basis. Shares may only be purchased in single- or consecutively-numbered groups. The member will receive the share production credits allocated during the designated term to each of the following shares, identified by the following unique number(s):

_____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________ _____________

In the event the applicable account associated with this Agreement is removed and/or not in service, Ozarks Electric will make every attempt to contact the member to determine where share credits can be transferred. During this time, the electricity produced by these panels will be provided to the utility grid system and utilized by the entire membership of Ozarks Electric. If after 60 days the member listed in this Agreement cannot be located to determine where share credits should be applied, share credit values will become the sole ownership of Ozarks Electric.


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TERM

Each share shall be active after the enrollment period set forth by Ozarks Electric for a Term ending May 2041 or until terminated pursuant to the terms of the License Agreement.

TERMINATION PROVISIONS:

In the event that the participating member discontinues electric service or elects to discontinue participation in the program, the Member’s shares may be assigned to another active qualified Ozarks Electric account or repurchased by the Cooperative. It is the member’s responsibility to notify Ozarks Electric of such change in writing via regular mail, email, or fax at least 30 days prior to the effective date of change. Share credits may not exceed total consumption of the account to which they are transferred. Notification shall include the following information:

1. Member’s name, mailing address and account number;2. Agreement number, number of shares to be transferred and share identification numbers;3. Current billed address;4. The name of the individual or entity to whom member is assigning this Agreement5. New billed address and account number;6. The effective date of such change or assignment.

The repurchase rate for member shares by Ozarks Electric shall be equal to the then effective fixed subscription amount per share for the current calendar year.

OZARKS ELECTRIC OBLIGATIONS:

Ozarks Electric agrees to:

• Provide all maintenance for O.N.E. Ozarks Electric shall be responsible for ensuring that O.N.E.and each of its components meet all applicable codes, standards and regulatory requirements atthe time of installation and throughout the term of this Agreement. In the event of equipmentfailure, Ozarks Electric will bring the equipment back to working order as quickly as possible. Inthe event damaged equipment may be disconnected from the grid or is otherwise not generatingelectric energy, the Member will not receive any output for production until O.N.E. Unit #1 facilityis reconnected to the electrical grid.

• Acquire and maintain, at its sole cost, insurance for O.N.E. Ozarks Electric will be listed as thesole loss payee for such insurance. In the event part or the whole of O.N.E. Unit #1 facility isdamaged beyond repair, Ozarks Electric may elect, at its sole discretion, to replace such parts orthe whole solar array if deemed necessary.


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Governing Law/Jurisdiction/Venue: This Agreement shall be deemed to have been made in, and shall be construed under, the internal laws of the State of Arkansas, without regard to the principles of conflicts of laws thereof. WITNESS WHEREOF, the parties have executed this Agreement as of the date written below. ___________________________________ ___________________________________ Member Name (please print) Member Signature ___________________________________ Date OZARKS ELECTRIC COOPERATIVE CORPORATION, INC. REPRESENTATIVE Name: _____________________________ Title: _______________________________


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Exhibit A Attachment B

Rate Schedule O.N.E. Solar

ENERGY RATE CREDIT FACTOR

The Energy Rate Credit Factor applicable to the period May 2021 to April 2022 is $0.04066 per kWh.

______________________________________

ENERGY RATE CREDIT FACTOR FORMULA

.

ERCF ($/kWh) = PRC * (1 + (AWC* PCP))

Where:

PRC = Prior year energy rate credit in $/kWh

AWC = Average Wholesale Cost Compound Growth Rate. The compound rate of growth in the Average Wholesale Cost per kWh for the previous five years calculated using data from the Cooperative’s annual Financial and Statistical Report (CFC Form 7) Part L for energy supplied by Arkansas Electric Cooperative Corporation.

PCP = Wholesale Power Cost as a percent of Operating Revenue. The sum of the previous five years wholesale power cost divided by the sum of the previous five years operating revenue (excluding non-electric revenue) calculated using data from the Cooperative’s CFC Form 7 Part A for Arkansas only.


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Documents

ARKANSAS PUBLIC SERVICE COMMISSION 13th Revision Sheet …