replacing 1st first electric cooperative corporation ark

THIS SPACE FOR PSC USE ONLY

ARKANSAS PUBLIC SERVICE COMMISSION

2nd Revised Sheet No. TC-1

Replacing 1st Revised Sheet No. TC-1

First Electric Cooperative Corporation Name of Company

Kind of Service: Electric Class of Service: All

TABLE OF CONTENTS PSC File Mark Only

Class of Service Schedule Name

Sheet Number

PART I. GENERAL INFORMATION

All 1. Utility Information

1

All 2. Tariff Format

2

All 3. Definitions

4

PART II. EXEMPTIONS

All 1. Current Status

6

PART III. RATE SCHEDULES

Residential 1. Single Phase Residential, Churches, and Schools

7

Residential/Commercial 2. Three Phase Service (50 kVA and Under)

10

3. (Reserved for Future Use)

Commercial 4. General Service

13

Irrigation 5. Agricultural Water Pumping Service

16

6. – 7. (Reserved for Future Use)

Lighting 8. Security Lighting Service

19


21


24

Irrigation 11. Optional Controlled Agricultural Water Pumping (5 Hr. Control)

26

Lighting 12. Athletic Field Lighting

28

APSC FILED Time: 1/30/2017 11:47:05 AM: Recvd 1/30/2017 11:42:12 AM: Docket 87-159-U-Doc. 209

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Karen.Shook

Sticky Note



6th Revised Sheet No. TC-2

Replacing 5th Revised Sheet No. TC-2





Sheet Number

PART III. RATE SCHEDULES (continued)

Commercial/Industrial 13. Large General Service

30

Commercial/Industrial 14. Customer Managed Interruptible Credit

33

Commercial/Industrial 15. Load Management Control- Large General Service

35

Industrial 16. Industrial Power Service – Optional Interruptible

37

17. -19. (Reserved for Future Use)

44

Prepaid Electric Service 20. Prepaid Electric Service 45 CT

Residential/Commercial 21. Load Control of Air Conditioning

46

Residential/Commercial 22. Load Control of Water Heaters

48

Single Phase 23. Transient Voltage Surge Suppression Service (CLOSED)

49.1

24.-50.

(Reserved for Future Use)

Commercial 51. Single Phase Commercial (50 kVA and Under)

50

52.-53. (Reserved for Future Use)

Lighting 54. Municipal Street Lighting Service

53

Lighting 55. Traffic Signal Service

56

All 56. Cost of Energy Adjustment

58

All 57. Calculation of Cost of Energy Adjustment Factors

59


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6th Revised Sheet No. TC-3

Replacing 5th Revised Sheet No. TC-3




Class of Service Schedule Name Sheet Number

PART III. RATE SCHEDULES (continued)

All 58. Cost of Debt Adjustment 61 All 59. Cost of Debt Adjustment Report 62 As Applicable 60. Power Factor Adjustment Rider 63.1 As Applicable 61. Voltage Fluctuations and Harmonic Distortion

Rider64

All 62. Terms of Payment Rider 65 As Applicable 63. Charges Related to Customer Activity 66 As Applicable 64. Tax Adjustment 70 As Applicable 64.1 Emergency Service – Benton (Closed 9/30/2016) 70.01 All 65. Net Metering 70.1a

66.-69. (Reserved for Future Use) As Applicable 70. Extension of Facilities 71 As Applicable 71. Installation of Underground Facilities 77

PART IV. POLICY SCHEDULES

All 1. Extended Absence Payment Plan 81

Residential 2. Extended Due Date Plan 82

Residential 3. Levelized Billing Plan 84

Residential 4. Provisions for Landlords and Tenants 86

All 5. Meter Testing Program 87

All 6. Standard Nominal Voltages 88

All 7. Voltage Verification Plan 89

ARKANSAS PUBLIC SERVICE COMMISSION APSC FILED Time: 11/8/2017 4:01:34 PM: Recvd 11/8/2017 4:00:54 PM: Docket 16-027-R-Doc. 266

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Original Sheet No. TC-4

Replacing Sheet No.





Sheet Number

PART IV. POLICY SCHEDULES (continued)

All 8. Pole Identification System

90

All 9. Supplying and Taking of Electric Service

91

All 10. Customer’s Installation

92

All 11. Cooperative’s Installation

93

All 12. Billing

95

All 13. Stopping Service By Customer

96


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1st Revised Sheet No. 1

Replacing Original Sheet No. 1



Part I. General Information Schedule No.: 1

Title: UTILITY INFORMATION PSC File Mark Only

1. UTILITY INFORMATION

Utility Official: Mr. Don Crabbe President and CEO

CT

Telephone Number: (501) 982-4545

Fax Number: (501) 982-8450

Mailing Address: First Electric Cooperative Corporation 1000 South JP Wright Loop Road (72076) PO Box 5018 Jacksonville, AR 72078-5018

CT CT


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Original Sheet No. 2

Replacing Sheet No.




Title: TARIFF FORMAT PSC File Mark Only

2. TARIFF FORMAT

2.1. TARIFF SYMBOLS

2.1.1. The following symbols appear in the right margin opposite any revision to the previously approved tariff.

Symbol Explanation

DR Discontinued Rate

AT Additions to Text

RT Removal of Text

CR Change in Rate

CP Change in Practice

CT Change in Text

NR New Rate

C A Correction

MT Move of Text

2.2. SHEET NUMBERING

2.2.1. Sheet numbers appear in the upper left corner of the sheet. The Table of Contents sheets are numbered sequentially beginning with TC-1. All other sheets are numbered sequentially beginning with 1. When a new sheet is added between sheets already in effect, a decimal is added. For example, a new sheet added between sheet 5 and 6 would be 5.1.

2.3. SHEET REVISIONS

2.3.1. Sheet revisions appear in the upper left corner of the sheet and are used to determine the most current sheet version on file with the Arkansas Public Service Commission. For example, the 3rd Revised Sheet No. 16 Replacing 2nd Revised Sheet No. 16.


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Replacing Sheet No.




Title: TARIFF FORMAT PSC File Mark Only

2.4. PARAGRAPH NUMBERING SEQUENCE

2.4.1. There are seven levels of paragraph numbering.

2. 2.1. 2.1.1. 2.1.1.A. 2.1.1.A.(1) 2.1.1.A.(1)a. 2.1.1.A.(1)a.(i)


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Replacing Sheet No.




Title: DEFINITIONS PSC File Mark Only

3. DEFINITIONS

3.1. The following definitions as used in the Rate Schedules, Policy Schedules, and in Service Agreements, shall, unless otherwise indicated, have the meaning given below:

3.2. COOPERATIVE EXTENSION TO CUSTOMER

3.2.1. Any branch from, or continuation of, an existing line to the point of delivery to customer, including increases in capacity of any of Cooperative’s existing facilities, or the changing of any lines to meet the customer’s requirements, including all transformers, service drops, meters, and installed service facilities owned by the Cooperative.

3.3. DUE DATE OF BILL

3.3.1. Shall mean the date after which a bill is considered delinquent and a late payment charge may be imposed.

3.4. METER

3.4.1. The meter or meters, together with auxiliary devices, if any, constituting the complete installation needed to measure the power and energy supplied to any individual customer at a single point of delivery.

3.5. MONTH

3.5.1. An interval of approximately 30 days.

3.6. NATIONAL ELECTRIC CODE

3.6.1. The National Electrical Code Standard of the National Board of Fire Underwriters for Electric Wiring and Apparatus as recommended by the National Fire Protection Association, and as may from time to time be amended or revised.

3.7. NOTICE

3.7.1. A written notification delivered personally or mailed by one party to the other at such other party’s last known address - the period of notice being computed from the date of such personal delivery or three (3) days after the date on which the notice is placed in the United States mail.


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Replacing Sheet No.




Title: DEFINITIONS PSC File Mark Only

3.8. POINT OF DELIVERY

3.8.1. The point at which Cooperative ownership of facilities terminates and at which customer’s ownership of facilities begins, or as otherwise defined and agreed upon in an Agreement for Service.

3.9. RATE SCHEDULE

3.9.1. Schedule of charges for each class of service approved by the Arkansas Public Service Commission, or other governing body.

3.10. SERVICE DROP

3.10.1. The wires owned by Cooperative connecting Cooperative’s distribution facilities to customer’s service terminals.


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4th Revised Sheet No. 6

Replacing 3rd Revised Sheet No. 6



Part II. Exemption Schedule No.: 1

Title: CURRENT STATUS PSC File Mark Only

1. CURRENT STATUS

1.1. INTEREST CHARGE FOR APPLICANT WITH PREVIOUS UNPAID BILL

1.1.1. The Cooperative has a rule exemption from the Arkansas Public Service Commission regarding interest charges to an applicant for service who is a former customer with an unpaid final bill over 90 days old. The Cooperative may charge interest of 10% per annum from the due date of the final bill to the date of application for new service. These charges apply only when the applicant is a former customer with an unpaid final bill over 90 days old. The Arkansas Public Service Commission granted this exemption in Docket No. 83-119-TF.

1.2. DEPOSIT FROM MILITARY PERSONNEL APPLICANT FOR SERVICE

1.2.1. Due to debt collection procedures in place at the base, the Cooperative may waive the deposit for service from military personnel stationed at the Little Rock Air Force Base in Jacksonville, Arkansas.

1.3. EXTENSION AGREEMENT REQUIREMENTS

1.3.1. The Cooperative may offer to enter into an extension agreement with a customer having difficulty paying a bill, in accordance with APSC Rule 6.13.B. The Cooperative is not required to enter into an extension agreement if the customer has failed to keep the terms of an extension agreement in the last twelve months.

1.4. DEPOSIT FROM APPLICANT FOR RESIDENTIAL SERVICE

1.4.1. If any of the conditions in the APSC General Service Rule 4.01.A(2) apply, the Cooperative may waive all or a portion of a deposit based on the applicant’s credit score as returned by a credit scoring service.

1.5. REFUSING SERVICE (AT)

1.5.1. By Order dated August 4,2009, in docket number 09-045-U, the Cooperative received an exemption from GSR 3.04(A)(9) to accept only the following forms of identification when opening an account for an applicant for utility service:

(a) Driver’s license or state-issued ID card; (b) Military ID (c) Passport (d) I-551 card (commonly known as a “green card”); (e) Certified birth certificate; or (f) Any other evidence which would, in the opinion of the utility, establish identity.


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Replacing 9th Revised Sheet No. 7


Kind of Service: Electric Class of Service: Residential

Part III. Rate Schedule No.: 1

Title: SINGLE PHASE RESIDENTIAL, CHURCHES AND SCHOOLS

PSC File Mark Only

1. SINGLE PHASE RESIDENTIAL, CHURCHES AND SCHOOLS

1.1. AVAILABILITY

1.1.1. To all residential customers, churches, and schools within the allocated service areas of theCooperative.

1.2. APPLICATION

1.2.1. To continuous, year-round electric service to a single family residence, an individual apartment, a farmresidence including appurtenant premises, churches and schools.

1.2.2. Services shall be supplied at one point of delivery and measured through one meter; shall be for the exclusive use of the customer; and, shall not be shared with others.

1.2.3. Not applicable to standby or supplementary service.

1.3. TYPE OF SERVICE

1.3.1. Single phase when available, 60 Hertz at a standard delivery voltage of the Cooperative.

1.4. NET MONTHLY RATE

1.4.1. Winter Rate Service Availability Charge @ $25.00 0-500 kWh @ 9.0069¢/kWh Excess kWh @ 7.5069¢/kWh

Summer Rate: Service Availability Charge @ $25.00 All kWh @ 9.0069¢/kWh


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PSC File Mark Only

1.4.2. The Summer Rate will apply to bills mailed during the months of June through October and the Winter Rate will apply to bills mailed during the months of November through May.

1.5. MINIMUM

1.5.1. The minimum monthly charge shall be $28.00 for single phase service plus such other amounts as may be required under line extension policy or other facilities contracts. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.

1.6. SEASONAL SERVICE RATE

1.6.1. Customers requiring service only during certain seasons of the year may be served by one of the following applicable seasonal rates. The applicable seasonal rate shall be determined based on the period of the customer's majority usage. The minimum annual charge shall be $336.00 for single phase service plus such other amounts as may be required under line extension policy or other facilities contracts. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.

1.6.2. Winter Rate Annual Availability Charge @ $300.00 0-6,000 kWh @ 9.0069¢/kWh Excess kWh @ 7.5069¢/kWh

Summer Rate: Annual Availability Charge @ $300.00 All kWh @ 9.0069¢/kWh


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3 Rd Revised Sheet No. 9

Replacing 2nd Revised Sheet No. 9





PSC File Mark Only

RT

1.7. CONDITIONS OF SERVICE

1.7.1. The customer shall be a member of the Cooperative, shall pay the membership fee and be bound by the provisions of the articles of incorporation and bylaws of the Cooperative.

1.7.2. Motors having starting currents in excess of 260 Amperes at 240 Volts shall not be connected to service being rendered under this Schedule unless specifically authorized by the Cooperative.

1.8. CONTRACT PERIOD

1.8.1. Month to month except as otherwise specified in an agreement for electric service.

1.9. SERVICE REGULATIONS

1.9.1. Service under this schedule is subject to these tariffs as they are on file, or may in the future be filed, with the Arkansas Public Service Commission.

1.10. ADJUSTMENTS

1.10.1. Billing under this rate schedule shall be subject to the following riders and adjustments: A. Cost of Energy Adjustment - See Rate Schedule 56. B. Tax Adjustment - See Rate Schedule 64. C. Cost of Debt Adjustment - See Rate Schedule 58. D. Terms of Payment Rider - See Rate Schedule 62.


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Kind of Service: Electric Class of Service: Residential/Commercial


Title: THREE PHASE SERVICE (50 kVA AND UNDER) PSC File Mark Only

2. THREE PHASE SERVICE (50 kVA AND UNDER)

2.1. AVAILABILITY

2.1.1. To all customers within the allocated service areas of the Cooperative.

2.2. APPLICATION

2.2.1. To continuous, year-round electric service to a single family residence, an individual apartment, a farmresidence including appurtenant premises, churches and schools. Also to all electric service required bysmall commercial establishments and public buildings requiring 50 kVA or less installed transformercapacity.

2.2.2. Services shall be supplied at one point of delivery and measured through one meter; shall be for the exclusive use of the customer; and, shall not be resold or shared with others.



2.3.1. Three phase when available, 60 Hertz at a standard delivery voltage of the Cooperative.





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2.5. MINIMUM

2.5.1. The minimum monthly charge shall be $52.50 for three phase service plus such other amounts as may be required under line extension policy or other facilities contracts. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.


2.6.1. Customers requiring service only during certain seasons of the year may be served by one of the following applicable seasonal rates. The applicable seasonal rate shall be determined based on the period of the customer's majority usage. The minimum annual charge shall be $630.00 for three phase service plus such other amounts as may be required under line extension policy or other facilities contracts. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.


Summer Rate: Annual Availability Charge @ $510.00

All kWh @ 10.1999¢/kWh


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3rd Revised Sheet No. 12






RT








2.10. ADJUSTMENTS



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Kind of Service: Electric Class of Service: Commercial


Title: GENERAL SERVICE PSC File Mark Only

4. GENERAL SERVICE

4.1. AVAILABILITY


4.2. APPLICATION

4.2.1. To all electric service required by customers of commercial, industrial and farm service for all uses,including lighting, heating and power, whose load requirements are greater than 50 kVA but less than151 kVA of installed transformer capacity and for which no specific rate schedule is provided. Alsoincludes service to institutional and public buildings. Not applicable to standby, supplementary,temporary breakdown, resale or shared service. Service shall be supplied at one point of delivery andmeasured through one meter.


4.3.1. Single phase or three phase when available, 60 Hertz at a standard delivery voltage of the Cooperative.


4.4.1. Winter Rate Service Availability Charge @ $42.50 All kW Demand @ $11.37/kW All kWh @ 3.6371¢/kWh

Summer Rate: Service Availability Charge @ $42.50 All kW Demand @ $14.37/kW All kWh @ 3.6371¢/kWh


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4.5. MINIMUM MONTHLY CHARGE 4.5.1. The minimum monthly charge shall be the highest one of the following charges as determined for the

customer in question: A. A charge of $1.25 for each kW of the highest monthly demand established during the preceding

12 months ending with the current month plus 3.6371¢ per kWh for the current month's usage.

B. The minimum monthly charge specified in the contract for service.

4.5.2. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.

4.6. DETERMINATION OF BILLING DEMAND

4.6.1. The billing demand shall be the kilowatts, as shown by or computed from, the reading of the Cooperative's demand meter, for the 15 minute period of the customer's greatest use during the month.

4.6.2. If the power factor at the point of measurement is found to be less than 98%, demand measurement may also be made by a kVA demand meter, in which case one kVA as registered will be considered as 0.98 kW, but not less than the actual kW.

4.7. PRIMARY SERVICE 4.7.1. When a customer contracts to take service at a nominal voltage of not less than 13,200/7620 and

provides all the facilities (except metering equipment) necessary to take service at such voltage, the following discounts will apply to the Net Monthly Rate provided in this rate schedule. A. Primary Service and Primary Metering – 4½%. B. Primary Service and Secondary Metering

(Secondary metering at the option of the Cooperative) - 2½%.


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2nd Revised Sheet No. 15

Replacing 1st Revised Sheet No. 15





4.7.2. In the event the Cooperative owns any part of the substation (other than metering equipment) or service

transformers and service is metered, at the option of the Cooperative, at the primary voltage, a discount of 2% will be applied to the Net Monthly Rate provided in this rate schedule.


4.8.1. The customer shall be a member of the Cooperative, shall pay the membership fee and be bound by the provisions of the articles of incorporation and by-laws of the Cooperative.


4.9.1. As set forth in an agreement for electric service.



4.11. ADJUSTMENTS

4.11.1. Billing under this rate schedule shall be subject to the following riders and adjustments:

A. Cost of Energy Adjustment - See Rate Schedule 56.

B. Tax Adjustment - See Rate Schedule 64.

C. Cost of Debt Adjustment - See Rate Schedule 58.

D. Terms of Payment Rider - See Rate Schedule 62.

RT


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Kind of Service: Electric Class of Service: Irrigation


Title: AGRICULTURAL WATER PUMPING SERVICE PSC File Mark Only

5. AGRICULTURAL WATER PUMPING SERVICE

5.1. AVAILABILITY


5.2. APPLICATION

5.2.1. For purposes of crop irrigation, fish-farming, drainage or any combination of these purposes.


5.3.1. Single or three phase when available, 60 Hertz at one standard voltage of the Cooperative.


5.4.1. Winter Rate Service Availability Charge @ $50.00 All kWh @ 11.2314¢/kWh

Summer Rate: Service Availability Charge @ $50.00 Demand Charge @ $7.50 per kW of billing demand 0-342 kWh/kW @ 15.5974¢/kWh Excess kWh @ 11.2314¢/kWh


5.5.1. The billing demand shall be the kilowatts, as shown by or computed from the reading of the Cooperative's demand meter, for the 15 minute period of the customer's greatest use during the month.

5.5.2. If the power factor at the point of measurement is found to be less than 98%, demand measurement may also be made by kVA demand meter, in which case one kVA as registered will be considered as 0.98 kW, but not less than the actual kW.


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5.6. SUMMER SEASON

5.6.1. The Summer Rate will apply to bills mailed during the months of July through October and the Winter Rate will apply to bills mailed during the months of November through June.



5.7.2. Single phase motors having a rated capacity in excess of 7.5 horsepower shall not be connected to service rendered under this schedule unless authorized by the Cooperative.


5.8.1. As specified in an agreement for electric service.



5.10. MONTHLY MINIMUM

5.10.1. The minimum monthly bill for bills mailed during the months of July through October shall not be less than $13.50 per kW of metered demand excluding the customer charge and bill adjustments. Credits allowed per Rate Schedule 11 shall apply against the minimum as defined above.


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5.11. ADJUSTMENTS







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Kind of Service: Electric Class of Service: Lighting


Title: SECURITY LIGHTING SERVICE PSC File Mark Only

8. SECURITY LIGHTING SERVICE8.1. AVAILABILITY


8.2. APPLICATION

8.2.1. To unmetered automatically controlled dusk to dawn outdoor security lighting service. The Cooperative shall install, own, operate and maintain all lamp fixtures. All necessary service, maintenance and lampreplacement will be furnished at the Cooperative's expense within 72 hours after notice is given by thecustomer. Closed rates shall continue to be provided to customers only so long as the Cooperative hasfixtures and repair parts in stock. Once existing inventory has been exhausted, closed rate shall no longer be offered to any customers.


8.3.1. Mercury Vapor (Unshielded) 175 Watt* (75 kWh/month) @ $7.26 250 Watt* (110 kWh/month) @ $9.84 400 Watt* (180 kWh/month) @ $12.78 High Pressure Sodium (Unshielded): 100 Watt* (45 kWh/month) @ $7.26 150 Watt* (65 kWh/month) @ $9.84 250 Watt* (110 kWh/month) @ $12.78 400 Watt* 180 kWh/month) @ $18.52 Metal Halide (Unshielded): 400 Watt (180 kWh/month) @ $18.45

*Lamp fixtures are no longer available for new installation

New LED Lighting (Unshielded): 7000 – 9000 Lumens Security Light (25 kWh/mnth) @ $7.26 20000 – 30000 Lumens Flood Light (85 kWh/mnth) @ $12.78


8.4.1. The customer shall be a member of the Cooperative, shall pay the membership fee and be bound by the provisions of the Articles of Incorporation and By-laws of the Cooperative.

8.4.2. The above charges are applicable to luminaires installed on existing Cooperative poles with a 120 volt source available. The customer shall pay a contribution in aid of construction equal to the cost of all additional facilities if customer requires a security light location other than on an existing Cooperative pole structure. The customer shall protect the lighting unit from damage insofar as he is able to do so.

8.4.3. If customer requires a transformer installation to serve a security light(s) location, customer must pay a contribution in aid of construction for the total installed cost of the transformer unit.


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Title: SECURITY LIGHTING SERVICE PSC File Mark Only

8.5. SHIELDED LIGHTING OPTION

8.5.1. A customer requesting a shielded lighting alternative will pay the monthly rate for the corresponding lamp fixture as listed in paragraph 8.3.1., plus a monthly adder. The monthly adder shall be calculated based upon the incremental cost difference between the shielded and the unshielded lamp recovered over the estimated life of the fixture.


8.6.1. Not less than one year or for such time as set forth in an agreement for lighting service.



8.8. ADJUSTMENTS






8.9. REQUEST FOR REPLACEMENT WITH LED LIGHT

8.9.1. An existing non-LED light will be replaced by the nearest equivalent LED light at no charge to the customer under the following conditions: 1) the existing non-LED light is not operating and 2) the Cooperative does not have in inventory equipment to replace or repair the existing non-LED light.

8.9.2. An existing non-LED light that does not meet the requirements of 8.9.1 will be replaced by an LED light upon request by the customer. In such a case, the customer will pay to the Cooperative a fee of $70 per light plus a trip fee of $45 per trip.

APSC FILED Time: 5/3/2019 3:59:27 PM: Recvd 5/3/2019 3:58:13 PM: Docket 18-076-TF-Doc. 5

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Kind of Service: Electric Class of Service:

Part III. Rate Schedule No.:

Title: PSC File Mark Only

RESERVED FOR FUTURE USE


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Title: OPTIONAL CONTROLLED AGRICULTURAL WATER PUMPING (5 HR. CONTROL) PSC File Mark Only

11. OPTIONAL CONTROLLED AGRICULTURAL WATER PUMPING (5 HR. CONTROL)

11.1. AVAILABILITY

11.1.1. To all customers receiving service under Agricultural Water Pumping Service Rate Schedule 5.

11.2. APPLICATION

11.2.1. To any customer receiving service under Agricultural Water Pumping Service Rate Schedule 5 who permits the Cooperative to control their pumping load during periods of the Cooperative's peak load conditions.

11.3. CREDIT

11.3.1. The customer will receive a credit per kWh of energy used per month during the summer season.

11.3.2. Interruptible Credit @ 6.0000¢/kWh

11.4. SUMMER SEASON

11.4.1. The summer season shall be bills mailed during the months of July through October.


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Title:

OPTIONAL CONTROLLED AGRICULTURAL WATER PUMPING (5 HR. CONTROL) PSC File Mark Only

11.5. TIME OF CONTROL

11.5.1. The daily control period shall be up to a maximum of 5 hours per day, between the hours of 2:30 p.m. and 8:30 p.m. Load will be controlled when system characteristics indicate a peaking situation is likely to occur during the months of June through September.

11.6. OTHER PROVISIONS

11.6.1. Cooperative will furnish and install required load control devices and customer will furnish and install required starters and other necessary devices for the proper operation of customer's equipment under this rate.

11.6.2. The Cooperative shall be responsible for the repair and maintenance of the load control device only and shall not be responsible in any way for the repair and maintenance of the customer's pumping unit.

11.6.3. If there is evidence of alteration or tampering with the Cooperative's control unit, the customer shall reimburse Cooperative for the cost of replacement or repair of the control unit and the customer shall receive no credit on his final billing for the installation of the control. The customer's total annual billing shall be calculated under the non-controlled Agricultural Water Pumping Service Rate Schedule 5.

11.6.4. If the customer shall request that the Cooperative remove or override the load control device at any time during the irrigation season, the customer shall receive no credit on his final billing for the installation of the control. The customer's total annual billing shall be calculated under the non-controlled Agricultural Water Pumping Service Rate Schedule 5.

11.6.5. Availability of 5 hour switches and therefore credit rate may be limited.



CT


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Title: ATHLETIC FIELD LIGHTING PSC File Mark Only

12. ATHLETIC FIELD LIGHTING

12.1. AVAILABILITY


12.2. APPLICATION

12.2.1. To all electric service required on the premises for baseball fields, football fields, riding arenas and other outdoor athletic or sports areas of a similar nature.

12.2.2. Service shall be supplied through one meter; shall be for the exclusive use of the customer; and shall not be resold or shared with others.



12.3.1. Single or three-phase when available, 60 Hertz at one standard delivery voltage of the Cooperative.


12.4.1. Service Availability Charge @ $35.00 All kW @ $1.68/kW All kWh @ 4.6364¢/kWh

12.5. MINIMUM

12.5.1. The minimum monthly charge shall be the service availability charge. The minimum monthly charge shall apply only in periods with consumption or such periods of time as may be set forth in an agreement for electric service. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.


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Title: ATHLETIC FIELD LIGHTING PSC File Mark Only


12.6.1. The billing demand shall be the kilowatts, as shown by or computed from, the reading of the Cooperative's demand meter, for the 15 minute period of the customer's greatest use during the billing period.

CT


12.7.1. The customer shall be a member of the Cooperative, shall pay the membership fee and be bound by the provisions of the Articles of Incorporation and By-laws of the Cooperative.

12.7.2. Service being provided under this schedule shall be disconnected during seasons or periods of time the service is not in regular use by the customer.





12.10. ADJUSTMENTS






RT


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Kind of Service: Electric Class of Service: Commercial/Industrial


Title: LARGE GENERAL SERVICE PSC File Mark Only

13. LARGE GENERAL SERVICE

13.1. AVAILABILITY


13.2. APPLICATION

13.2.1. To customers of commercial, industrial and farm service for all uses, including lighting, heating and power, whose load requirements exceed 150 kVA of installed transformer capacity and for which no specific rate schedule is provided. Also includes service to institutional and public buildings.

13.2.2. Not applicable to standby, supplementary, temporary breakdown, resale or shared service. Service shall be supplied at one point of delivery and measured through one meter.


13.3.1. Single or three-phase when available, 60 Hertz at one standard delivery voltage of the Cooperative.


13.4.1. Winter Rate Service Availability Charge @ $85.00 All kW @ $13.23/kW All kWh @ 3.7878¢/kWh

Summer Rate: Service Availability Charge @ $85.00 All kW @ $15.48/kW All kWh @ 3.7878¢/kWh



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13.5. MINIMUM MONTHLY CHARGE

13.5.1. The minimum monthly charge shall be the highest one of the following charges as determined for the customer in question: A. A charge of $1.25 for each kW of the highest monthly demand established during the

preceding 12 months ending with the current month plus 3.7878¢ per kWh for the current month's usage. B. The minimum monthly charge specified in the contract for service.



13.6.1. The billing demand shall be the kilowatts, as shown by or computed from, the reading of the Cooperative's demand meter, for the 15 minute period of the customer's greatest use during the month.

13.6.2. If the power factor at the point of measurement is found to be less than 98%, demand measurement may also be made by a kVA demand meter, in which case one kVA as registered will be considered as 0.98 kW, but not less than the actual kW.

13.7. PRIMARY SERVICE

13.7.1. When a customer contracts to take service at a nominal voltage of not less than 13,200/7620 and provides all the facilities (except metering equipment) necessary to take service at such voltage, the following discounts will apply to the Net Monthly Rate provided in this rate schedule.

A. Primary Service and Primary Metering - 4½%. B. Primary Service and Secondary Metering

(Secondary metering at the option of the Cooperative) - 2½%.


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13.7.2. In the event the Cooperative owns any part of the substation (other than metering

equipment) or service transformers and service is metered, at the option of the Cooperative, at the primary voltage, a discount of 2% will be applied to the Net Monthly Rate provided in this rate schedule.

MT




13.9.1. As set forth in an agreement for electric service.



13.11. ADJUSTMENTS







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Title: CUSTOMER MANAGED INTERRUPTIBLE CREDIT PSC File Mark Only

14. CUSTOMER MANAGED INTERRUPTIBLE CREDIT

14.1. AVAILABILITY

14.1.1. This optional interruptible credit is available to customers receiving service under Rate Schedule 13 (Large General Service) and having characteristics suitable for customer managed interruptible service.

14.2. INTERRUPTIBLE CREDIT

14.2.1. Provided that customer modifies his or her operation to minimize use during peak periods, customer shall receive an interruptible credit each month based on the customer's monthly Billing Demand as defined in Schedule 13 less the Peak Demand as defined herein. (Where Peak Demand exceeds Billing Demand, there will be no interruptible credit.) Said credit shall not exceed 50% of customer's cumulative bill (as calculated per Rate Schedule 13) for the period before the application of the credit.

14.2.2. Interruptible Credit @ $7.35/kW

14.2.3. Peak demand shall be defined as the average of the maximum four monthly "Peak Period" demands measured by a demand meter and occurring during the most recent months of June, July, August and September. Peak demand shall be calculated as follows: Peak Demand = JPPD + JIPPD + APPD + SPPD 4 where JPPD, JIPPD, APPD and SPPD equal June, July, August and September peak period demands.


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Title: CUSTOMER MANAGED INTERRUPTIBLE CREDIT PSC File Mark Only

14.2.4. "Peak Periods" used in recording peak demands shall be the hours of 3:00 p.m. to 8:00 p.m. on days

in which the temperature equals or exceeds 93°F. Temperature of record shall be that as reported by the National Oceanic and Atmospheric Administration for the Little Rock reporting station. Peak period demand will be the maximum demand occurring during peak periods during the month. The Cooperative may allow customer to operate within defined peak periods during given days without addition to Peak Demand if it is clear to operating personnel of the Cooperative that a wholesale peak will not occur during the period. In order for this to take place, the designated operating personnel of the customer must call the designated load management supervisor (LMS) of the Cooperative requesting waiver of the defined peak period for the day. If it is clear to the LMS that a peak will not occur, then he will notify customer that it is permissible to operate during that day. Permission will be provided by phone and then by electronic notification as a confirmation of the waiver.

14.2.5. Customer shall reimburse Cooperative for all costs involved in special metering required for providing the interruptible credit. This includes investment incurred for special metering at the installation plus monthly interpretation expenses associated with the special metering.

14.2.6. Where customer does not have a 4 month peak period history available, then the peak demand will be calculated by dividing the sum of historic peak months available by the actual number of months available.

14.2.7. The commencement date of this schedule for new customers will be June 1 of any given year.


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Title:

LOAD MANAGEMENT CONTROL – LARGE GENERAL SERVICE

PSC File Mark Only 15. LOAD MANAGEMENT CONTROL – LARGE GENERAL SERVICE

15.1. AVAILABILITY

15.1.1. This is an optional schedule available to any customer receiving service under Rate Schedule 13 and agreeing to let the Cooperative interrupt service for periods defined herein, upon installation of the appropriate equipment and facilities by the Cooperative and the customer. Cooperative will provide 30 minutes notice prior to interruptions.

15.2. CREDIT


15.2.2. The credit shall not exceed 50% of the customer's cumulative bill (as calculated per Rate Schedule 13) for the period before the application of the credit. Said credit shall be applied at the end of the period.


15.3.1. The Cooperative shall have the right to interrupt service from 2:30 p.m. to 8:30 p.m. for the period of June 1 to September 30, or during system emergency conditions which may occur any time of the year.

15.3.2. It is the responsibility of the customer to maintain his operation in a state of readiness so that service may be interrupted given 30 minutes advance notice. Notice will not be provided prior to re-energization.

15.3.3. Customer shall install, own and maintain equipment to be used in disconnecting the service during peak periods. Said equipment shall be of an automatic nature and capable of being controlled by Cooperative's contact device. Said equipment shall be acceptable to the Cooperative.


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Title:

LOAD MANAGEMENT CONTROL – LARGE GENERAL SERVICE

PSC File Mark Only 15.3.4. Customer will provide adequate phone or communication facilities to receive notice. Customer will designate

and have available authorized individuals that will receive notice.

15.3.5. The Cooperative will not be responsible for repair or maintenance of customer's equipment or losses which occur due to the fact that customer was not prepared to be interrupted.

15.3.6. If there is evidence of alteration or tampering with Cooperative's control unit or customer's main disconnect device, customer will reimburse Cooperative for the cost of replacement or repair of the control unit plus the credit extended customer. Cooperative may cancel agreement and remove its control unit under these conditions.

15.3.7. Customer shall reimburse Cooperative for all costs involved in special metering required for providing the interruptible credit. This includes investment incurred for special metering at the installation plus monthly interpretation expenses associated with the special metering.

15.3.8. The commencement date of this schedule for new customers will be June 1 of any given year.


15.4.1. Not less than one year.


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Kind of Service: Electric Class of Service: Industrial


Title: INDUSTRIAL POWER SERVICE – OPTIONAL INTERRUPTIBLE PSC File Mark Only

16. INDUSTRIAL POWER SERVICE – OPTIONAL INTERRUPTIBLE

16.1. AVAILABILITY

16.1.1. To all customers within the allocated service areas of the Cooperative that qualify for the Interruptible Credit Rider (IC) as described in the rates of Arkansas Electric Corporation (AECC).

16.2. APPLICATION

16.2.1. To large industrial customers whose load requirements equal or exceed 5,000 kW where customer has agreed to interrupt all or a portion of his electrical load at any time upon demand by the Cooperative with at least three hours advance verbal or electronic notice. Interruptions shall be as called for by AECC, First Electric's wholesale power supplier.

16.2.2. Not applicable to standby, supplementary, temporary breakdown, resale or shared service unless negotiated at time of contract.


16.3.1. Three phase, 60 Hertz at standard primary voltage.


16.4.1. Service Availability Charge @ $200.00 All kW Demand @ $11.27/kW All kWh @ 3.1132¢/kWh


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Title: INDUSTRIAL POWER SERVICE – OPTIONAL INTERRUPTIBLE PSC File Mark Only

16.5. INTERRUPTIBLE CREDIT

16.5.1. The customer will receive a credit as compensation for availability of interrupted load.


16.6. CURRENT MONTH KW DEMAND

16.6.1. The Current Month kW Demand shall be the highest one hour kW demand occurring in the current month.

16.7. BILLING KW DEMAND

16.7.1. The Billing kW Demand shall be the average of the Current Month kW Demands occurring in the current month and preceding eleven (11) months.

16.7.2. If the customer has not established twelve consecutive months of Current Month kW Demand, the Billing kW Demand shall be the average of the customer's Current Month kW Demands until such time that twelve months of Current Month kW Demands have been established.

16.8. MINIMUM MONTHLY CHARGE

16.8.1. The monthly minimum shall be the charges computed under the Net Monthly Rate but not less than $11.27 per kW of Billing Demand, less the Interruptible Credit as defined above. Should customer elect to disconnect service, customer shall pay as part of the final bill the cost of ratcheted wholesale demand charges due to the customer which the Cooperative will have to pay its supplier during the following 11 months.



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Title:

INDUSTRIAL POWER SERVICE – OPTIONAL INTERRUPTIBLE PSC File Mark Only

16.9. WHOLESALE POWER CHANGES

16.9.1. The rate herein shall be modified an equivalent amount when the cost of wholesale power the Cooperative purchases from its supplier is modified.

16.10. TERM OF SCHEDULE

16.10.1. This schedule shall take effect when Cooperative's wholesale power supplier implements its Interruptible Credit Rider (IC) for the customer.

CT


16.11.1. The customer shall be a member of the Cooperative, shall pay the membership fees and be bound by the provisions of the articles of incorporation and by-laws of the Cooperative.

16.11.2. The Cooperative may designate AECC as the entity responsible for requesting the interruption from the customer and to directly contact the customer regarding any of the provisions and requirements of this rate schedule.

AT

16.11.3. So long as the customer maintains at least 5,000 kW of interruptible load, the customer may designate, with proper notice, additional portions of its load as firm. In the event that a portion of the customer's load Is designated as firm, all Billing Demand (both firm and interruptible) shall be determined under the definitions set forth herein in paragraph 16.7. For that portion of load that has been designated as firm load, the customer shall not receive an interruptible credit and the load designated as firm shall not be subject to interruption.


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Title:


16.11.4. Service may be interrupted in any calendar year up to the number of hours stated in AECC's

Interruptible Credit Rider, when, in AECC's sole judgment, such interruptions may prevent the interruption of service to other customers. Service may be interrupted by AECC for up to fifty percent (50%) of the number of hours stated in AECC's Interruptible Credit Rider for any reason. This provision does not impair or limit AECC and the Cooperative's right to interrupt service in the case of system emergency. Hours interrupted due to system emergency shall not be included in the number of interruptible hours available for interruption.

RT, MT

16.11.5. The Cooperative will make interruptible service available to the customer based on availability of said service from its wholesale power supplier (AECC). The quantity of interruptible service is made up of blocks of power as designated for this purpose by the Cooperative's wholesale power supplier (AECC). Said blocks have different Maximum Annual Interruption Periods. The chart shown in AECC's Interruptible Credit Rider includes the Block Number designation, the Load Limit available in the Block, and the Maximum Annual Interruption permitted within the Block as provided for by the Cooperative's wholesale power supplier (AECC). The Load Limits that are permitted within each Block equal the composite total as permitted from all consumers of Member Cooperatives served by AECC, and not the amount that is assigned to the individual customer. Nothing in this rate obligates the Cooperative or its wholesale power supplier (AECC) to purchase or maintain capacity or reserves in excess of those required to serve AECC's firm load.

CT

16.11.6. Service may be interrupted by Cooperative up to the number of hours stated in the Interruption Blocks, as shown in AECC's Interruptible Credit Rider. Each Interruption Block has maximum kW load limits, so service under any particular block is subject to availability.

CT


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16.11.7. If the customer’s electrical demand is 40,000 kW or less, then the customer must provide at

least one year's advance written notice to the Cooperative and its wholesale power supplier (AECC) of its intent to discontinue interruptible service under this rate schedule and convert to firm service. If the customer's electrical demand is over 40,000 kW, then the customer shall provide at least three year's advance written notice to the Cooperative and AECC to discontinue interruptible service and convert to firm service. Should capacity be available, a shorter time frame for converting to firm service may be approved by AECC's Board of Directors.

CT

RT

16.12. FAILURE TO INTERRUPT AT LOCATIONS WHERE COOPERATIVE CAN PHYSICALLY INTERRUPT THE LOAD

16.12.1. If, having received at least three hours advance verbal or electronic notice of a request to interrupt, the customer fails to interrupt, the Cooperative shall interrupt the customer's load.

16.13. FAILURE TO INTERRUPT AT LOCATIONS WHERE COOPERATIVE CANNOT PHYSICALLY INTERRUPT THE LOAD

16.13.1. If, having received at least three hours advance verbal or electronic notice of a request to interrupt, the customer fails to interrupt, then a customer with load of 40,000 kW or less shall continue to be subject to interruption for one year following their failure to interrupt. If customer's load is greater than 40,000 kW, the customer shall continue to be subject to interruption for three years following their failure to interrupt. In the event that the customer fails to interrupt, the customer shall no longer receive an Interruptible Credit. Upon completion of the above stated terms, the customer will no longer be eligible for AECC's IC rate and shall no longer be subject to interruption.


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Title:


16.14. SUPPLEMENTAL SERVICE

AT

16.14.1. During periods when service would normally be interrupted, the Cooperative, through its wholesale power supplier (AECC) will make a good faith effort to continue service by making available to the customer capacity and associated energy purchased by AECC from other power suppliers when such capacity and associated energy is reasonably available to AECC. AECC will exercise sole judgment as to the availability, quantity, and source of this supplemental service. The Cooperative and the customer shall have no control of AECC's judgment or recourse from it.

16.14.2. The customer shall have the right to accept or reject this supplemental service at each time an interruption under normal service is called for by the Cooperative. At each time the Cooperative notifies the customer that normal service will be interrupted, the Cooperative will also notify the customer whether or not supplemental service is available. If supplemental service is available, the hourly MWh amounts to be supplied as supplemental service and the price per MWh to the customer for such supplemental service shall be quoted by the Cooperative. Within 15 minutes of notification of the availability of supplemental service, the customer shall notify the Cooperative whether it chooses to interrupt or accept supplemental service.

16.14.3. Failure of the customer to notify the Cooperative of a decision to interrupt or accept supplemental service within said 15 minute period shall be deemed an election to interrupt. If supplemental service is accepted by the customer, AECC may notify directly the customer of an interruption in supplemental service. The customer must interrupt such supplemental service within 5 minutes of the time such notice is given. Provisions of this supplemental service shall be subject to the criteria of the Regional Reliability Council of which AECC is a member.

16.15. SUPPLEMENTAL SERVICE CHARGE

16.15.1. When the customer chooses to accept supplemental service, the customer will be charged the price quoted by the Cooperative and accepted by the customer for such service. Such quoted price to the customer will be AECC's expected total charge to the Cooperative for providing supplemental service plus an adder equal to 10% of such expected total charge not to exceed five dollars ($5.00) per MWh.


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Title:


16.16. CONTRACT CONFORMANCE WITH AECC’s INTERRUPTIBLE CREDIT RIDER

16.16.1. If any contract or tariff provision conflicts with AECC’s Interruptible Credit Rider, the AECC tariff provisions shall govern.

16.17. POINT OF MEASUREMENT AND METERING

16.17.1. The delivery point shall be the point that the Cooperative’s wholesale power supplier delivers service in conformance with its interruptible schedule. A separate metering point will be established for each point where interruptible service is provided.


16.18.1. As set forth in agreement for electric service.


16.19.1. Service under this schedule is subject to these tariffs as they are on file, or may in the future be filed, with the Arkansas Public Services Commission.

16.20. LIABILITY OF AECC AND THE COOPERATIVE

16.20.1. It is understood that the interruption portion of this rate is provided to the customer to allow the customer added flexibility in controlling load and costs. Neither the Cooperative nor AECC will be held liable for losses or damages which may accrue to the customer as a result of interruptions under the provisions of this rate schedule.

16.21. ADJUSTMENTS

16.21.1. Billing under this rate schedule shall be subject to the following riders and adjustments: A. Cost of Energy Adjustment - See Rate Schedule 56. B. Tax Adjustment - See Rate Schedule 64. C. Cost of Debt Adjustment - See Rate Schedule 58. D. Terms of Payment Rider - See Rate Schedule 62. E. Power Factor Adjustment Rider - See Rate Schedule 60. F. Voltage Fluctuations and Harmonic Distortion Rider - See Rate Schedule 61.

AT AT


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AT




First Electric Cooperative Corporation

Name of Company



Title:

PSC File Mark Only



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Title:

Prepaid Electric Service PSC File Mark Only 20. PREPAID ELECTRIC SERVICE

20.1. AVAILABILITY

20.1.1 Available to Residential customers who receive single-phase service under Rate Schedule 1 where the Cooperative has the capability to install or has already installed a remote disconnect collar that permits Prepaid metering. The Prepaid Electric Service Program will be offered on a strictly voluntary basis upon election by an eligible Customer desiring to participate in the program.

20.1.2 Customers applying for or receiving service as a landlord as defined in APSC General Service Rule 6.19 are not eligible for the Prepaid Electric Service Program

(AT)

20.2. APPLICATION

20.2.1 Any eligible new or existing Customer may request participation in the Prepaid program where the Cooperative has the capability to offer Prepaid metering.

20.2.2 Excluding deposits related to meter tampering, a new customer requesting the Prepaid program will not be required to pay a security deposit.

(CT)

20.2.3 Any accrued security deposit on an existing Customer’s account at the time of entry to the Prepaid program, excluding deposits related to meter tampering, will be applied to the Customer’s account balance, and any remainder will be refunded or used to purchase energy, at the Customer’s preference.

20.2.4 Any balance remaining after application of any billed and/or paid security deposit will be paid with 50% of

Customer’s future purchase power payments until the remaining balance is paid in full. (CT)

20.2.5 A Prepaid credit balance of $20.00 will be required to begin Prepaid service. (CT)

20.2.6 A reconnection fee will not be assessed to Customers participating in the Prepaid Electric Service Program when service is stopped due to a lack of prepayment and then reinstated after purchase is made.

20.2.7 Customers taking standard service who have been disconnected for non-payment and elect to reconnect under the Prepaid Electric Service Program will not be assessed a reconnection fee.


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1st Revised Sheet No. 45.1

Replacing Original Sheet No. 45.1




Title:

Prepaid Electric Service PSC File Mark Only

20.3 PROVISIONS

20.3.1 Power may be purchased at any time in any increments equal to or exceeding a $20.00 minimum purchase amount. Customers may purchase power by internet, telephone, payment kiosk, or during normal business hours at any Cooperative office.

20.3.2 Standard provisions of the Cold Weather rule and Elderly and Individuals with Disabilities rules are applicable under this service.

20.3.3 Medical certification will be honored per the provisions of APSC General Service Rules – Rule 6.17 (CT)

20.3.4 Customers must maintain a credit balance to avoid disconnection. Balance will be calculated daily.

20.3.5 Customers will not receive a paper bill.

20.3.6 The Cooperative will monitor usage of participating Prepaid customers and send purchase requirement notifications when their credit balance drops below $15.00, unless modified by the Customer. Participating customers can choose to receive purchase requirement notifications by electronic mail, text message or phone calls (or a combination of the three options). All notifications will be generated from the automated system.

20.3.7 Credits on an active Prepaid account may not be refunded or transferred to another account until the Prepaid account is closed or the customer withdraws from the program.

(AT)

20.3.8 Prepaid accounts may qualify for a Prepaid arrangement. Accounts may only enter into one arrangement at a time and arrangements may not be altered. A Prepaid arrangement will be paid with 50% of Customer’s future power payments until the arrangement balance is paid in full. Qualifications for a Prepaid arrangement are listed below:

A. Enrollment in Prepaid with any balance remaining from a standard service account after application of any billed and/or paid security deposits.

B. A balance transferred from an inactive account to a Prepaid account. C. A Prepaid balance due upon expiration of a Physician Statement.

(AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT)

20.4 PREPAID ELECTRIC SERVICE PROGRAM WITHDRAWAL (AT)

20.4.1 Customers may choose to withdraw from the Prepaid Electric Service Program at any time. Upon withdrawal, Customer must pay in full any Prepaid balance in addition to any arrangement balance that is owed.

(AT) (AT)


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Original Sheet No. 45.2





Title:

Prepaid Electric Service PSC File Mark Only

20.4 PREPAID ELECTRIC SERVICE PROGRAM WITHDRAWAL (Continued) (AT)

20.4.2 Deposits will be reviewed as follows to continue service upon withdrawal from the Prepaid Electric Service Program:

A. If the account was an existing active non-Prepaid account at time of Prepaid enrollment and remained on Prepaid for 12 consecutive months, a credit scoring service will be used to determine if a deposit is required. If a deposit is required, one half of the deposit is due immediately upon withdrawal from the program and the remaining one half of the deposit will be billed on the first billing after withdrawal.

B. If the account was originally connected as a Prepaid account, a credit scoring service will be used to determine if a deposit is required. If a deposit is required, one half of the deposit is due immediately upon withdrawal from the program and the remaining one half of the deposit will be billed on the first billing after withdrawal.

C. If the account was an existing active non-Prepaid account at time of Prepaid enrollment and remained on Prepaid for LESS THAN 12 consecutive months, any deposit refunded at the time of Prepaid enrollment will be reinstated and must be paid in full immediately upon withdrawal from the program.

(AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT)

20.5 OTHER PROVISIONS (MT)

20.5.1 Except as modified herein, all provisions of Rate Schedule 1 shall apply (MT)


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Title: LOAD CONTROL OF AIR CONDITIONING PSC File Mark Only

21. LOAD CONTROL OF AIR CONDITIONING

21.1. AVAILABILITY

21.1.1. Available to any customer receiving service under Rate Schedules 1, 51 or 2 having a central air conditioning system with a connected compressor load of at least 2 kVA upon installation of the appropriate equipment and facilities.

21.2. APPLICATION

21.2.1. Applicable to any customer receiving service under Rate Schedules 1, 51 or 2 and having a central air conditioning system with a connected compressor load of 2 kVA or more and agreeing to permit Cooperative to install a control device so that Cooperative can control the operation of the air conditioning compressor during periods of Cooperative's peak load conditions and during emergency conditions.

21.3. CREDIT

21.3.1. The customer will receive a credit per kVA of connected compressor capacity controlled for the period of June to September. The credit will be applied to bills mailed during the months of July through October. Said credit shall not apply to installations using under 500 kWh during the month and shall not exceed 20% of the monthly energy charge before the application of the credit.

21.3.2. A/C Credit @ $1.43 / kVA

21.3.3. For the credit, the Cooperative shall have the right to interrupt service to the compressor unit for approximately 30 minutes per hour during peak load conditions from June through September.


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Title: LOAD CONTROL OF AIR CONDITIONING PSC File Mark Only




21.5.1. It is the responsibility of the customer to maintain his air conditioning unit and to keep his unit in good repair and working order.

21.5.2. The Cooperative shall not be responsible for repair or maintenance on the customer's air conditioning unit. The Cooperative shall be responsible for the repair and maintenance of the control unit.

21.5.3. If there is evidence of alteration or tampering with Cooperative's control unit, customer will reimburse Cooperative for the cost of replacement or repair of the control unit plus the credit extended the customer. Cooperative may cancel agreement and remove its control unit under these conditions.

21.5.4. When customer is receiving both water heater and air conditioner credits, the total credit amount allowed will be limited to 20% of the energy charge before application of credits.

21.5.5. The load management program is experimental and subject to future modification.


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Title: LOAD CONTROL OF WATER HEATERS PSC File Mark Only

22. LOAD CONTROL OF WATER HEATERS

22.1. AVAILABILITY

22.1.1. Available to any customer receiving service under Rate Schedules 1, 51, 2 or 4 having an electric water heater of 4 kW or larger upon installation of the appropriate equipment and facilities.

22.2. APPLICATION

22.2.1. Applicable to any customer receiving service under Rate Schedules 1, 51, 2 or 4 having an electric water heater of 4 kW or larger, and agreeing to permit Cooperative to install a control device so that Cooperative can control the operation of the water heater during periods of Cooperative's peak load conditions and during emergency conditions.

22.3. CREDIT

22.3.1. The customer will receive a credit per water heater controlled for the period of June to September. The credit will be applied to bills mailed during the months of July through October. Said credit shall not apply to installations using under 500 kWh during the month and shall not exceed 20% of the monthly energy charge for the period before the application of the credit.

22.3.2. Water Heater Credit @ $6.18 / unit


22.4.1. The Cooperative shall have the right to interrupt service to the water heater for a 4 hour period during the hours of 2:30 p.m. through 8:30 p.m. Said interruptions shall occur during peak load conditions from June through September or during emergency conditions which may occur during any time of the year.


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Title: LOAD CONTROL OF WATER HEATERS PSC File Mark Only

22.4.2. It is the responsibility of the customer to maintain his water heater and to keep his unit in good repair and working

order.

22.4.3. The Cooperative shall not be responsible for repair or maintenance of the customer's water heater. The Cooperative shall be responsible for the repair and maintenance of the control unit.

22.4.4. If there is evidence of alteration or tampering with Cooperative's control unit, customer will reimburse Cooperative for the cost of replacement or repair of the control unit plus the credit extended the customer. Cooperative may cancel agreement and remove its control unit under these conditions.

22.4.5. When customer is receiving both water heater and air conditioner credits, the total credit amount allowed will be limited to 20% of the energy charge before application of credits.

22.4.6. The load management program is experimental and subject to future modification.

22.5. CONTRACT



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Replacing Original Sheet No.


Kind of Service: Electric Class of Service: Single Phase


Title:

TRANSIENT VOLTAGE SURGE SUPPRESSION SERVICE - CLOSED PSC File Mark Only

23. TRANSIENT VOLTAGE SURGE SUPPRESSION SERVICE – CLOSED

23.1. DESCRIPTION OF SERVICE

23.1.1. For existing customers only. Service is non-transferable to new customers at existing locations or new locations for existing customers. Service available only as long as the Cooperative’s existing transient voltage surge suppression device stock with manufacturer’s warranty lasts. Transient Voltage Surge Suppression Service is intended to reduce the magnitude of surges entering the location from the Cooperative’s distribution system.

CT

23.2. AVAILABILITY

23.2.1. Transient Voltage Surge Suppression Service is an optional enhanced service available upon request of the customer. Service is limited to single-phase customers.

23.3. PROGRAM

23.3.1 Closed CT

23.4. FEE FOR SERVICE

23.4.1 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: $5.00/month for one meter socket protector. Ownership of the meter socket protector will remain with the Cooperative.

Purchase Option None – closed to new customers. CT


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Kind of Service: Electric Class of Service: Single Phase


Title:

TRANSIENT VOLTAGE SURGE SUPPRESSION SERVICE - CLOSED PSC File Mark Only

23.5. LIMITATIONS OF SERVICE

23.5.1. Transient voltage surges are part of any electrical, telephone, or cable TV 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. The Cooperative, by providing equipment listed herein, is not implying or guaranteeing the customer’s electrical equipment will not be damaged in the future by transient voltage surges. The Cooperative’s only responsibility herein is provision and installation of equipment.

23.6. AGREEMENT FOR SERVICE

23.6.1. Closed to new service. CT

23.7. TERM

23.7.1. Service may be discontinued at any time at the request of the customer. CT


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Title: SINGLE PHASE COMMERCIAL (50 kVA AND UNDER) PSC File Mark Only

51. SINGLE PHASE COMMERCIAL (50 kVA AND UNDER)

51.1. AVAILABILITY


51.2. APPLICATION

51.2.1. To all electric service required by small commercial establishments and public buildings requiring 50 kVA or less installed transformer capacity.

51.2.2. Services shall be supplied at one point of delivery and measured through one meter; shall be for the exclusive use of the customer; and, shall not be shared with others.



51.3.1. Single phase when available, 60 Hertz at a standard delivery voltage of the Cooperative.





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Title: SINGLE PHASE COMMERCIAL (50 kVA AND UNDER) PSC File Mark Only


51.5. MINIMUM

51.5.1. The minimum monthly charge shall be $28.00 for single phase service plus such other amounts as may be required under line extension policy or other facilities contracts. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.


51.6.1. Customers requiring service only during certain seasons of the year may be served by one of the following applicable seasonal rates. The applicable seasonal rate shall be determined based on the period of the customer’s majority usage. The minimum annual charge shall be $336.00 for single phase service plus such other amounts as may be required under line extension policy or other facilities contracts. All applicable monthly billing adjustments shall be applied in addition to the minimum bill charges.


Summer Rate: Annual Availability Charge @ $300.00 All kWh @ 9.0069¢/kWh


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Title:

SINGLE PHASE COMMERCIAL (50 kVA AND UNDER) PSC File Mark Only

RT








51.10. ADJUSTMENTS



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Title: MUNICIPAL STREET LIGHTING SERVICE PSC File Mark Only

54. MUNICIPAL STREET LIGHTING SERVICE

54.1. AVAILABILITY

54.1.1. To any municipality or Property Owner Association (POA) within the allocated service area of the Cooperative.

54.2. APPLICATION

54.2.1. To lighting service required by the municipality or POA for streets, alleys and other public ways. Not applicable to temporary, resale, shared or seasonal service. Closed rates shall continue to be provided to customers only so long as the Cooperative has fixtures and repair parts in stock. Once existing inventory has been exhausted, closed rate shall no longer be offered to any customers.

54.3. CHARACTER OF SERVICE

54.3.1. Lighting service under this schedule will be furnished from dusk until dawn. The service voltage and type of service, series of multiple, will be at the Cooperative's option.


54.4.1. Cooperative Owned Facilities

The following net monthly rate is applicable when the Cooperative owns the entire street lighting facility, consisting of the Cooperative's standard luminaire fixture on a wood pole, overhead circuits, controls and all other related equipment. Cooperative will operate and maintain such facility at its expense, except that municipality will reimburse Cooperative for the cost of material required for replacing broken outer globes and for the total cost of replacing or repairing broken or damaged poles used primarily for street lighting.

54.4.1.A. Mercury Vapor Light (Unshielded) 100 Watt* (45 kWh/month) @ $5.57 175 Watt* (75 kWh/month) @ $6.78 250 Watt* (110 kWh/month) @ $9.44 400 Watt* (180 kWh/month) @ $12.70

High Pressure Sodium Lighting (Unshielded) 100 Watt* (45 kwh/month) @ $6.78 150 Watt* (65 kWh/month) @ $9.44 250 Watt* (110 kWh/month) @ $12.70 400 Watt* (180 kWh/month) @ $16.66

* Lamps no longer available for new installations

(CONTINUED ON NEXT PAGE)


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LED Lighting (Unshielded) 7000 – 9000 Lumens Security (25 kWh/month) @ $6.78 7000 – 9000 Lumens Street (30 kwh/month) @ $9.44 5000 – 9000 Lumens Decorative (30 kWh/month) @ $9.44 20000 – 30000 Lumens Flood (85 kWh/month) @ $12.70

54.4.1.B Ornamental Poles. Available to all new and existing installations.

1) Additional monthly charges will be made for each of the Cooperative's standard ornamental poles as follows:

For Poles of 30 Feet or Less Mounting Height ........................$1.25 per pole For Poles of 35 Feet Mounting Height .....................................$2.00 per pole

2) Not applicable when a nonrefundable contribution in aid of construction is made to cover the additional installed cost of ornamental poles.

54.4.1.C Shielded Lighting Option

A municipality requesting a shielded lighting alternative will pay the monthly rate for the corresponding lamp fixture as listed in paragraph 54.4.1.A., plus a monthly adder. The monthly adder shall be calculated based upon the incremental cost difference between the shielded and the unshielded lamp recovered over the estimated life of the fixture.

54.4.1.D Underground and Other Nonstandard Facilities. Available to all new and existing installations.

When the Cooperative provides underground circuits or any equipment other than the Cooperative's standard equipment for overhead facilities, there will be an additional monthly charge equal to 1.5% of the cost of such facilities in excess of the cost of standard overhead facilities.

54.4.2. Municipally or Property Owner Association (POA) Owned Facilities

The following net monthly rate is applicable when the municipality/POA owns the entire street lighting facility, including the luminaire, pole, circuit, controls and all other related equipment on the load side of the Cooperative's point of delivery; or when such facility is provided by any other public agency and municipality is obligated to operate and maintain such facility*. Cooperative will operate and maintain such facilities and municipality/POA will reimburse Cooperative for cost of all maintenance material, except lamp replacements. Municipality/POA will reimburse Cooperative for total cost of replacing or repairing broken or damaged poles.

Incandescent or MVL 100 Watt* (45 kWh/month) @ $3.99 175 Watt* (75 kWh/month) @ $5.00 400 Watt* (180 kWh/month) @ $9.71


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High Pressure Sodium Lighting 100 Watt* (45 kWh/month) @ $5.00 150 Watt* (65 kWh/month) @ $6.91 250 Watt* 110 kWh/month) @ $9.71 400 Watt* (180 kWh/month) @ $13.20

* Lamp fixtures are no longer available for new installations

New LED Lighting At the cooperative’s sole discretion, the cooperative may elect to connect new Municipally or POA owned lighting. All new lighting so connected will be LED lighting. The municipality/POA will own the entire street lighting facility, including the luminaire, pole, circuit, controls and all other related equipment on the load side of the Cooperative's point of delivery. Cooperative will operate and maintain such facilities and municipality/POA will reimburse Cooperative for cost of all labor, overhead, vehicle, maintenance material, or other cost of repair or replacement for such lighting. Municipality/POA will reimburse Cooperative for total cost of replacing or repairing broken or damaged poles.

5000 – 8999 Lumens (30 kWh per month) @ $1.73 9000 – 19999 Lumens (60 kWh per month) @ $3.45 20000 – 30000 Lumens (85 kWh per month) @ $5.18


54.5.1. Not less than one year or for such time as set forth in an agreement for lighting service.



54.7. ADJUSTMENTS







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Replacing Sheet No.





54.8 REQUEST FOR REPLACEMENT WITH LED LIGHT

54.8.1 An existing non-LED light will be replaced by the nearest equivalent LED light at no charge to the customer under the following conditions: 1) the existing non-LED light is not operating and 2) the Cooperative does not have in inventory equipment to replace or repair the existing non-LED light.

54.8.2. An existing non-LED light that does not meet the requirements of 54.8.1 will be replaced by an LED light upon request by the customer. In such a case, the customer will pay to the Cooperative a fee of $70 per light plus a trip fee of $45 per trip.


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Title: TRAFFIC SIGNAL SERVICE PSC File Mark Only

55. TRAFFIC SIGNAL SERVICE

55.1. AVAILABILITY

55.1.1. At any point on the Cooperative's existing distribution Iines.

55.2. APPLICATION

55.2.1. To unmetered traffic control signals and to flashing or warning signals of a municipality, a county, the state of Arkansas, or an agency thereof for the control of traffic on public streets or highways.


55.3.1. Single phase, 60 Hertz at a standard delivery voltage of the Cooperative.


55.4.1. Traffic Controls Per Direction @ $6.49 (3 Lens signals) Excess Lens @ $2.17

Flash or Warning Signals First 100 Watt @ $6.74 Each Additional 25 Watt @ $1.11

55.4.2. If average lamp rating exceeds 85 watts, the number of lenses at each intersection, or point of control, will be determined by dividing the sum of the lamp ratings, in watts, by eighty-five (85) and rounding to nearest whole number (major fractions will be rounded to one).

55.4.3. Each fifty watts, or fraction thereof, of power requirement of signal controlling and/or traffic counting devices at each intersection or point of control will be counted as one additional lens.


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Title: TRAFFIC SIGNAL SERVICE PSC File Mark Only


55.5.1. The customer shall be a member of the Cooperative, shall pay the membership fee and be bound by the provision of the Articles of Incorporation and By-laws of the Cooperative, and by such tariffs as may be approved by the Arkansas Public Service Commission.

55.5.2. If additional facilities are necessary or if it is necessary to rearrange existing facilities, customer will pay to the Cooperative the cost of such additional facilities or rearrangement.

55.5.3. Customer agrees not to change the connected load or the character of its facilities at each installation without notifying the Cooperative in writing of its intention to do so.

55.5.4. The Cooperative reserves the right to test and/or inspect the customer’s installation from time to time and to adjust the wattage ratings for billing purposes to conform with the findings of such tests or inspections.

55.6. ADJUSTMENTS



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ARKANSAS PUBLIC SERVICE COMMISSIONAPSC FILED Time: 12/30/2020 9:44:59 AM: Recvd 12/30/2020 9:38:12 AM: Docket 87-159-U-Doc. 279






Title: COST OF ENERGY ADJUSTMENT PSC File Mark Only

56. COST OF ENERGY ADJUSTMENT

56.1. APPLICATION

56.1.1. To all customers taking electric service under the approved Rate Schedules of the Cooperative.

56.2. COST OF ENERGY ADJUSTMENT

56.2.1. If the cost per kilowatt-hour (kWh) of energy to the Cooperative changes from the base cost of $0.036352 per kWh sold* 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 kilowatt-hour of energy shall include the per kWh charges, the fuel cost adjustments and the AECC billing for TO/RTO Rider charges** billed the Cooperative by its suppliers. The energy cost shall be adjusted by an amount equal to the over-or-under recovery of energy cost through the energy adjustment defined as the difference between those energy costs to be recovered in the preceding month and those costs actually collected in the preceding month. No other costs shall be included in this adjustment.

56.2.2. The Cost of Energy Adjustments shall be reported to the Staff on forms approved by the Commission at the earliest possible date prior to the implementation of the Cost of Energy Adjustment or as soon as possible thereafter.

56.2.3. *ECA Base of No-Loss Loads = $0.031132/kWh purchased.

56.2.4. ** For Industrial Power Service Customers, where TO/RTO Rider charges are billed the Cooperative by its suppliers and are separately identified by on the power supplier’s bills, such charges will be directly billed to the Industrial customers.

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Title: CALCULATION OF COST OF ENERGY ADJUSTMENT FACTORS PSC File Mark Only

57. CALCULATION OF COST OF ENERGY ADJUSTMENT FACTORS57.1. CALCULATION OF COST OF ENERGY ADJUSTMENT FACTORS

For billing during the month of

Industrial Remainder Section I - Current Period

1. Estimated Cost of Energy1.a Estimated TO/RTO Rider demand and energy charges Direct billed 2. Estimated kWh Sold3. Base Cost of Power per kWh Sold $0.031132 $0.036352 4. Base Power Cost Line 2 x Line 3 5. Power Cost to be Recovered Line 1 - Line 4 6. Prior Period Under (Over) Recovery Line 177. Total Amount to Recover Line 5 + Line 6 8. ECA Factor Line 7 ÷ Line 2

Section II - Prior Period Reconciliation 9. Cost of Energy (Power Bill)

9.a TO/RTO Rider demand and energy charges Direct billed 10. kWh Sold11. Base Cost of Power per kWh Sold Previous month Line 3 12. Base Power Cost Line 10 x Line 11 13. Power Cost to be Recovered Line 9 - Line 12 14. Prior Period Under (Over) Recovery Previous month Line 1715. Total Amount to Recover Line 13 + Line 14 16. ECA Amount Recovered As Billed 17. Under (Over) Recovery Line 15 - Line 16

Report Prepared By: Phone:


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Part III. Rate Schedule No.: 57A

Title: (Reserved for future use) PSC File Mark Only


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Title: COST OF DEBT ADJUSTMENT PSC File Mark Only

58. COST OF DEBT ADJUSTMENT

58.1. APPLICATION


58.2. COST OF DEBT ADJUSTMENT

58.2.1. If the cost of debt to the Cooperative changes from the annual interest of $9,711,427 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 changes. 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 kWh's for the billing quarter and a CFC-DSC ratio of 1.85. Any over or under collection shall be carried over to the next quarter's factor determination.


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Title: COST OF DEBT ADJUSTMENT REPORT PSC File Mark Only

59. COST OF DEBT ADJUSTMENT REPORT

59.1. INDUSTRIAL POWERCOOPERATIVE: ADDRESS

QUARTERLY COST OF DEBT ADJUSTMENT REPORT 1. Date of

Report _____________________ 2. Adjustment Rate to Apply

to Bills Dated _____________________

3. (a) Calculations Based on Cost of Debt for Quarter _____________________________________(b) Rate Base Allocation Factor __1.250%__. (Industrial Power Class, IP)

4. Outstanding Long-Term Debt and Cost of Debt this Quarter: (5)

Type of Debt

(6) Outstanding Debt

Balance

(7) Annual Rate

(8) Annual Cost

(9) Cost of Debt Paid

this Quarter

$ % $ $ $ % $ $ $ % $ $ $ % $ $ $ % $ $ Amortization of Conversion Fees $ $ Less CFC Performance Discount $ $ Less CFC Collateral Discount $ $ Less CFC Volume Discount $ $

Totals $ $ $ 10. Total Cost of Debt Paid this Quarter (Column 9 total) ……………………………………………... $ 11. Cost of Debt in Base Rates $9,711,427 x (a/365) ………………………………………………… $ 12. Cost of Debt Adjustment this Quarter (Line 10 – Line 11) $ 13. (Line 12) x CFC-DSC Level of 1.85…………………………………………………………………… $

(Line 13a) x Rate Base Allocation Factor of __1.250%__

$ 14. Cost of Debt Adjustment Authorized for Collection prior to Quarter………………………………. $ 15. Less Cost of Debt Adjustment Collected prior Quarter …………………………………………….. $ 16. Over or Undercollected Cost of Debt Adjustment previously Authorized $ 17 Total Cost of Debt Adjustment Authorized for Collection this

Quarter. (Line 13 +/- Line 16) $18. Estimated kWh Sales for Billing Quarter kWh 19. Cost of Debt Adjustment Rate for this Quarter (Line 17 / Line 18) $ /kWh

Notes: (a) Number of days in quarter in which adjustment is to occur.

PERSON COMPLETING REPORT TELEPHONE NUMBER


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Title: COST OF DEBT ADJUSTMENT REPORT PSC File Mark Only

59.2. NET SYSTEM COOPERATIVE: ADDRESS

QUARTERLY COST OF DEBT ADJUSTMENT REPORT 1. Date of

Report _____________________ 2. Adjustment Rate to Apply

to Bills Dated _____________________

3. (a) Calculations Based on Cost of Debt for Quarter _____________________________________(b) Rate Base Allocation Factor __98.750%__. (All other classes)

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

(5) Type of

Debt

(6) Outstanding Debt

Balance

(7) Annual Rate

(8) Annual Cost

(9) Cost of Debt Paid

this Quarter

$ % $ $ $ % $ $ $ % $ $ $ % $ $ $ % $ $ Amortization of Conversion Fees $ $ Less CFC Performance Discount $ $ Less CFC Collateral Discount $ $ Less CFC Volume Discount $ $

Totals $ $ $ 10. Total Cost of Debt Paid this Quarter (Column 9 total) ……………………………………………... $ 11. Cost of Debt in Base Rates $9,711,427 x (a/365) ………………………………………………… $ 12. Cost of Debt Adjustment this Quarter (Line 10 – Line 11) $ 13. (Line 12) x CFC-DSC Level of 1.85…………………………………………………………………… $

(Line 13a) x Rate Base Allocation Factor of __98.750%__ $ 14. Cost of Debt Adjustment Authorized for Collection prior to Quarter………………………………. $15. Less Cost of Debt Adjustment Collected prior Quarter …………………………………………….. $ 16. Over or Undercollected Cost of Debt Adjustment previously Authorized $ 17 Total Cost of Debt Adjustment Authorized for Collection this

Quarter. (Line 13 +/- Line 16) $18. Estimated kWh Sales for Billing Quarter kWh 19. Cost of Debt Adjustment Rate for this Quarter (Line 17 / Line 18) $ /kWh

Notes: (a) Number of days in quarter in which adjustment is to occur.

PERSON COMPLETING REPORT TELEPHONE NUMBER


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4th Revised Sheet No. 63.1

Replacing 3rd Revised Sheet No. 63.1


Kind of Service: Electric Class of Service: As Applicable


Title: POWER FACTOR ADJUSTMENT RIDER PSC File Mark Only

60. POWER FACTOR ADJUSTMENT RIDER

60.1. APPLICABILITY

60.1.1. This rider is applicable to the following Rate Schedule: Rate 16 Industrial Power Service – Optional Interruptible

60.2. DEFINITIONS

60.2.1. The power factor shall be determined to the nearest one-tenth of one percent at each delivery point at the time of Current Month kW Demand. The impact for multiple meter points at the same location shall be calculated as the net impact on the transmission system.

60.3. CALCULATION OF CHARGE AND KVAR CREDIT

RT

60.3.1. SUMMER MONTHS MT

60.3.1.1. During the summer months, the Average Power Factor (APF) requirements shall be 98%.

60.3.1.2. The APF shall be calculated using the average KW and average KVAR from the four summer months (June, July , August and September) during the current month and the previous eleven months. KVAR in months with a leading power factor shall be Included as zero in the average.

Charge: In the event that such APF is less than 98% lagging at any delivery point, a charge for that delivery point shall be made that is calculated as follows:

Charge KW = (98%*(Billing KW/APF))-Billing KW The Charge KW shall be multiplied by the Average Demand rate in the applicable rate schedule.


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Replacing 4th Revised Sheet No. 63.2




Title: POWER FACTOR ADJUSTMENT RIDER PSC File Mark Only

Credit: In the event that the APF is greater than 98% lagging, the Cooperative shall determine the difference between lagging KVAR at 98% lagging power factor and lagging KVAR required at the APF. A credit shall be given each month equal to $0.10 per KVAR for such difference.

MT

Credit KVAR = TAN(ACOS(0.98))*Billing KW - TAN(ACOS(APF))*Billing.

60.3.2. NON SUMMER MONTHS

60.3.2.1. Charges for the non summer months shall be based on the power factor at the time of the Current Month KW Demand.

Charge: In the event that the current month power factor is less than 95% lagging at any delivery point, a charge for that delivery point shall be made that is equal to the difference between 95% of the KVA at the time when the Current Month KW Demand is established and the KW at the time when the Current Month KW Demand is established. This difference shall be multiplied by the Average Demand rate in the applicable rate schedule.

Credit: In the event that the current month power factor is greater than 95% lagging, the Cooperative shall determine the difference between lagging KVAR required at 95% lagging power factor and the lagging KVAR required at the time the Current Month KW Demand is established. A credit shall be given each month equal to $0.10 per KVAR for such difference. In the event that such power factor is leading, the credit given by the Cooperative will be equal to the credit which would be given at 100% power factor.


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RT



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Title: VOLTAGE FLUCTUATIONS AND HARMONIC DISTORTION RIDER PSC File Mark Only

61. VOLTAGE FLUCTUATIONS AND HARMONIC DISTORTION RIDER

NR

61.1. APPLICABILITY

61.1.1. This rider is applicable to the following Rate Schedule: Rate 16 Industrial Power Service – Optional Interruptible

61.2. DESIGN CRITERIA FOR ELECTRIC SERVICE TO AN ARC FURNACE CONSUMER

61.2.1. The Consumer agrees to operate its equipment in such a manner that the maximum instantaneous change in three phase power flow at any of its connections to the utility system shall cause voltage fluctuations no greater than those shown in the following table:


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Frequency of Occurrence

Maximum Allowable % Voltage Dip

Individual Voltage Dips 1 Per Hour 3.0%



Individual Voltage Dips 1 Per Minute 0.8%

Individual Voltage Dips 1 Per Second 0.4%

Fluctuation Frequency

Maximum Allowable Voltage Fluctuation

Swing 1 Per Second 0.4%






Points between those shown above will be interpolated.


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3rd Revised Sheet No. 64.2

Replacing 2nd Revised Sheet No. 64.2





61.2.2. The Consumer agrees to install, own, operate, and maintain necessary harmonic filtering equipment which will operate in parallel with its equipment in such a manner that does not cause the harmonic component of voltages at any of its connections to the utility system be no greater than the following: The total harmonic distortion (THD) shall not be greater than 1.5% of the fundamental voltage. (IEEE Standard 519 for 115 kV and above.)

1.5% ≥ THD = ��Vh2Vi2

𝐻𝐻

ℎ=2

�

12

𝑥𝑥100%

Where Vh is the harmonic voltage and Vi is the fundamental voltage.

61.2.3. If the Consumer operates its equipment in such a manner as to exceed these design criteria, the Cooperative or AECC shall have the right to immediately discontinue the furnishing of electric power until the cause(s) of such excess(es) shall have been removed or remedied. The Cooperative or AECC shall have the further right to add a surcharge of the greater of 0.35 cents per kWh or the expense of the failure to meet the criteria in the Application section of this Rider.


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Title: TERMS OF PAYMENT RIDER PSC File Mark Only

62. TERMS OF PAYMENT RIDER

62.1. TERMS OF PAYMENT – NET SYSTEM

62.1.1. Bills are rendered monthly and are due and payable within 22 calendar days after bill is mailed for all active accounts. In the event payment is not made within 22 days after the date the bill is mailed, the Cooperative shall collect an additional 10% of the first $30.00 of the bill and 2% of the remaining balance as a late payment charge.

AT

62.1.2. A final bill issued to an account is due and payable within 14 calendar days after bill is mailed. A late payment charge is not applied to final bills.

AT

62.1.3. This section of the rider is applicable to the following schedules:

1, 2, 4, 5, 8, 9, 12, 13, 51, 54, and 55.

62.2. TERMS OF PAYMENT – INDUSTRIAL POWER (RATE SCHEDULE 16)

62.2.1. Bills are rendered monthly and are due and payable within 14 calendar days after bill is mailed. No late payment charge shall be imposed with payment of past due bill.

62.2.2. This section of the rider is applicable to Rate Schedule 16.


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Title: CHARGES RELATED TO CUSTOMER ACTIVITY PSC File Mark Only

63. CHARGES RELATED TO CUSTOMER ACTIVITY

63.1. APPLICABLE SERVICE AREA

63.1.1. To all customers taking electric service under the Cooperative's retail rate schedules as they are

now on file or as they may in the future be filed and approved by the Arkansas Public Service Commission (APSC).

63.2. CUSTOMER ACCOUNT RECORD STATEMENT

63.2.1. The Cooperative will charge a fee of ………………………………………………………………$0.00 when a customer or any authorized party requests a statement of the customer’s energy consumption for any period up to the preceding 13 months. .

CR

63.3. ENERGY CONSUMPTION STATEMENT

63.3.1. The Cooperative will charge a fee of ………………………………………………………………$0.00 To any customer or any authorized party GSR 7.02.

CR

63.4. MEMBERSHIP FEE

63.4.1. The Cooperative will charge a refundable membership fee of……………………………………… $10.00 to any customer applying for initial service with the Cooperative. The fee is refundable upon disconnection from the Cooperative's system.

63.5. DEPOSIT FROM APPLICANT FOR NON-RESIDENTIAL SERVICE

63.5.1. The Cooperative may require a deposit from a non-residential applicant for service.

63.6. DEPOSIT FROM APPLICANT FOR RESIDENTIAL SERVICE

63.6.1. The Cooperative may require a deposit from an applicant for residential service in accordance with APSC General Service Rule 4.01.A.. If any of the conditions in APSC General Service Rule 4.01.A.(2) apply, the Cooperative may waive all or a portion of a deposit based on the applicant's credit score as returned by a credit scoring service.


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63.7. DEPOSIT FROM LANDLORD

63.7.1. The Cooperative may require a deposit when an applicant for residential service qualifies as a landlord as defined in the APSC General Service Rules. The amount of the deposit will equal the estimated bill for three (3) average billing periods.

63.8. DEPOSIT DUE TO BANKRUPTCY

63.8.1. In accordance with the United States Bankruptcy Code, U.S.C.A. Title 11 § 366, the Cooperative may require a customer to furnish adequate assurance of payment in the form of a deposit or other security. This deposit may be in addition to all other deposits posted with the Cooperative before the bankruptcy filing.

63.9. DEPOSIT FROM CUSTOMER

63.9.1 The Cooperative may require a new deposit or an increase in the amount of a deposit from a customer in accordance with APSC General Service Rule 4.02.

63.9.2 Deposits will be reviewed as follows to continue service upon withdrawal from the Prepaid Electric Service Program: A. If the account was an existing active non-Prepaid account at time of Prepaid enrollment and remained on

Prepaid for 12 consecutive months, a credit scoring service will be used to determine if a deposit is required. If a deposit is required, one half of the deposit is due immediately upon withdrawal from the program and the remaining one half of the deposit will be billed on the first billing after withdrawal.

B. If the account was originally connected as a Prepaid account, a credit scoring service will be used to determine if a deposit is required. If a deposit is required, one half of the deposit is due immediately upon withdrawal from the program and the remaining one half of the deposit will be billed on the first billing after withdrawal.

C. If the account was an existing active non-Prepaid account at time of Prepaid enrollment and remained on Prepaid for LESS THAN 12 consecutive months, any deposit refunded at the time of Prepaid enrollment will be reinstated and must be paid in full immediately upon withdrawal from the program.

(AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT) (AT)

63.10. LATE PAYMENT CHARGE

63.10.1. The Cooperative will charge a late payment charge as established in Rate Schedule 62 as filed with the Arkansas Public Service Commission.

63.11. PROCESSING FEE FOR LEVELIZED BILLING WITHDRAWAL

63.11.1. The Cooperative will require a payment of a processing fee of: ……………………………………….$0.00 if a customer withdraws from a levelized billing plan more than 1 time in 12 months.


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63.12. RETURNED CHECK CHARGE

63.12.1. The Cooperative will charge a returned check fee when the customer makes payment by a check or other payment instrument that is not honored by customer’s financial institution for any reason other than bank error. The returned check fee shall be the maximum collection fee amount permitted under Arkansas Statute 4-60-103.

63.13. METER READING REPORT CHARGE

63.13.1. The Cooperative will charge a meter reading report fee of: ............................................................. $0.00 if a customer has requested a meter reading report in writing and the customer has already received a free meter reading report in the last 12 months.

63.14. METER TEST FEE

63.14.1. The Cooperative will charge a meter test fee of: ............................................................................ $50.00 when a customer requests that the Cooperative test the meter for accuracy. The meter will be tested in accordance with the procedures set out in GSR 5.18.. The fee will not be charged to the customer if meter test results show the meter to be operating outside of the guidelines of Rule 7.05. of the Special Rules -Electric.

63.15. COLLECTION FEE

63.15.1. The Cooperative will charge a fee of: .............................................................................................. $35.00 when the last day to pay, as printed on the most recent shut-off notice, has passed and a utility employee either accepts payment at the premises under GSR 6.09.B(1) or visits the premises at the customer’s request to collect. The collection fee will also apply when the Cooperative employee elects to postpone suspension of service procedures based on the consumer’s stated intention to provide payment at the Cooperative’s office by the end of the business day.

63.16. RECONNECTION FEE

63.16.1. The Cooperative will charge a reconnect fee of: ............................................................................ $65.00 when a customer or other authorized party pays to be reconnected prior to 4:00 p.m. during normal working hours. Normal working hours shall include the hours between 8:00 a.m. and 5:00 p.m., all days excluding weekends and holidays.


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63.16.2. The Cooperative will charge a reconnect fee of: .......................................................................... $100.00

when a customer or other authorized party pays to be reconnected after 4:00 p.m. or during hours other than the normal working hours described in paragraph 63.16.1.. Reconnections will not be made on the same day unless payment is received by 5:00 p.m.

63.17. FINANCE CHARGE ON DELAYED PAYMENT AGREEMENTS

63.17.1. The Cooperative will not assess a finance charge on delayed payment agreements.

63.18. SERVICE ACTIVATION FEE

63.18.1. The Cooperative will charge a fee of: ............................................................................................ $25.00 for service activation at each location during normal working hours. Normal working hours shall include the hours between 8:00 a.m. and 5:00 p.m., all days excluding weekends and holidays.

63.19. RESERVED FOR FUTURE USE

63.19.1. Reserved for future use.

63.20. TRIP FEE

63.20.1. The Cooperative will charge a fee of .............................................................................................. $50.00 when a customer requests a service trip by the Cooperative to the consumer’s premises during normal working hours as described in 63.16.1. In the event the Cooperative’s facilities are the cause of the service request, no such charge shall be made.

63.20.2. The Cooperative will charge a fee of ............................................................................................. $75.00 when a customer requests the Cooperative to investigate a service problem, during other than normal working hours as described in paragraph 63.16.1, if the Cooperative’s facilities are not the cause of the service problem. In the event the Cooperative’s facilities are the cause of the service request, no such charge shall be made.


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Title: TAX ADJUSTMENT PSC File Mark Only

64. TAX ADJUSTMENT

64.1. APPLICATION


64.2. TAX ADJUSTMENT

64.2.1. System base rates do not include excise, license, privilege or franchise taxes (except ad valorem and income taxes) which the Cooperative has to pay. Such taxes or charges shall be recovered from those customers within jurisdictional boundaries of the taxing bodies and shall be referenced on the face of the bill. Tax adjustments shall be collected in the same manner in which taxes are incurred.

CT


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Replacing None Sheet No.



Part III. Rate Schedule No.: 64.1

Title: EMERGENCY SERVICE – BENTON – Closed 9/30/2016 PSC File Mark Only

64.1 EMERGENCY SERVICE - BENTON

64.1a APPLICATION

64.1.1a Applicable to Benton Utilities for emergency wholesale service. This tariff will only be applicable from the effective date through September 30, 2016. It will be closed to all customers after that date.

64.1.2a Benton Utilities will pay in advance the full cost of adding any facilities required to provide service and any maintenance cost for said facilities, in addition to any engineering, consulting or other costs required to provide service.

64.1.3a Benton Utilities will reimburse the cooperative in full for the total cost of purchased power incurred by the Cooperative from its power supplier to provide service to Benton Utilities, including, but not limited to, generation, transmission, service charges, taxes and any future ratchet or other power cost-related costs incurred by the Cooperative in providing service to Benton Utilities. In addition, the cost of power will be increased by 5% to account for losses incurred by the Cooperative between its delivery point with its power supplier and the delivery point with Benton Utilities.


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2nd Revised Sheet No. 70.1a

Replacing 1st Revised Sheet No. 70.1a


Kind of Service: Electric Class of Service: ALL


Title: NET-METERING PSC File Mark Only

TABLE OF CONTENTS Tariff Provisions .............................................................................................................. Page 70.1a Preliminary Interconnection Site Review Request ............................................................. Page 70.1d

Standard Information ......................................................................................... Page 70.1d Terms and Conditions ........................................................................................ Page 70.1e

Standard Interconnection Agreement for Net-Metering Facilities ....................................... Page 70.1f Standard Information ......................................................................................... Page 70.1f Interconnection Agreement Terms and Conditions .............................................. Page 70.1g

Disclaimer ....................................................................................................................... Page 70.1k

65. NET-METERING65.0 DEFINITIONS 65.0.1 65.0.2 65.0.3 65.0.4 65.0.5 65.0.6 65.0.7 65.0.8

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

65.1 AVAILABILITY

65.1.1. Service under the provisions of this tariff is available to any residential or any other customer who takes service under standard rate schedules 1, 2, 4, 5, 9, 12, 13, 16 or 51, is a Net Metering Customer, and who has obtained a signed Standard Interconnection Agreement for Net-Metering Facilities with a 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. The generating capacity of Net-Metering Facilities may not exceed one thousand kilowatts (1,000 kW) for non-residential use unless otherwise allowed by the Commission. Net-Metering is intended primarily to offset part or all of the customer’s energy use.

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

65.1.2. 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.

65.2. MONTHLY BILLING 65.2.1. 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. 65.2.2. 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.

APSC FILED Time: 3/2/2021 9:05:03 AM: Recvd 3/2/2021 9:03:23 AM: Docket 16-027-R-Doc. 587

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2nd Revised Sheet No. 70.1b

Replacing 1st Revised Sheet No. 70.1b





65.2.3. 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.

65.2.3a 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 retail rate 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 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.

65.2.3.a.1 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.

65.2.3.b 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 the statutory limits under Ark.Code Ann. 23-18-604(b)(9), the Cooperative shall credit the 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 on 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.

The Cooperative shall also bill the Net-Metering Customer a grid charge. Grid Charge rate: $0.00.

65.2.4. 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.

65.2.5. 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).

65.2.6 After application of 65.2.5 and upon request of the Net-Metering Customer pursuant to 65.2.8, and 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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2nd Revised Sheet No. 70.1c

Replacing 1st Revied Sheet No. 70.1c





65.2.7 Net Excess Generation shall be credited as described in 65.2.5 and 65.2.6 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 plus any additional sum determined under the Net-Metering Rules, 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 cost, plus any additional sum determined under the Net-Metering Rules 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; or3) 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 Avoided Costs plus any additional sum determined under the Net Metering Rules for the current year.

65.2.8 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.

(c) However, the common ownership requirements 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)(c) co-locate at a site hosting the Net Metering Facility.

(d) 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.

65.2.9 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.

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


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2nd Revised Sheet No. 70.1d

Replacing 1st Revised Sheet No. 70.1d





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 Inverter Rating (kW) __________________________________AC Expected 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 Customer): Date:


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2nd Revised Sheet No. 70.1e

Replacing 1st Revised Sheet No. 70.1e





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. 70.1f

Replacing 1st Revised Sheet No. 70.1f





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: Mailing Address: City: State: Zip Code: Facility Location (if different from above): ____ Daytime Phone: Evening Phone:

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:

______________________________________________ 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. 70.1g

Replacing 1st Revised Sheet No. 70.1g





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 First Electric Cooperative Corporation ("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.

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.


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2nd Revised Sheet No. 70.1h

Replacing 1st Revised Sheet No. 70.1h





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 to 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; and3) 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.

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.


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2nd Revised Sheet No. 70.1i

Replacing 1st Revised Sheet No. 70.1l





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.

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:


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2nd Revised Sheet No. 70.1j

Replacing 1st Revised Sheet No. 70.1j




Title: NET METERING PSC File Mark Only

Attention: Attention: Mr. Don Crabbe [Customer] First Electric Cooperative Corporation Name: 1000 JP Wright Road (72076) Address: PO Box 5018 City: Jacksonville, AR 72078-5018 Email:

Customer notices to Cooperative shall refer to the Customer's electric service account number set forth in Section 1 of this Agreement.

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: First Electric Cooperative Corporation

By: By:

Title: Title:

Mailing Address: Mailing Address: P.O. Box 5018

Jacksonville, AR 72078-5018

E-mail Address: E-mail Address:

___________________________ ___________________________


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2nd Revised Sheet No. 70.1k

Replacing 1st Revised Sheet No. 70.1k





Third-Party Owner (if applicable)

By:

Title:

Mailing Address:

E-mail Address: :

___________________________ ___________________________

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 First Electric Cooperative (the Cooperative).

1. Electricity rates, basic charges, and service fees, set by First Electric Cooperative and approved by theArkansas 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 First Electric Cooperative.

3. My Net-Metering System is subject to the current rates of First Electric Cooperative, and the rules andregulations of the Commission. First Electric Cooperative may change its rates in the future with approvalof the Commission or the Commission may alter its rules and regulations, or both may happen. If either orboth 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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Title: EXTENSION OF FACILITIES PSC File Mark Only

TABLE OF CONTENTS


Sheet Number

As Applicable 70.1 Applicable Service Area

72

As Applicable 70.2 General Regulations

72

As Applicable 70.3 Design and Construction Standards

72

As Applicable 70.4 Definitions

72

As Applicable 70.5 Extension of Service Considerations

73

As Applicable 70.6 Single-Phase Overhead Line Extensions – Permanent

74

As Applicable 70.7 Single-Phase Overhead Line Extensions – Temporary

74

As Applicable 70.8 Three-Phase Overhead Line Extensions – Permanent

74

As Applicable 70.9 Three-Phase Overhead Line Extensions – Temporary

75 RT

As Applicable 70.10 Multiple Applicants for Service From the Same Extension

75 CT


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Replacing Sheet No.





70. EXTENSION OF FACILITIES

70.1 APPLICABLE SERVICE AREA

70.1.1. All areas allocated by the Arkansas Public Service Commission to the Cooperative for the provision of retail electric service.

70.2 GENERAL REGULATIONS

70.2.1 The ownership of the line, including any extensions, remains with the Cooperative and the Cooperative reserves the right to connect others and to determine all construction specification and distances.

70.3 DESIGN AND CONSTRUCTION STANDARDS

70.3.1 The Cooperative will be guided by the provisions of the National Electric Code, the National Electric 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 that construction begins.

70.3.2 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.

70.4 DEFINITIONS

70.4.1 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.

70.4.2. Permanent Installation: 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 electric service on a year-round basis. To qualify as a permanent installation, a building or mobile home used as a dwelling must have a permanent water supply under pressure and a sewage disposal system. The applicant must also have at least a leasehold interest in the site where the electric service extension is to be provided.


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70.4.3. Temporary or Non-Permanent Installations: 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 are not limited to the following:

A. Modular and mobile homes not qualifying as a permanent installation as defined in paragraph 70.4.2.

B. Services 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 and road shows.

E. Certain farm buildings such as hay sheds and feeder sheds.

70.5. EXTENSION OF SERVICE CONSIDERATIONS

70.5.1. 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.

70.5.2. The applicant shall provide for the acquisition of right-of-way easements for the extension.

70.5.3. The applicant shall provide the Cooperative with an accessible entrance to the site.

70.5.4 Applicant must install metering and service entrance facilities as required by the Cooperative’s Member Installation Standards for Electric Service. No installation will be connected to electric service unless it meets the requirements of the Cooperative. The Cooperative will furnish to each applicant a drawing showing the installation requirements of a typical meter loop for the requested service. The Cooperative will provide installation of all meter loops located on Cooperative’s service poles.

CT


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70.5.5. If a contribution in aid of construction will be required in order to extend service to the applicant, the

applicant must sign an Extension of Service Agreement, before construction begins.

70.6 SINGLE-PHASE OVERHEAD LINE EXTENSIONS – PERMANENT

70.6.1. When an extension of 1,000 feet or less is required, service will be extended to a permanent installation without any contribution in aid of construction required of the applicant.

CT RT

70.6.2. When an extension of more than 1,000 feet is required, the applicant must pay a contribution in aid of construction as follows:

First 1,000 feet: No contribution is required Over 1,000 feet: Contribution is 100% of the cost of the line that is in excess of 1,000 feet.

70.6.3. The amount of the contribution in aid of construction will be calculated by the Cooperative. The charge will be based on the Cooperative’s average cost per foot of for the extension, calculated using the Cooperative’s current labor, material, and overhead costs, excluding the costs of transformers and meters.

70.6.4. If approved by the Commission under its Promotional Practice Rules, the Cooperative may waive all or a portion of the contribution or negotiate a returnable contribution where the Cooperative determines that doing so would result in a net economic benefit to all other members.

CT

70.6.5. 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.

70.7. SINGLE-PHASE OVERHEAD LINE EXTENSIONS – TEMPORARY

70.7.1. The applicant shall be required to pay, before construction begins, a contribution in aid of construction equal to the total estimated cost of the line extension and of the retirement of that extension, less the cost of transformers, meters, and other salvageable materials.

70.8. THREE-PHASE OVERHEAD LINE EXTENSIONS – PERMANENT

70.8.1. When an extension of 1,000 feet or less is required, service will be extended to a permanent installation without any contribution in aid of construction required of the applicant.

CT


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70.8.2.

When an extension of more than 1,000 feet is required, the applicant must pay a contribution in aid of construction as follows:

First 1,000 feet: No contribution required All feet over 1,000 feet: Contribution is 100% of the cost of the line that is in excess of 1,000 feet.

CT AT RT

70.8.3. The amount of the contribution in aid of construction will be calculated by the Cooperative. The charge will be based on the Cooperative’s average cost per foot of for the extension, calculated using the Cooperative’s current labor, material, and overhead costs, excluding the costs of transformers and meters.

70.8.4. If approved by the Commission under its Promotional Practice Rules, the Cooperative may waive all or a portion of the contribution or negotiate a returnable contribution where the Cooperative determines that doing so would result in a net economic benefit to all other members.

CT

70.8.5. Small compressors, hobby motors, welders, or other loads that can be economically served with single phase service will not be considered as permanent three phase.

70.8.6. In areas that have existing single-phase overhead lines that must be converted to three-phase lines in order to provide service to the applicant, overhead three-phase service will be installed upon the applicant’s prepayment of a contribution in aid of construction. The applicant’s contribution in aid of construction will equal the total cost of the line conversion less the construction cost of 1,000 feet of three-phase line.

CT

70.8.7. When the conversion of an existing electric line is necessary to provide the desired electric service, the length of line extension will be measured from the point where the line conversion begins.

70.8.8. 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.

70.9. THREE PHASE OVERHEAD LINE EXTENSIONS – TEMPORARY

70.9.1. The applicant shall be required to pay, before construction begins, a contribution in aid of construction equal to the total estimated cost of the line extension and of the retirement of that extension, less the cost of transformers, meters, and other salvageable materials.


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70.10. MULTIPLE APPLICANTS FOR SERVICE FROM THE SAME EXTENSION

70.10.1. The Cooperative will make reasonable efforts to identify and notify residents, farmsteads, businesses, and other establishments in the general area of a proposed extension of service and give them an opportunity to participate in the extension. Any contribution in aid of construction required under this policy will then be paid by the participants in the extension on the basis of a proportionate share. Proportionate shares will be calculated by the Cooperative on a cost per foot basis.

70.10.2. 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.

70.10.3. When a customer pays for an extension of service and later moves from that service location, the Cooperative will attempt to leave those facilities in place for use by other customers.

A. If the Cooperative removes the facilities, an applicant requesting the same extension of service at the premises within twelve months shall obtain the extension cost-free.

AT

B. If the facilities were removed at the request of a previous customer at the service location, the extension will be provided based on the Cooperative’s regular line extension policy.


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Replacing Sheet No.




Title: INSTALLATION OF UNDERGROUND FACILITIES PSC File Mark Only

71. INSTALLATION OF UNDERGROUND FACILITIES

71.1 APPLICABLE SERVICE AREA

71.1.1. All areas allocated by the Arkansas Public Service Commission to the Cooperative for the provision of retail electric service.

71.2 GENERAL REGULATIONS

71.2.1 The ownership of the line, including any extensions, remains with the Cooperative and the Cooperative reserves the right to connect others and to determine all construction specification and distances.

71.3 DESIGN AND CONSTRUCTION STANDARDS

71.3.1 The Cooperative will be guided by the provisions of the National Electric Code, the National Electric 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 that construction begins.

71.3.2 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.

71.4 DEFINITIONS

71.4.1 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 facilities.

71.4.2. Developer: A person, partnership, association, corporation or governmental agency that owns or promotes a residential subdivision, apartment development, commercial development or mobile home park.

71.4.3. 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 customers.


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71.4.4. Subdivision: Any tract of land which is divided into no less than ten lots for the construction of single-

family residences.

71.5. CONDITIONS

71.5.1. The Cooperative will make underground construction desired by the developer or applicant for service available only if, in the Cooperative’s judgment, it is feasible to construct, own, operate, maintain, and replace underground facilities at the particular location taking into account the size and type of load.

71.5.2. All necessary easements must be provided to the Cooperative prior to any underground construction.

71.5.3. All rough site grading must be completed and final grade established prior to installation of any underground electric facilities.

71.5.4. The Cooperative shall have the right to excavate necessary trenches to locate and repair the underground facilities in the event of failure of service.

71.5.5. 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.

71.5.6. Any subdivision or development to be served under this policy shall consist of a single tract of land so arranged and situated that the underground electric distribution system and associated service connections will be the only type of electric system required within the subdivision or development.

71.5.7. To the maximum extent practicable, the Cooperative will work out an agreement with the affected telephone company to install electric cables in the same trench with due care being taken to conform to National Electrical Code and all applicable local codes and specifications. No water, gas nor sewer pipes shall be installed in the same trench with the Cooperative’s electric cables.

71.5.8. The type of construction, character of service and location of the underground electric system will be at the option of the Cooperative. 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 paying the Cooperative the estimated additional cost incurred thereby.

71.5.9. Applicant must install metering and service entrance facilities as required by the Cooperative’s Member Installation Standards for Electric Service suitable for the type of installation requested. No installation will be connected to electric service unless it meets the requirements of the Cooperative.

CT


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71.6. DEVELOPER’S/APPLICANT’S RESPONSIBILITY

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

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

71.6.3. Developer will, at no cost to the Cooperative, provide and record all easements and rights-of-way required by the Cooperative and will execute, or cause to be executed, all other contracts and agreements required by the Cooperative. All easements for underground electric service shall be on the street side of the lot.

71.6.4. 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.

71.6.5. The developer or applicant shall be responsible for the opening of all trenches, excavating for the transformer vault, if required, preparing trench for cable installation and, after the cable and associated accessories have been installed, backfilling all trenches, all according to Cooperative specifications, Cooperative may, by agreement and at its option, perform the trenching and backfilling operations, to be reimbursed at its actual cost.

71.6.6. 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. The developer will hold the Cooperative or its subcontractors harmless against any claims for such damage.

71.6.7. The applicant shall furnish and install metering and service entrance facilities as required by the Cooperative’s Member Installation Standards for Electric Service suitable for the type of installation requested.

CT

RT


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Replacing Sheet No.





71.7. COOPERATIVE RESPONSIBILITY

71.7.1. The Cooperative will furnish all material and equipment (excluding the conduit from the top of meter to trench) and will construct, install, own and maintain the complete underground electric system to the meter socket including the conduit to be installed under streets, alleys, drives, sidewalks and other paved areas.

71.8. CHARGES

71.8.1. If feasible, underground electric facilities will be provided upon the payment of a contribution in aid of construction equal to the cost of installing underground facilities in excess of the cost of installing overhead facilities, excluding transformers and meters, with the following exceptions:

A. For installation to any type of temporary or seasonal load, the contribution in aid of construction shall be equal to the cost of installing underground facilities, less transformers and meters.

71.8.2 The Cooperative will periodically calculate the average installed cost per foot of installing underground and overhead facilities (less transformers and meters). Contributions in aid of construction will be applied on a per foot basis.

71.8.3. If a customer with an existing overhead service requests underground service, the customer shall pay, in addition to the charges applicable in paragraph 71.8.1., all costs involved in the removal of the overhead service, plus the installed cost of the overhead facilities, less salvage value of the materials removed.

71.9. STREET LIGHTS

71.9.1. Where street lights are to be installed in a subdivision at the same time underground distribution system is installed, and the cable for the street lighting is to lie in a common trench with the distribution cable, the Cooperative will furnish, install, own and maintain the entire street lighting system except that developer shall pay Cooperative the total actual installed cost of each street light pole or standard.

71.9.2. Where developer desires that a street light system be installed after the underground distribution system has been installed, developer shall pay Cooperative the actual cost of opening and closing the trench for the underground street lighting circuit(s) in addition to the total actual installed cost of each street light pole or standard.


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Part IV. Policy Schedule No.: 1

Title: EXTENDED ABSENCE PAYMENT PLAN PSC File Mark Only

1. EXTENDED ABSENCE PAYMENT PLAN

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

1.1.1. 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 more 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.

1.1.2. 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.

1.1.3. The customer may arrange to make payment(s) during the period of absence using a bank draft or credit card.

AT

1.2 The customer must notify the Cooperative in order to take advantage of any of these extended absence payment plans.


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Replacing Sheet No.




Title: EXTENDED DUE DATE PLAN PSC File Mark Only

2. EXTENDED DUE DATE PLAN

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

2.2. AVAILABILITY

2.2.1. Customers whose income checks from any of the sources listed below are not normally received by the regular bill due date are eligible to apply for an extended due date. Qualifying income sources are as follows:

A. Persons receiving Aid to Families with Dependent Children (AFDC), or Aid to the Aged, Blind and Disabled (AABD);

B. Persons receiving Supplemental Security Income; or,

C. Persons whose primary source of income is Social Security or Veterans Administration disability or retirement benefits.

2.3. APPLICATION

2.3.1. Customers shall become plan participants upon either written or verbal application to the Cooperative. Participation will continue each month thereafter, regardless of account location, as long as the customer’s account remains active. Verification of income being received by the customer may be required.

2.3.2. After acceptance of a customer by the Cooperative as a participant in the Extended Due Date Plan, the customer shall supply to the Cooperative the date on which his monthly income is received (check receipt date) and the Cooperative will make this information a permanent part of the customer’s record.

2.4. SETTING THE EXTENDED DUE DATE

2.4.1. During the billing procedure each month, the Cooperative billing system will compare the check receipt date supplied by the customer with the billing date and the bill due date. Based on this comparison, the following method of determining a bill due date will be used:


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Replacing Sheet No.




Title: EXTENDED DUE DATE PLAN PSC File Mark Only

A. If the check receipt date occurs within the time span between the billing date and the bill due date,

the normal bill due date of the account remains in effect.

B. If the check receipt date occurs beyond the time span of the billing date and the bill due date, the due date will be at least three days after the check receipt date and only the extended due date will appear on the customer's bill.

2.4.2. If the customer does not pay bills by the close of business on the extended due date 2 times in a row or any 3 times in the last 12 months, the Cooperative will remove the customer from the plan. The Cooperative will notify the customer in writing when the customer has been removed from the plan for late payment.

2.4.3. If payments are not received by the close of business on the extended due date, the Cooperative will follow the established notification process established by the Arkansas Public Service Commission which could ultimately result in termination of the service.


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Title: LEVELIZED BILLING PLAN PSC File Mark Only

3. LEVELIZED BILLING PLAN

3.1. AVAILABILITY

3.1.1. To a year-round residential customer receiving electric service under approved Rate Schedule 1 or 2 who desires to take service under the conditions stated herein.

3.2. APPLICATION

3.2.1. Upon request from any residential customer qualifying for this service.

3.2.2. Not applicable to temporary or seasonal service.

3.3. BILLING

3.3.1. The customer's monthly bill will be computed in accordance with the applicable rate schedule(s) and the customer's account debited with such amount. The net amount payable for service for the current month will equal, to the nearest whole dollar, the average monthly amount debited to the customer's account during the twelve months ending with the current month, plus or minus one-twelfth of the accumulated difference between previous debits and the amounts payable under this plan.

RT

3.3.2. Where the customer has less than twelve months billing history at the present location or the billing history is not representative, estimates of monthly bills may be made based upon average bills for the rate class.

CT

3.4. TERMS AND CONDITIONS

3.4.1. The eligibility criteria for levelized billing shall be the same as the criteria specified in General Service Rules 4.01.A.(2) under which a utility may require a deposit. If the customer meets the requirements for no deposit, then they are also eligible for the levelized billing plan. Once a customer has met the criteria for refunding a deposit, the customer will be eligible for levelized billing.

AT


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Title: LEVELIZED BILLING PLAN PSC File Mark Only

3.4.2. Billing under this plan may be terminated if customer's payment is delinquent for two

consecutive months, or payment is delinquent three times in a twelve month period. Plan billing may also be terminated upon suspension of customer's service.

3.4.3. A customer may withdraw from the plan at any time.

RT

3.4.4. Upon withdrawal from a levelized billing plan, the customer shall have the option of paying the account balance in full or, if qualified, under a delayed payment agreement.


3.5.1. Except as modified herein, all other provisions of Rate Schedules 1 and 2 shall apply.


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Replacing Sheet No.




Title: PROVISIONS FOR LANDLORDS AND TENANTS PSC File Mark Only

4. PROVISIONS FOR LANDLORDS AND TENANTS

4.1. ACCOUNT IDENTIFICATION

4.1.1. The Cooperative has established the following procedures for identifying accounts where utility service is provided at an address different from the mailing address of the bill:

A. When application is made for service, Cooperative personnel will inquire as to whether the account qualifies as a landlord/tenant situation as described by GSR 6.19.A.

B. A suitable form for applying for these provisions is available in the Cooperative's office and is included in the Cooperative's General Information to Customers booklet provided to each new customer.

C. Cooperative customers will be notified annually of their rights under GSR 6.19.B. through billing inserts or publications distributed to customers of the Cooperative.


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Replacing Sheet No.




Title: METER TESTING PROGRAM PSC File Mark Only

5. METER TESTING PROGRAM

5.1. TEST PROGRAM FOR NEW METERS

5.1.1. To ensure that new meters conform to the accuracy requirements of SR-E 7.05.B., before installation by the Cooperative, all new meters will be inspected and tested in a meter shop or laboratory under the sampling method indicated below:

100% of all new meters will be tested.

X New meters will be tested on a sampling basis conforming to ANSI C12.1-1982, § 8.1.5.

5.2. IN-SERVICE METER TESTING PROGRAM

5.2.1. In accordance with SR-E 7.08.B., the Cooperative maintains a periodic in-service testing schedule for watthour, polyphase, demand meter and pulse recorders as follows:

A. All single phase watthour meters are to be tested not to exceed 16 years.

B. Self contained polyphase meters are to be tested not to exceed 12 years.

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

D. In-service pulse recorders are compared monthly to the meter registration. If the registration agrees within the 1% tolerance outlined in ANSI C12.1-1982 § 8.2.3.1., the pulse recorder is scheduled for testing not to exceed a 16 year cycle. However, if the recorder-meter registration checks do not agree within the 1%, the demand metering equipment is tested.

E. Note: Any meter not containing surge proof magnets is retired.


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Replacing Sheet No.




Title: STANDARD NOMINAL VOLTAGES PSC File Mark Only

6. STANDARD NOMINAL VOLTAGES

6.1. NOMINAL VOLTAGES - SECONDARY

6.1.1. The following secondary voltages are available from the Cooperative depending on the customer's size, application and location on its distribution system:

Single Phase: 120/240

Three Phase: 120/208 wye 277/408 wye 240 delta* 480 delta*

* not available at new installations requiring primary underground or in 14.4/29.4 kV primary system areas.

6.2. NOMINAL VOLTAGES - PRIMARY

6.2.1. The following primary voltages are available from the Cooperative depending on the customer's size, application, and location on its distribution system:

7.62/13.2 kV 14.4/24.9 kV

6.3. OTHER VOLTAGE SERVICE

6.3.1. Depending on the customer's size, application and location, customers requiring other voltages may be served through special arrangements under written agreements.


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Title: VOLTAGE VERIFICATION PLAN PSC File Mark Only

7. VOLTAGE VERIFICATION PLAN

7.1. ELECTRIC VOLTAGE VERIFICATION PLAN

7.1.1. The Cooperative will have installed by 01/01/2006, at each of its distribution substations, voltmeters that verify voltage levels by recording continual voltage readings.

CT


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Title: POLE IDENTIFICATION SYSTEM PSC File Mark Only

8. POLE IDENTIFICATION SYSTEM

8.1. MEANS OF OWNERSHIP IDENTIFICATION

8.1.1. The Cooperative will identify the ownership of its poles by the installation of the following metal tag nailed to each pole. The circular identification will be located above the brand added by each pole manufacturer which contains the length, pole class, date of manufacture, type of wood and type of treatment information.

8.2. FIELD IDENTIFICATION

8.2.1. The field identification of specific structures and poles in order to direct service and operations personnel is accomplished by the use of a geo-referenced map grid number. Each map grid number is referenced from a known point of beginning in the Arkansas State Plane coordinate system. These structure and pole locations, together with the electrical system, map grid, background data, and other Cooperative information, are maintained in the Cooperative’s Geographic Information System (GIS), which is available through various printed and electronic media to the Cooperative’s employees and contractors.

CT


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Replacing Sheet No.




Title: SUPPLYING AND TAKING OF ELECTRIC SERVICE PSC File Mark Only

9. SUPPLYING AND TAKING OF ELECTRIC SERVICE

9.1. CONTINUITY OF ELECTRIC SERVICE

9.1.1. The Cooperative will use all reasonable diligence in providing a regular and uninterrupted supply of electric service, but does not guarantee the electric service against interruptions or irregularities. In case the supply of electricity shall fail or be interrupted, or become defective through an act of God, or the public enemy, or state, municipal or other public authority, or because of accident, strike, or any other causes beyond the reasonable control of the Cooperative, the Cooperative shall not be liable for such failure, interruption or defect.

9.2. CUSTOMER’S RESPONSIBILITY

9.2.1. Customer assumes all responsibility on customer’s side of the point of delivery for the electric service supplied or taken, as well as for the electrical installation, appliances and apparatus used in connection therewith, and shall save Cooperative harmless from and against all claims for injury or damage to persons or property occasioned by or in any way resulting from such electric service or the use thereof on customer’s side of the point of delivery.

9.3. RIGHT-OF-WAY FOR DISTRIBUTION FACILITIES

9.3.1. Without reimbursement, customer shall make or procure conveyance to Cooperative right-of-way (to include licenses for franchises, if essential) for all Cooperative owned distribution facilities whether installed by Cooperative, purchased by Cooperative or contributed to Cooperative by customer and for all future extensions and modifications to such facilities, satisfactory to Cooperative for Cooperative’s extensions, and the customer shall protect Cooperative in its peaceful use and occupancy of such right-of-way.

9.4. ACCESS TO PREMISES

9.4.1. Duly authorized agents of Cooperative shall at all reasonable hours have access to the premises of customer for the purpose of inspecting, operating, maintaining, removing, or replacing Cooperative property and for the reading of Cooperative meters and all other purposes incidental to the supplying of service; and shall be furnished such access at any time for emergency repairs, removal, replacement, or operation of Cooperative facilities.


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Replacing Sheet No.




Title: CUSTOMER’S INSTALLATION PSC File Mark Only

10. CUSTOMER’S INSTALLATION

10.1. COMPLIANCE WITH RECOGNIZED STANDARDS

10.1.1. Customer’s installation shall meet or exceed all requirements of the National Electrical Code and all state and local regulations applicable thereto, at the time of such installation.

10.2. SERVICE FROM COOPERATIVE

10.2.1. In all cases where new installations or alterations and additions to existing installations are to be made, Cooperative shall be consulted as to the location of all service connections and/or meters and metering equipment. The Cooperative shall also be consulted regarding the size and character of load to be connected or added and the characteristics of service to be supplied.

10.2.2. The point of attachment of Cooperative’s facilities to the customer’s building and the nature and characteristics of service will be given in writing for all new installations and for alterations or additions to existing installations. The Cooperative will not be responsible when such information is given verbally.

10.3. NATURE AND USE OF INSTALLATIONS

10.3.1. Customer will select and operate his equipment in such a manner that it will not cause unusual fluctuations or disturbances on the Cooperative system and it will not adversely affect Cooperative’s electric service either to the customer or to others. When Cooperative supplies three-phase service, the customer will control his use of the electric service so that the load at the point of delivery will be maintained in reasonable electrical balance between the phases.

10.4. GROUNDING

10.4.1. Customer shall be responsible for the installation and maintenance of an electrical ground which meets or exceeds all requirements of the National Electrical Code, and all state and local regulations applicable thereto at the time of such installation for grounding the neutral bus of the service entrance panel, main disconnecting switch or main circuit breaker.


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Replacing Sheet No.




Title: COOPERATIVE’S INSTALLATION PSC File Mark Only

11. COOPERATIVE’S INSTALLATION

11.1. INSTALLATION AND MAINTENANCE

11.1.1. Except as otherwise provided in Service Rules and Regulations, in Agreements for Service or Rate Schedules, Cooperative will install and maintain its lines and equipment on its side of point of delivery. Cooperative shall not be required to install, inspect or maintain any lines or equipment except meters on customer’s side of the point of delivery. Only Cooperative employees are authorized to connect Cooperative’s service drop to customer’s service terminals.

11.2. PROTECTION BY CUSTOMER

11.2.1. Customer shall protect Cooperative’s wiring and apparatus on customer’s premises and shall permit no one but Cooperative employees or persons authorized by law to inspect or handle same. In the event of any loss or damage to the Cooperative’s property arising out of carelessness, neglect, or misuse by customer or other unauthorized persons, the cost of making good such loss or repairing such damage shall be paid by customer.

11.2.2. All wiring and apparatus supplied by Cooperative, purchased by Cooperative or contributed to Cooperative by customer shall remain its property, and if in customer’s possession, shall on termination of Agreement for Service be returned to Cooperative by customer in as good of condition as when received by customer, ordinary wear and tear excepted. Cooperative may at any time examine, change or repair its property on the premises of customer and may remove its property upon or at any time after termination of service.

11.3. RELOCATION OF FACILITIES

11.3.1. The Cooperative may relocate its facilities from time to time as it becomes necessary for the operation and improvement of the system.

11.3.2. If a customer requests that certain Cooperative facilities be relocated, the customer shall pay in advance for the relocation, including cost of all materials required and estimated direct labor cost; unless one of the following conditions are met:

A. The relocation is made for the convenience or will be made for the advantage of the Cooperative.

B. The relocation will result in a substantial improvement in the Cooperative’s facilities or their location.


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Replacing Sheet No.




Title: COOPERATIVE’S INSTALLATION PSC File Mark Only

C. The relocation is associated with other regularly scheduled conversion or construction work and can be done at the same time.

11.4. METERING

11.4.1. Cooperative will furnish and install the necessary meter(s) and customer shall, without reimbursement, provide and maintain location satisfactory to the Cooperative for its installation.

11.4.2. No customer will furnish or install any meter or other measuring device for the purpose of measuring electric service to any person, firm, corporation, association, or to any third party.


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Title: BILLING PSC File Mark Only

12. BILLING

12.1. METER READING AND BILLING

12.1.1. The Cooperative shall read the meters on the system each month.

12.1.2. The customer is responsible for providing free access to the meter.

12.1.3. In the event the meter cannot be read due to conditions beyond the control of the customer, (high water, etc.), the Cooperative may estimate the meter reading and render a bill. The customer’s account shall be adjusted at the next regular billing date, provided an actual meter reading is obtained.

12.1.4. Non-receipt of bills by the customer shall not release or diminish the obligation of the customer with respect to payment thereof.

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12.2. SELECTION OF RATE SCHEDULE

12.2.1. When an application for electric service is made, the Cooperative will select the rate schedule most favorable to the customer for the applicable electric service requested. The selection will be based on the prospective customer’s statement as to the class of electric service desired, the amount and manner of use, and any other pertinent information. Cooperative shall not be liable for any errors, in connection herewith.

12.2.2. If, for any cause, electric service is supplied under a rate schedule not applicable to the class of electric service taken, on discovery of the error, all bills rendered under the incorrect rate schedule shall be recalculated in accordance with the lowest applicable rate schedule; and any excess paid shall be refunded by Cooperative or any amount due shall be paid by customer as the case may be.

12.2.3. A customer being billed under one or more optional schedules applicable to his class of electric service may elect to be billed on any other applicable schedule by notifying Cooperative in writing. Cooperative will bill customer under such elected schedule from and after the date of the next meter reading. However, a customer having made such change of schedule may not make another change within the next twelve months.


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Replacing Sheet No.




Title: STOPPING SERVICE BY CONSUMER PSC File Mark Only

13. STOPPING SERVICE BY CONSUMER

13.1. CUSTOMER’S RIGHT TO STOP SERVICE

13.1.1. A customer who wants to stop service must provide the Cooperative with at least five (5) days notice that electric service will be no longer required at the location. The minimum five day notice begins:

A. On the day the customer telephones the utility or personally informs the appropriate employee at the local office; or,

B. Three (3) days after the customer mails the notice to the Cooperative.

13.1.2. If the customer has signed a written contract for a term of years under an Agreement for Electric Service with the Cooperative, the customer may stop service only under the terms and conditions as set forth in the Agreement for Electric Service.


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replacing 1st first electric cooperative corporation ark

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