ARKANSAS PUBLIC SERVICE COMTvlTSSION

ARKANSAS PUBLIC SERVICE COMTvlTSSION

On'einal Sheet No. TC-I

Replacing Shtet No.

Cam11 Elcctric Coonerative Cornoration Name of Company

Kind of Sentice: EIectic

TABLE OF CONTENTS

Class of Service

Au

AI1

All

PART r. GENERAL ~ O R M A T I O I Y Schedule Name

1. UtiIity Information

2. TariffPomat

3. Definitions

F!!,EC

PSC File Mark w

Sheet Number

I

2

3

WSPACEFORPSCUSEONLY

ARKANSAS PUBLIC SERVICE COMMISSION APPROVED

I

Origind Sheet NO. TC-2

Replacing Sheet No.

Cam11 Electric Cmuerative Corporation Name of Company

Kina of Sentice: flectric

TABLE OF CONTENTS

Class ofservice

Au

PARTE EXEMFIIONS Schedule Name

1. Current Status

Sheet Number

5

IXB SPACE FOR PSC USE ONLY

ARUANSAS PUBLIC SERVICE COMMISSION APPROVED

THIS SPACE FOR PSC USE ONLY

ARKANSAS PUBLIC SERVICE COMMISSION

12th Revised Sheet No. TC-3

Replacing 11th Revised Sheet No. TC-3

Carroll Electric Cooperative CorporationName of Company

Kind of Service: Electric

Title: TABLE OF CONTENTSPSC File Mark Only

PART III. RATE SCHEDULES

Class of Service Schedule Name Sheet Number

Single Phase 1. Single Phase Service Under 100 kVA 6

Three Phase 2. Three Phase Service Under 100 kVA 8

Commercial 3. Large Power Service (Under 250 kW) 11

Commercial 4. Large Power Service (Over 250 kW) 15

Lighting 5. Security and Street Lighting Service 19

6. (Reserved for Future Use) 23

All 7. Cost of Energy Adjustment Clause Rider No. 1 26

All 8. Energy Cost Adjustment Report Form 28

All 9. Tax Adjustment Clause Rider No. 2 29

All 10. Cost of Debt Adjustment Clause Rider No. 3 30

All 11. Cost of Debt Adjustment Form 31

All 12. Terms of Payment Clause Rider No.4 32

All 13. Municipal Tax Clause 33

Commercial/Industrial 14. Optional Commercial (Over 50 kW) 36



As Applicable 17. Extension of Facilities 43

Industrial 18. Special Contract – Bekaert Corporation 51

All 19. Charges Related to Customer Activity 61

Single Phase 21. Transient Voltage Surge Suppression Service 64.2

22. (Reserved for Future Use) 64.4



All 25. Net Metering 64.11

APSC FILED Time: 5/31/2019 3:33:57 PM: Recvd 5/31/2019 3:33:00 PM: Docket 87-159-U-Doc. 246

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2nd Revised Sheet No. TC-4

Replacing 1st Revised Sheet No. TC-4


Kind of Service: Electric Class of Service: All

Title: TABLE OF CONTENTSPSC File Mark Only

PART III. RATE SCHEDULES

Class of Service Schedule Name Sheet

Number

Residential 1. Levelized Billing Plan 65

Residential 2. Provisions for Landlords and Tenants 67

Residential 3. Extended Due Date Plan 68

Residential 4. Extended Absence Payment Plan 71

All 5. Meter Testing Programs 72

All 6. Standard Nominal Voltages 75

All 7. Supplying and Taking of Electric Service 76

All 8. Customer’s Rights and Responsibilities 79

All 9. Billing 82

All 10. Pole Identification 84

All 11. Voltage Verification Plan 85

All 12. Emergency Load Conservation and CurtailmentPlan

86


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, ,I; . ::v. LCm.

': I : I*i.U'1. " d l .I

; 1 1' I v:,L:rv

I I - > ARKANSAS PUBLIC SERVICE COMMISSION

1st Rewised Sheet No. 1

Rep I acing Original Sheet No. 1

Carroll Electric Cooperative Corporation -: \LEQ

Title: UTILITY INFORMATION

Kind of Service: Electtie Class of Seruice: All

PSC FJ% w my

Part I. General Information Schedule No.: I

I. UTILITY INFORMATION

Utility Official: Rob Buaz PresidentlCEO

Telephone Number: 870423-21 61 870-4234 5 ( f a x )

Mailing Address: CARROLL ELECTRIC COOPERATIVE CORP. 920 Hwy. 62 Spur (72616-4527) P.0. BOX 4000 Benyville, AR 726164000

. \ * I .

THE SPACE FOR PSC USE ONLY I ..It

ARKANSAS PU8LlC SERVICE CC~M?A!SSION APPROVED

Oriainal Sheet No. 2

TitIe: TARDF FORMAT

1 JUlI 6

psc File Marl: only

Replacing Sheet No.

Carroll Elecrric Cooperotive Cornoration Name of Company

Kind of Senice: Electric. Clnss of Servicc: All

Part 1; General Information ScheduIe No.: _2

2. T A R E F F O R i i T

2.1. TAREF SYMBOLS

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

Svmbol Exdanation

(DR) Discontinued Rate

(AT) Additions to Text

(RT) Removal of Text

(CP) Change in Practice

INRI New Rate

(C) A Correction

W) Move of Text


ARKANSAS PUBLIC SERVlCE COMMISSION APPROVED



1st Revised Sheet No. 3 Replacing Original Sheet No. Carroll Electric Cooperative Corporation Kind of Service: Electric Class of Service: All Part I. General Information Schedule No.: 3 Title: DEFINITIONS PSC File Mark Only

3. DEFINITIONS 3.1 . Carroll Electric Cooperative Corporation offers the following definitions for words and

expressions used in these tariffs unless otherwise indicated in a specific tariff

Customer's Installation In general, all electrical circuits and facilities of any kind or nature on the customer's side of the point of delivery (except the Cooperative's meter installations).

Cooperative

Carroll Electric Cooperative Corporation.

Cooperative Extension to the Customer Any branch from or continuation of an existing line to the point of delivery to the customer, including increases in capacity of any of the 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.

Developer

A person, partnership, association, corporation or governmental agency that owns or promotes a tract of land.

(CT)

Meter

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.

APSC FILED Time: 1/25/2013 11:06:25 AM: Recvd 1/25/2013 11:05:51 AM: Docket 87-159-u-Doc. 146

krhude

New Stamp

Orim'nal Sheet No. L

Rcplacinp Shcct No.,

Cnrmll Electric Caonerntive Comaration N m e of Company

Kind of Service: Electric Class of Service: ,411

Part 1. General Information Schedule No.: 3

Title: DE??"IONS

JUH ti l l l a AH '95

Month An intervaI of approximately 30 days.

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

Notice A written notification deIivered 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 mailing, except notice of suspension or termination of service by the Cooperative or the customer shall be three (3) days after the notice is posted in the United States mail.

Point of Delivery The point at which the Cooperative's ownership of facilities terminates and at which the customerls ownership of facilities begins, or as othenvise defined and asreed upon in an ageement for service.

Sewice Drop The wires owned by the Cooperative which connect the Cooperative's distribution facilities to the customer's service terminals.

Subdivision Any tract of land which is divided into lots for the construction of new single-family residences.

~ ~~



I jUN8 '95 ORDER2 ' 9 5 -0 6 6 - T F

ARKANSAS PUBLlC SERVICE COMMISSION

PSt Revised SheelNo. 5

Repladng OriCliiIa! SheelNo. 5

CarroII Electric Cooperative Corporation Name of Company

Kind of Sewlca' Efectric Class of Sem'ce: All

Part 11. Exempfion Schedule No. I

Title: CURRENT STATUS

I. CURRENT STATUS

1J Gcncml Senticc Rule 3.04(A)(9) -Refusing Scntice

By Order dated August 4,2009, in docket number 09-045-U, CarrolI EIectn'c Coopemlive Corporation received an exemption from Rule 3.04(A)(9) ofthe Commission's General Service Rules to accept ody the following foms of identification when opening an account for an applicant for utility service:

(a} Driver's Iicense or state-issued ID card; (b) Military ID;

(d) 1-55 1 card (commonly known as a "green card"'); (e) Certified b i certificate; or (0 Any other evidence which would, in the opinion of the utility, establish idenlily.

(c} Passport

MIS SPACE FOR PSC USE ONLY




9th Revised Sheet No. 6

Replacing 8th Revised Sheet No. 6

Carroll Electric Cooperative Corporation Name of Company

Kind of Service: Electric Class of Service: Single Phase

Part III. Rate Schedule No. 1

Title: SINGLE PHASE SERVICE UNDER 100 kW PSC File Mark Only

1. SINGLE PHASE SERVICE UNDER 100 KW

1.1. APPLICABLE SERVICE AREA

1.1.1. All allocated territory.

1.2. CUSTOMER CLASS

1.2.1. Single phase service under 100 kW.

1.3. AVAILABILITY OF SERVICE

1.3.1. Available for single phase service under 100 kW of capacity subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission (Commission) and to the rules of the Commission. The capacity of individual motors served under this schedule shall not exceed ten horsepower (10 H.P.).

1.4. CHARACTER OF SERVICE

1.4.1. Service shall be single phase, 60 hertz, furnished at standard secondary voltages, unless otherwise stated in accordance with approved schedules.

1.5. NET MONTHLY RATE

1.5.1. Year 1 Year 2 Year 3 Year 4 Year 5

Winter Rate: Availability Charge @ $13.40 $15.02 $16.64 $18.26 $19.88 0-500 kWh @ 9.050¢ /kWh 9.008¢ /kWh 8.967¢ /kWh 8.927¢ /kWh 8.888¢ /kWh Excess kWh @ 8.191¢ /kWh 8.149¢ /kWh 8.108¢ /kWh 8.068¢ /kWh 8.029¢ /kWh

Summer Rate: Availability Charge @ $13.40 $15.02 $16.64 $18.26 $19.88 All kWh @ 9.050¢ /kWh 9.008¢ /kWh 8.967¢ /kWh 8.927¢ /kWh 8.888¢ /kWh

Year 1 shall commence on October 1, 2019 and will continue for a period equal to twelve months. Year 2 will commence immediately following Year 1 and continue for twelve months. Years 3, 4 and 5 will likewise follow. The charges for later periods shall equal Year 5.

The phase in rates shown above are subject to change if, at any time, the rate under which the Cooperative purchases electric service at wholesale is modified in any way. The Cooperative shall make corresponding modifications in the rate for service herein.


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Kind of Service: Electric Class of Service: Single Phase


Title: SINGLE PHASE SERVICE UNDER 100 kW PSC File Mark Only

1.5.2. eBundle Credit

Each member who participates in both electronic billing (eBilling) and electronic draft (eDraft) shall receive an “eBundle discount” in the form of a $1.00 monthly billing credit.

1.6. MINIMUM CHARGES

1.6.1. The minimum monthly charge under this rate will be $13.40 for Year 1, $15.02 for Year 2, $16.64 for Year 3, $18.26 for Year 4 and $19.88 for Year 5 and beyond.

1.7. SPECIAL CONDITIONS

1.7.1. Winter usage shall pertain to the usage months of October through April. Summer usage shall pertain to the usage months of May through September.

1.7.2. Temporary service that is not permanent as defined in Rate Schedule 17 shall be supplied in accordance with the foregoing rate except the customer shall pay in addition to the foregoing charges, the total cost of connecting and disconnecting service, less the value of materials returned to stock. A deposit in advance may be required of the full amount of the estimated bill for service, including the cost of connection and disconnection.

1.8. ADJUSTMENT RIDERS

1.8.1. Energy Adjustment: The amount of the bill shall be adjusted as provided in Rate Schedule No. 7, Cost of Energy Adjustment Clause Rider No. 1.

1.8.2. Tax Adjustment: The amount of the bill shall be adjusted as provided in Rate Schedule No. 9, Tax Adjustment Clause Rider No. 2.

1.8.3. Cost of Debt Adjustment: The amount of the bill shall be adjusted as provided in Rate Schedule No. 10, Cost of Debt Adjustment Clause Rider No. 3.

1.8.4. Terms of Payment: The above rates are net. Terms of payment shall be per Rate Schedule No. 12, Terms of Payment Clause Rider No. 4.


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Kind of Service: Electric Class of Service: Three Phase


Title: THREE PHASE SERVICE UNDER 100 kW PSC File Mark Only

2. THREE PHASE SERVICE UNDER 100 KW



2.2. CUSTOMER CLASS

2.2.1. Three phase service under 100 kW.


2.3.1. Available for three phase service under 100 kW of capacity, subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission and to the rules of the Commission. Motors having a rated capacity in excess of ten horsepower must be three phase.


2.4.1. Service shall be three phase from existing secondaries, 60 hertz, furnished at standard secondary voltages, unless otherwise stated in accordance with approved schedules.


2.5.1.. Year 1 Year 2 Year 3 Year 4 Year 5

Winter Rate: Availability Charge @ $25.73 $29.89 $34.05 $38.21 $42.37 0-500 kWh @ 9.050¢ /kWh 9.008¢ /kWh 8.967¢ /kWh 8.927¢ /kWh 8.888¢ /kWh Excess kWh @ 8.191¢ /kWh 8.149¢ /kWh 8.108¢ /kWh 8.068¢ /kWh 8.029¢ /kWh

Summer Rate: Availability Charge @ $25.73 $29.89 $34.05 $38.21 $42.37 All kWh @ 9.050¢ /kWh 9.008¢ /kWh 8.967¢ /kWh 8.927¢ /kWh 8.888¢ /kWh

Year 1 shall commence on October 1, 2019 and will continue for a period equal to twelve months. Year 2 will commence immediately following Year 1 and continue for twelve months. Years 3, 4 and 5 will likewise follow. The charges for later periods shall equal Year 5.

The phase in rates shown above are subject to change if, at any time, the rate under which the Cooperative purchases electric service at wholesale is modified in any way. The Cooperative shall make corresponding modifications in the rate for service herein.


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Kind of Service: Electric Class of Service: Three Phase


Title: THREE PHASE SERVICE UNDER 100 kW PSC File Mark Only

2.5.2 eBundle Credit



2.6.1. The minimum monthly charge under this rate shall be $25.73 for Year 1, $29.89 for Year 2, $34.05 for Year 3, $38.21 for Year 4, and $42.37 for Year 5 and beyond. where 10 kVA or less of transformer capacity is required. For members requiring more than 10 kVA of transformer capacity, the minimum monthly charge shall be increased at the rate of $0.75 for each additional kVA or fraction thereof required.



2.7.2 .

Temporary service that is not permanent as defined in Rate Schedule 17 shall be supplied in accordance with the foregoing rate except the customer shall pay in addition to the foregoing charges, the total cost of connecting and disconnecting service, less the value of materials returned to stock. A deposit in advance may be required of the full amount of the estimated bill for service, including the cost of connection and disconnection.







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ARKANSAS PUBLIC SERVICE COMMISSION Roy I 9 2 115 P i '00

I s t s d Sheet No. 10

Replacing Oriainal SheetNo. 10

Carroll Electric COOP erative Cormration Name of Company

Kind of Service: Electric Class of Service:

Part Ill. Rate Schedule No.

Title:

RESERVEDFORFUTUREUSE

TH18 SPACEFOFl FSC USE ONLY

- ARKANSAS PUBLIC SERVICE COMMISSION APPROVED






Kind of Service: Electric Class of Service: Commercial


Title: LARGE POWER SERVICE (GREATER THAN 100 kW AND

UNDER 250 KW)

PSC File Mark Only

3. LARGE POWER SERVICE (GREATER THAN 100 KW AND UNDER 250 KW)



3.2. CUSTOMER CLASS

3.2.1. Customers with a demand greater than 100 kW and under 250 kW.


3.3.1. Available for service for all types of uses greater than 100 kW and under 250 kW demand, subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission and the rules of the Commission.


3.4.1. Service shall be single phase or three phase if available from existing secondaries, 60 hertz, furnished at standard voltages, unless otherwise stated in accordance with approved schedules.


3.5.1.

Winter Rate: Availability Charge @ $84.80 All kW Demand @ $7.40 /kW All kWh @ 5.443¢ /kWh

Summer Rate: Availability Charge @ $84.80 All kW Demand @ $9.84 /kW All kWh @ 5.443¢ /kWh

3.5.2. Determination of Billing Demand

The billing demand shall be the maximum kilowatt demand established by the customer for any period of 15 consecutive minutes during the month for which the bill is rendered, as indicated or recorded by a demand meter and adjusted for power factor.


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Replacing 3rd Revised Sheet No. 12




Title: LARGE POWER SERVICE (GREATER THAN 100 kW AND

UNDER 250 KW)

PSC File Mark Only

3.5.3. Power Factor Adjustment

A. The customer agrees to maintain unity power factor as nearly as practicable. Demand charges will be adjusted for customers with 50 kW or more of measured demand to correct for average power factors lower than 98 percent (98%), and may be so adjusted for other customers if and when Cooperative deems necessary. Such adjustments will be made by increasing the measured demand one percent (1%) for each one percent (1%) by which the average power factor is less than 98 percent (98%) lagging.




3.6.1. The minimum monthly charge under this rate shall be the highest one of the following charges as determined for each applicable customer:

The Service Availability Charge; or

The minimum monthly charge specified in the contract for service; or

A charge of $0.75 per kVA of installed transformer capacity.



3.7.2. Conditions of Service

A. Motors having a rated capacity in excess of ten horsepower (10 H.P.) must be three phase.


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Title: LARGE POWER SERVICE (GREATER THAN 100 KW AND

UNDER 250 KW)

PSC File Mark Only

B. All wiring, pole lines and other electrical equipment beyond the metering point, shall be considered the distribution system of the customer and shall be furnished and maintained by the customer.

C. If service is furnished at primary distribution voltage, a discount of four percent (4%) shall apply to the demand and energy charges, and if the minimum charge is based on transformer capacity, a discount of four percent (4%) shall also apply to the minimum charge. The Cooperative shall have the option of metering at secondary voltage and subtracting the estimated transformer losses from the metered kilowatt hours and kilowatt demand.







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ARKANSAS PUBLIC SERVICE COMMISSION . 1 st Revised Sheet No. 74

Reptacing Oriainal Sheet No. 14

Carroll Electric Cooperative Comoration Name of Company


Part 111. Rate Schedule No.

Title:









Title: LARGE POWER SERVICE (OVER 250 KW) PSC File Mark Only

4. LARGE POWER SERVICE (OVER 250 KW)



4.2. CUSTOMER CLASS

4.2.1. Commercial customers with a demand in excess of 250 kW.


4.3.1. Available for commercial service for all types of uses in excess of 250 kW demand, subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission and the rules of the Commission.


4.4.1. Service shall be single phase or three phase if available from existing secondaries, 60 hertz, furnished at standard voltages, unless otherwise stated in accordance with approved schedules.


4.5.1

Winter Rate: Availability Charge @ $127.20 All kW Demand @ $9.90 /kW All kWh @ 4.790¢ /kWh

Summer Rate: Availability Charge @ $127.20 All kW Demand @ $12.81 /kW All kWh @ 4.790¢ /kWh

4.5.2. Determination of Billing Demand

The billing demand shall be the maximum kilowatt demand established by the customer for any period of 15 consecutive minutes during the month for which the bill is rendered, as indicated or recorded by a demand meter and adjusted for power factor.


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4.5.3. Power Factor Adjustment

A. The customer agrees to maintain unity power factor as nearly as practicable. Demand charges will be adjusted for customers with 50 kW or more of measured demand to correct for average power factors lower than 98 percent (98%), and may be so adjusted for other customers if and when the Cooperative deems necessary. Such adjustments will be made by increasing the measured demand 1% for each 1% by which the average power factor is less than 98% lagging.




4.6.1. The minimum monthly charge under this rate shall be the highest one of the following charges as determined for each applicable customer:

The Service Availability Charge; or

The minimum monthly charge specified in the contract for service; or

A charge of $0.75 per kVA of installed transformer capacity.



4.7.2. Conditions of Service

A. Motors having a rated capacity in excess of ten horsepower (10 H.P.) must be three phase.


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B. All wiring, pole lines and other electrical equipment beyond the metering point, shall be considered the distribution system of the customer and shall be furnished and maintained by the customer.

C. If service is furnished at primary distribution voltage, a discount of four percent (4%) shall apply to the demand and energy charges, and if the minimum charge is based on transformer capacity, a discount of four percent (4%) shall also apply to the minimum charge. The Cooperative shall have the option of metering at secondary voltage and subtracting the estimated transformer losses from the metered kilowatt hours and kilowatt demand.


4.8.1. Energy Adjustment: The amount of the bill shall adjusted as provided in Rate Schedule No. 7, Cost of Energy Adjustment Clause Rider No. 1.





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No1 1 st Revised Sheet No. 18

Replacing Oriainat Sheet No. 18

1 Name of Company

9 2 4s PI! '00

FILED Kind of Service: Electric Class of Service:


Title: PSC Ma& On*

RESERVED FOR FUTURE USE







Kind of Service: Electric Class of Service: Lighting


Title: STREET LIGHTING SERVICE PSC File Mark Only

5. STREET LIGHTING SERVICE



5.2. CUSTOMER CLASS

5.2.1. Outdoor lighting


5.3.1. Available to customers for outdoor lighting, subject to the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission and to the rules of the Commission.

5.4. INSTALLATION OF EQUIPMENT

5.4.1. A lighting unit will be furnished and installed on an existing Cooperative pole suitable to both the customer and the Cooperative. The Cooperative will make all necessary electrical connections and will furnish electricity to the unit, which shall be controlled by a photo cell or other programmable technology.


5.5.1 Unshielded lighting units on Wood Poles with Overhead Brackets

Lamp Size Rate 70 W LED @ $10.30 175 W MVL*; 100 W HPS* @ $7.79 250 W MVL*; 150 W HPS* @ $10.22 400 W MVL or MH*; 250 W HPS*; 129 W LED @ $15.03 1000 W MVL* or MH*; 266 W LED @ $34.29

* Lamps no longer available for new installation or replacement.


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Kind of Service: Electric Class of Service: Lighting


Title: STREET LIGHTING SERVICE PSC File Mark Only


5.6.1. Street lighting equipment including lamps, fixtures, controls and the necessary street lighting circuits, transformers and additional guys and fittings will be furnished and maintained by the Cooperative.

5.6.2. This schedule applies to either multiple or series street lighting circuits. The Cooperative will determine the type of circuit.

5.6.3. Mercury vapor, high pressure sodium, and Metal Halide lamps are not available for new installations or for lamp replacements.

5.7. SHIELDED LIGHTING OPTION

5.7.1 A consumer requesting a shielded lighting alternative will pay the monthly rate for the corresponding lamp fixture as listed in paragraph 5.5.1., 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.






APSC FILED Time: 4/16/2018 3:21:13 PM: Recvd 4/16/2018 3:11:31 PM: Docket 18-023-TF-Doc. 1

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23-T

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No.

- 3

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



Title:

Kind of Service: Electric Class of Service: Liqhtina


LPR 16 9 39 \[ '07

?!LED

PSC File W OrSV

I APFROVEP

JUN 2 2 2007ORDER 3 0 7 0 4 2 ' T F

ARKANSAS PUBLIC SERVICE COMMISSION I Mol g 2 45 PM "I

Title:

1 st Revised SheetNo. 22 ,

Replacing Oriainat SheetNo. 22

PSC Fila MMk Only

Carroll Electric Cooperative Corrroration Name of Company


Part Ill. Rate Schedule No.


ARKANSAS PUBLlC SERVICE COMMISSION APPROVED

DEC 7 ZOO0 ORDER t 2 9 9 - 2 5 6 U








Title: PSC File Mark Only



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2nd Revised Sheet No. 25

Replacing 1st Revised Sheet No. 25







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Title: COST OF ENERGY ADJUSTMENT CLAUSE - Rider No. 1 PSC File Mark Only

7. COST OF ENERGY ADJUSTMENT CLAUSE - RIDER NO. 1



7.2. CUSTOMER CLASS

7.2.1. All classes.

7.3. CHARACTER OF CLAUSE

7.3.1. If the cost per kilowatt-hour of energy to the Cooperative changes from the base cost of $0.039960 per kWh sold embedded in the Cooperative's rate schedules, 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 energy charges billed the Cooperative by its suppliers, the fuel cost adjustments billed the Cooperative by its suppliers, 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.

7.3.2. Any Cost of Energy Adjustment shall be reported to the Staff on the form designated by the Commission prior to implementation or as soon as possible thereafter.

7.3.3. Per existing contract, the base cost of energy for Rate 18-Bekaert Corporation is $0.031195 per kWh sold. The Cooperative shall bill Bekaert on separate billing lines for the applicable demand and energy charges for the TO/RTO Rider charge billed the Cooperative by its suppliers.


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FORM 94-1.27S







Title: COST OF ENERGY ADJUSTMENT CLAUSE - Rider No. 1

PSC File Mark Only


7.4.1. Adjustments for Lighting (Rate Schedule 5) shall be based on:

Lamp Size kWh per Month

70 watts 29 100 watts 41129 watts 53 150 watts 62 175 watts 72 250 watts 103 266 watts 110 400 watts 165 1000 watts 411


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Title: ENERGY COST ADJUSTMENT REPORT FORM PSC File Mark Only

CARROLL ELECTRIC COOPERATIVE CORPORATION Box 4000 - Berryville, AR 72616-4000

Energy Cost Adjustment Report Form

Applicable to Customers billing for month of For Sales during the month of

Section I Net of

Bekaert Bekaert

1. kWh Purchased kWh kWh

2. Losses – Actual / Estimated (Circle one) % kWh kWh

3. Cooperative Use kWh kWh

4. kWh Sold – Actual / Estimated (Circle one) kWh kWh

5. kWh Sold Prior Eleven Months – Actual kWh

6. Line 4 + Line 5 kWh

7. Wholesale Charges for Energy and Fuel Cost from AECC $ $ (Twelve Months Year to Date)

8. Adjustments from previous twelve months over/under

Collections (circle one and define in Section II

if applicable) $ $

9. Less: Base cost of energy embedded in rates

$0.039960/kWh x 12mo YTD Form 7 kWh Sales Net System kWh $

$0.031195/kWh x Current mo Form 7 kWh Sales Bekaert kWh $

10. Adjusted Wholesale Energy Charges

[(Line 7 +/- line 8 - Line 9)] $ $

11. Cost of Energy Adjustment Rate $ /kWh $ /kWh

(Line 10 / Line 6)


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1st Revised Sheet No. 28.1

Replacing Original Sheet No. 28.1




Title: ENERGY COST ADJUSTMENT REPORT FORM PSC File Mark Only

Section II*

$ - ($ /kwh x kWh = (Line 13 prior

Month) (Line 11 prior Month) (12 mo YTD Actual kWh Sold

prior month)

*Section II is applicable only when the Cooperative is using estimated sales. Actual kWh sold prior month, per sales report.

Note: All 12 months prior calculations shown above will be phased in monthly from the month following acceptance of this change by the Arkansas Public Service Commission for the following year and remain 12 month calculations thereafter.

Person Completing Report:

Telephone Number:

Section I continued…

12. TO/RTO Rider adjustment:

a. TO/RTO Rider Charges (Twelve mo YTD Net of Bekaert) $ /line 6 $ /kWh b. TO/RTO Rider Charges (Current mo Bekaert Energy Only) $ /line 4 $ /kWh

13. Total Energy Adjustment $ /kWh $ /kWh


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Oridind ShectNo. 29

Replacing Sheet No.

Carroll Elmtic Caoaerative Cornomtion Nnme of Cornpnny

Kind of Service: Electric Ciass of Service: &

Part ID. Rrtte Schedule No. 9

6 UH ti Ii 18 AH ‘$5

9.

9.1.

9.2.

9.3.

TAX ,LU33USmm,NT CLAUSE - RIDER NO. 2

APPLICABLE SERVICE AREA

9.1.1. AI1 allocated territory

CUSTOMER CLASS

9.2.1. AI1 classes

C W C T E R OF CLAUSE

9.3.1. 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 shaII be recovered from those customers within jurisdictional boundaries of the taxing bodies and shaH be referenced on the face of the bill. Tax adjustments shall be coIIected in the same manner in which ta.ues are incurred.

1

‘ M I S SPACLFORFSC USE ONLY

A R M S A S PUBtlC SERVICE COMMISSION APPROVED

JUN8 ‘95ORDER2 ’ 95-06 6 - T F



3rd Revised Sheet No. 30

Replacing 2nd Revised Sheet No. 30




Title: COST OF DEBT ADJUSTMENT CLAUSE - Rider No. 3 PSC File Mark Only

10. COST OF DEBT ADJUSTMENT CLAUSE - RIDER NO. 3



10.2. CUSTOMER CLASS

10.2.1. All classes.

10.3. CHARACTER OF CLAUSE

10.3.1. If the embedded cost of debt to the Arkansas jurisdiction of the Cooperative changes from the $8,960,417 embedded in the 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 Arkansas jurisdiction kilowatt-hours for the billing quarter and a OTIER coverage of 1.80. Any over or under collection shall be carried over to the next quarter's factor determination.

10.3.2. The Cost of Debt factor calculated on Rate Schedule 11-Line 20 shall be increased by $0.00612/kWh sold in determining the Cost of Debt factor to apply to Rate 18-Bekaert Corporation.


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Carroll Electric Cooperative Corporation

Name of Company



Title: COST OF DEBT ADJUSTMENT FORM PSC File Mark Only

11. COST OF DEBT ADJUSTMENT FORM

COOPERATIVE: Carroll Electric Cooperative Corporation

ADDRESS: P.O. Box 4000, Berryville, AR 72616-4000

QUARTERLY COST OF DEBT ADJUSTMENT REPORT

1. Date of 2. Adjustment Rate to Apply Report to Customer's Bills dated

3. Calculations Based on Cost of Debt for Quarter

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

(5) (6) (7) (8) (9) Type of Outstanding Annual Annual Cost of Debt Paid Debt Debt Balance Rate Cost this Quarter

$ % $ $ $ % $ $ $ % $ $ $ % $ $ $ % $ $ Less Amortization of Fees Per RUS to CFC Debt Conversion $ $ Less CFC Performance Discount $ $ Less CFC Collateral Discount $ $ Less CFC Volume Discount $ $ Plus CFC Forward Rate Lock Premium $ $

Totals $ $ $

10.Total Cost of Debt Paid this Quarter (Column 9 total) ............................................ $

11.Times Arkansas Jurisdiction Proportion of .9003. . . . . . . . . . . . . . . . . . . . . $

12.Cost of Debt in Base Rates $8,960,417 x (a/365). . . . . . . . . . . . . . . . . . . . $

13.Cost of Debt Adjustment this Quarter (Line 11- Line 12) $

14.(Line 13) x RUS-OTIER Level of 1.80 .................................................................... $

15.Cost of Debt Adjustment Authorized for Collection prior to Quarter ...................... $

16.Less Cost of Debt Adjustment Collected prior Quarter (b) ..................................... $

17.Over or Undercollected Cost of Debt Adjustment previously Authorized ............... $

18.Total Cost of Debt Adjustment Authorized for Collection this Quarter. (Line 14 +/- Line 17) $

19.Estimated kWh Sales for Billing Quarter (Arkansas Jurisdiction) kWh

20.Cost of Debt Adj. Rate for this Quarter (Line 18 / Line 19) (Net System) $ /kWh

Rate 18 Bekaert Corporation Only 21.Rate 18 Cost of Debt Adjustment adder $ 0.00612 /kWh

22.Cost of Debt Adj. Rate for this Quarter (Line 20 + Line 21) (Rate 18) $ /kWh

Notes: (a) Number of days in quarter in which adjustment is to occur. (b) Cost of Debt collected in prior quarter (Line 16) shall be based on factor shown on Line 20 only

and exclusive of the $0.00612 adder of Rate 18

PERSON COMPLETING REPORT TELEPHONE NUMBER


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ARKANSAS PUBLIC SERVICE COM"ITSS1ON

I OriEiinnl SheetNo. 32

Replacing Shmt NO.

Cam11 Electric Cooperative Carparation Name of Company

Kind of &.Nice: Electric Class of Service: All

Part m. Rate ScheduIe No. 12

Title: TERMS OFPAYMENT CLAUSE- RidcrNo.J

12. TERMS OF PAYMENT CLAUSE - RIDER NO. 4

12. I. APPLTCABLE SERVICE AREA

13- 1.1. AH allocated territory

12.2. CUSTOMER CLASS

12.2.1. AII classes

22.3. TERMS

12.3.1. All bills are due and payabIe within twenty-hvo (22) calendar days after the date the bill is mailed. Any current bill not paid within 22 days after the date the bdI is mailed will be assessed a Iate charge totaling ten percent (10%) of the first $30 and two percent (2%) of the biII amount over $30.

m S SPACE FOR PSCUSE ONLY


JUN8 '95ORDm2 ' 9 5 - 0 6 6 - T F

1 st Revised SheetNo. 33

Replacing Original SheetNo. 33

CarrolI Electric Cooperative Corporation Name of Company

Kind of Servie: EIectn-e Class of Service: All

Part 111. Rate ScheduIe No. 13

I " I '

I*.' I I, E 0

Trtle: MUNICIPAL TAX CLAUSE P S G F h J s C d y 1 13. MUNICIPAL TAX CLAUSE


13.1.1. All allocated territory, more specifically accounts physicalIy located within ctty limits of a municipality that imposes a franchise tax upon the Cooperative. (CT)

13.2. CUSTOMER CUSS

13.2.1. All classes

13.3. TERMS

j3.3.1. The municipal tax rate shall be subject to an increase or decrease in proportion to the amount of new or revised excise, license, privilege or franchise taxes (except ad valorem and income taxes) which the Cooperative may hereafter have to pay, which are levied or imposed, or increased, or decreased by laws or ordinances. Such adjustments shall be recovered only from those customers within jurisdictional boundaries of the taxing bodies and shall be referenced on the face of the bill. Tax adjustments shalI be collected monthly as a percentage of the total applicable revenue applied to each customer's reguIar bill and the total amount shown as a separate line item on the bill.

3 0 7


APSC FILED Time: 4/8/2019 3:42:43 PM: Recvd 4/8/2019 3:32:41 PM: Docket 19-016-TF-Doc. 1 ARKANSAS PUBLIC SERVICE COMMISSION






Title: MUNICIPAL TAX CLAUSE PSC File Mark Only

13.4. SCHEDULE OF TAX RATE BY CITY

City Tax as a Percent of

Gross Revenue

Avoca 4.25% Bella Vista 4.25% Bethel Heights 2.00% Blue Eye, AR 2.00% Blue Eye, MO 4.00% (excludes industrial revenue) Cave Springs 3.00% Centerton 4.00% Decatur 4.00% Elm Springs 4.25% Eureka Springs 5.00% Garfield 2.00% Gravette 4.00% Highfill 1.00% Huntsville 5.00% Jasper 3.00% Little Flock 4.00% (excludes industrial revenue) Lowell 4.00% (excludes industrial revenue) Pea Ridge 4.00% Rogers 4.00% (excludes industrial revenue) Springdale 4.00% (excludes industrial revenue)

13.5. SCHEDULE OF INDUSTRIAL TAX RATE BY CITY

13.5.1. The following cities apply a tax for industrial revenue at a different rate than those listed above.

City

Industrial Tax as a Percent of

Gross Revenue

Blue Eye, MO 1.00% Little Flock, AR 1.00% Lowell, AR 1.00% Rogers, AR 1.00% Springdale, AR 1.00%

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1 st Revised SheetNo. 35

Replacing Original SheetNo. 35

Carroll Electric Cooperative Corporation ,: !. 1 ED I b-•

Name of Company


Part 111. Rate Schedule No. 13

Ttle: PscFkMsrltorltj



ARKANSAS PUBLIC SERVICE COMMtSSlON APPROVED

JUN 22 20070RDER 3 0 7 042'TF






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

Part III. Rate Schedule No.: 14

Title: OPTIONAL COMMERCIAL (OVER 50 kW) PSC File Mark Only

14. OPTIONAL COMMERCIAL (OVER 50 kW)

14.1. AVAILABILITY

14.1.1. At a point on existing facilities having adequate capacity and suitable voltage for delivery of service from the Cooperative's interconnected distribution system for all uses requiring more than 50 kW of measured demand, subject to the Rate Schedules and Policy Schedules of the Cooperative as filed with the Arkansas Public Service Commission.

14.2. APPLICATION

14.2.1. To all electric service required by the customer on the premises, when supplied at one point of delivery and measured through one kilowatt hour meter.

14.3. TYPE OF SERVICE

14.3.1. Single and three phase, 60 hertz at the Cooperative's standard voltage. Motors having a rated capacity in excess of ten horsepower must be three phase.


14.4.1. Rate: Availability Charge @ $127.20 Coincident kW Demand @ $10.44 /kW All kW Billing Demand @ $2.00 /kW All kWh @ 4.887¢ /kWh



14.5. MONTHLY BILLING DEMAND

14.5.1. The Monthly Billing Demand shall be the maximum 60 minute demand, as shown by or computed from, the reading of the Cooperative's demand meter during the month but not less than 50 kW.

14.6. COINCIDENT DEMAND

14.6.1. The Coincident Demand shall be the average of the customer's four 60 minute demands established during the most recent usage months of June, July, August, and September which are coincident with the Cooperative's wholesale power supplier's peak.


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14.7. POWER FACTOR ADJUSTMENT

14.7.1. The customer agrees to maintain unity power factor as nearly as practicable. Monthly billing demand and coincident demand charges will be adjusted to correct for average power factors lower than 98 percent (98%). Such adjustments will be made by increasing the measured demand one percent (1%) for each one percent (1%) by which the average power factor is less than 98 percent (98%) lagging.

14.8. MINIMUM

14.8.1. The minimum monthly bill shall be the highest of the following:

A. The Service Availability Charge B. Demand Charge (but not less than the monthly billing demand charge for 50 kW) C. $0.75/kVA of installed transformer capacity D. Minimum monthly charge specified in contract






14.10. PRIMARY SERVICE

14.10.1. If service is furnished at primary distribution voltage, a discount of four (4%) percent shall apply to the demand and energy charges.


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FORM 94-2.3S

14.11. CONTRACT PERIOD

14.11.1. Not less than one year or as set forth in agreement for service. Application of this schedule shall not be less than 12 consecutive months from commencement of this rate schedule to the customer. Upon termination of service, the customer shall pay as part of the final bill all ratcheted demands that the Cooperative will have to pay its wholesaler as a result of the customer's usage.


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FORM 94-1.39S



Replacing 1ST Revised Sheet No. 40







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FORM 94-1.6S





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





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IstRWiscd SheetNo. 43

Replacing Orininal SheetNo. 43

Cam11 Electric Cmperative Cornoration Name of Company

Kind of Service: Electric Class of Service: As Apelicable

Part m. Rate Schedule No. 17

Title: EXTENSION OF FACEITES

17. EXTENSION OF FACILITES

17.1. APPLTCABLE SERVICE AREA

17.1.1. AI allocated territory

17.2. PERMANENT OVERHEAD LINE EXTENSIONS

17.2.1. The Cooperative wiII build to permanent farmsteads and residences when the distance is 1,320 feet or less without cost to the customer when he has complied with the tariffs of the Cooperative as approved by and filed with the Arkansas Public Service Commission and the d e s of the Commission.

17.2.2. The following schedule will be followed when any request for service exceeds 1,320 feet in length as staked by the Cooperative:

A. The customer WilI pay an amount equal to 40 percent (40%) of total (CT) construction costs (excluding transformers and meters) in excess of 1,320 feet to a distance of 2,640 feet.

B, The customer Will pay an amount equd to 75 percent (75%) of total (CP) construction costs (excluding transformers and meters) in excess of 2,640 feet to a distance of 3,960 feet.

C. Where the extension exceeds 3,960 feet, the customer wilI pay 100 percent W) (100%) of total construction costs (excluding transformers and meters) in excess of 3,960 feet.

TIUS SPACEFOR PSC USE ONLY

A R K . ! r v

SE" . ? fq ,

4.A. I ARKANSAS PUBLIC SERVICE comss rm

1 st Revised SheetNO. 44

Replacing Oriainal SheetNo. 44


Kind of senice: EIeClric Class of Service: As Apalicablc


Title: EXTENSION OF FACILITES PSC FileUPtlr only

D.

E.

F.

(3.

Cdculation of constnrction costs mentioned in paragraphs A, B., and C. above shall be based on average construction cost per foot over the preceding six-month period.

By mutuaI agreement, the Cooperative and the customer may agree to apply any part of the projected costs toward the cost of preparing the right-of-way if the customer eIects to prepare the right-of-way for the Cooperative.

Ownership of the line shaII remain with the Cooperative and the right to connect others is in no way waived. All specifications and distances invoIved shali be determined by the Cooperative.

No increase in minimum bills will be levied as a result ofthe line extension.

17.3. SERVICE TO M LOCATION OTHER THAN PERMANENT

17.3.1. The customer must have at least a leasehold interest in the site on which eIectric service is to be built.

THIS SPACEFORPSCUSEONLY

' ARKANSAS PUBLIC SERVICE CbMMfSfiIfjY APPROVED

Oripiind SheetNo. 45

RcpIacing Sheet No.

CarmlI Electric Cooperative Comarotion Name of Company

Kind ofservice: Electric Class of Service: As Apnlicnble


Title: EXTENSION OF FACILITIES

Jun b

17.3.2.

17.3.3.

17.3 -4.

17.3.5.

17.3.6.

17.3.7.

17.3.8.

Provisions shaII be made for a permanent water suppIy under pressure and sewage disposal to the Iocation before the line is buiIt to the site.

The customer shall provide accessibIe entrance to the site.

The customer shall provide right-of-way clearing accordins to the Cooperative's specifications and provide the acquisition of right-of-way easements.

A contribution in the amount of the anticipated costs of construction, plus the amount of expense necessary for removal, less the estimated value of salvageabIe materials will be charsed.

Repayment wiII be made after five years of continued occupancy to the oriejnaI customer. Any lapse in delivery of power due to lack of occupancy or use of facilities or for nonpayment of bills voids the Cooperative's responsibility to refund the contribution.

A service wiII be considered temporary until a11 ofthe above conditions are met or when in the opinion of the Cooperative that exrenuatins conditions will not result in the continued use of the Cooperative-owned facilities.

The Cooperative reserves the risht: at any time durinz the first five years of continued occupancy to declare the service to be changed to a permanent overhead line extension and apply subsection 17.2. of this schedule. When and if this risht is exercised, the Cooperative will reimburse the customer the amount in excess of amounts that wouId have been paid had the extension been a permanent overhead line extension in the beginning.

THiS SPACEFORPSCUSE OmY

ARKANSAS weuc SERVICE COMMISSION APPROVED

ARX4NSAS PUBLIC SERVICE CO3'zi\llIISSXON

Ori~nnl SheetNo. 46

Replacing Sheet No.

Camll Electric Cooperolive Camoration Nme of Company

Kind of Service: Electric Clnss of Service: As Aadicnble


TitIe: EXTFMION OF FACLITES

JUN b

FILED

17.4. EXTENSION OF FACILITIES UNDERGROW

17.4.1. Normally fadities provided by the Cooperative shall be above ground facilities. However, underground facilities may be provided through an agreement by the Cooperative and a developer or an individual customer under the conditions as outlined below:

A Recovery of Costs and Expenses

1. The developer or customer shaII hwe the responsibility for the opening and closing of the trench, including a11 backfill according to the specifications as developed by the Cooperative.

2. The developer or customer shall install the transformer pad according to the specifications outlined on the electrical layout. At the present time, the Cooperative does not offer submersed electrical distribution transformers; therefore, all statements pertaining to transformers incorporated in these d e s shall be interpreted to mean pad-mounted transformers.

3. It shall be the responsibility of the developer or customer to instdl secondary sewices from a point on the lot line designated by the Cooperative. Normally, the location of the meter will be at the Iot line. However, it is recognized that in certain cases this is not feasible for the Cooperative, the developer, or the customer, in which case the meter may be placed on the outside of the dwelling in accordance with prevailing electrical codes. The developer or customer shall maintain accessibility to this secondary service for the purpose of maintenance.

... ..

T M S SPACE FORPSC USE ONLY


'95 ORDER2 ' 9 5 -0 6 6 - TF

OriQiinnI SheetNo. 47

Replacing Sheet No.

Carroll Electric Cooperative Comarntion Name of Company

Kind of Senice: Electric Class of Serviec: As Apdicnblc

Part IU. Rate ScheduIe No. 17

TitIe: EXTENSION OF FACILITIES

4. The Cooperative wiII furnish under its normal street lighting policy, street lighting where secondary sentice is available at the time other electrical work is being done. The normal cost of overhead construction wilI be calculated and subtracted from the actual cost of underground construction with the deveIoper agreeing to pay the difference between the two before the work is done.

5 . Where existing overhead faciIities are in place and the developer or customer desires removal of the overhead facilities, the following method of removd will apply with estimated payment being made before actuaI construction starts. In all cases, the Cooperative has the date of construction on aII of its existing facilities with an anticipated life expectancy of 35 years. It shd be the responsibility of the developer or customer to pay to the Cooperative the undepreciated value of the existins facilities on the subdivision site less any saIvaseable material. Ifit is deemed by the Cooperative that other benefits would accrue, any portion or all of this undepreciated expense may be waived by the Cooperative.

B. Trenching and Backfilling

1, The Cooperative shall not be liable as a resuIt of the developer or customer of any of his asent’s work in connection with opening or closin,o ofthe trench or performing any other work in connection with the instaIIation of any electrical facilities or the operation of the same except by the Cooperative’s own personneI or authorized representative.

TlUS SPACE FORPSC USE ONLY

ARKANSAS PUBLtC SERVICE COMMISSION APPROVED

Orininal SheetNo. 4s

Rep1 ac ing Sheet No.

Carroll Electric Coonemtiw Camomtion Nme of Compnny

Kind of Scdce: Electric Class of Senice: As AaaIieable

Part E L Rate Scliedule No. 17

Title: 33XTFNSION OF FACILITIES

JUH

FibED

C. Character of Service

1. Normally, only sin& phase sewice will be provided. However, if, for the convenience of the Cooperative, it is determined desirabIe that three phase circuiting should be installed, no additional charges would be made to the deveIoper or customer. If, however, the developer or customer insists that three phase service be provided, then the totd cost of the additional expenses incurred would be borne by the developer or customer.

2. Service connection wilI be made avaiIabIe at the point of the desired permanent service location. It will be the responsibility of the developer or customer to furnish any other temporary construction fadhies necessary to complete the job.

D. Individua? Service Connections

1 . A developer may choose whether or not he desires undersound dectrical distribution for his subdivision as per these rules or he may choose an underground secondary system only from an overhead primary system, in which case all the provisions for individual service connections, trenching, backfilling and easements would apply.

2. Services to individual houses not considered to be part of a subdivision with overhead primary and with undersround secondary will be made in accordance with subsections 17.4. LA3. arid 17.4.1 .D. I -

'THIS SPACE FOR PSC USE ONLY

ARKANSAS PUBLIC SERV!CE COMMISSION APPROVED

On'ainal ShcetNo. 49

Replacing Sheet No.

Cormll Electric Coonerativc Cornoration Name of Compnny

f i d of Service: E1ect1-k Clnss of Sentice: As Annlicable

Part ID. Rzte Schedule No. 17

Title: EXTENSION OF FACElTES

II 19 AH 't35

psc File only

E. Criteria and Requirements

1. The Cooperative will not normalIy make ZvailabIe underground primary sentice to individua1 residentid installations. A group of lots of five or more will be considered as a subdivision in determifiing the availability of totd underground system. MobiIe home pvks, meeting all the other criteria of these rules, shall be considered to be subdivisions except for paragraphs 17.4.1.A.3. and 17.4.1.D.I.

2. Where individuals, not part of a subdivision, insist that a11 facilities serving him be placed underground and it does not handicap the further extension of the Iine to other customers, the norinal cost of overhead construction wiII be calculated and the customer shalI be required to pay the amount, if any, of the actual cost to the Cooperative of undersound construction above the norma1 cost of overhead construction.

F. Easement Requirements

1. Before any work is begun, the developer \vi11 finish the Cooperative with an approved, filed plat with protected and designated permanent utiIity easements, including bench marks and staked corners ofthe Cooperative's reference points. The Cooperative Will then hrnish the developer with a proposed layout of electricaI facilities including street lights and specifications of materials and equipment to be used.

THIS SPACE FOR PSC USE 0Sl.Y

Origind SheetNo. 50

Replacing Sheet No.

Cnrroll Electric Cooperative Camoration Name of Company

Kind of Service: Electric Class of Scnice: As Aoplicnble

Part IU. Rqte ScheduIe No. 17

TitIe: EXTENSION OF FACILITIES

2. Upon the deveIoper's approvaI ofthis plat and when rough grading proceeds to a point within six inches ofthe find grade, then the Cooperative will proceed to install, or cause to be installed, the electrical underground distribution system.

3. The deveIoper will provide a space for one overhead structure for the purpose of entering the subterranean system in the subdivision at a point specified by the Cooperative.

G.. Construction Standards

1. All work performed by the Cooperative and the developer shaII be in accordance with the National EIectrical Safety Code and those codes imposed by the IocaI political subdivision having jurisdiction and special rulinp from time to time by the Commission.

2. NomaIly, the Cooperative will recommend that no water or gas lines be placed in the same trench with the Cooperative's conductors. However, it shall be permissible for the communications cable to be placed in the same trench provided that it is explicitly understood that a minimum distance of one foot shall be spaced with an approved warning barrier placed one foot above the electrical conductors. In the event of interrupted electrical senice as a resdt of installation, maintenance or repair of communications cabIes, the communications company responsible for the disruption of service shaII reimburse the Cooperative for actual costs incurred in restoring service and repairing the electrical faciIities.

TfIIS SPACE FOR PSC USE ONLY

ARKANSAS PUBLIC SEfiVtCE COMMISSION APPROVED

AFSC FILED Time: 7E1120ii 3:53:37 PM: Reevd 7121120<1 35224 PM: Docket 77-021-U-Doe. 704


3rd Revised Sheet Na. 51


CarroIl Electric Cooperative Corporation Name of Company

Kind of Service: Electric Class of Service: Industrial

Part Ill. Rate Schedule No.: 18

SPECIAL CONTRACT - BEKAERT CORPORATION (Updated for U-2814 effective 071014201 1) [AT)

Title:

18. SPECIAL CONTRACT -6EKAERT CORPORATION

FSC R e M a h W

18.1. AGREEMENT FOR ELECTRIC SERVICE

18.1.1. Agreement made Julv 1, 1996, between Carroll Electric Cooperative Corporation (hereinafter wtled "Setlef), and 8ekaert Corporation (hereinafter called 'ConsumeT.), a Corporation.

18.1.2. The Setler shalt sell and deliver to the Consumer, and the Consumer shall purchase all of the electric power and energy which the Consumer may need at it5 facility located near Rogers, Arkansas, up to a maximum demand of 20,000 kilowatts, upon the terms and conditions provided herein.

18.2. S ERWCE CHARACTERISTICS

18.2.1. Service hereunder shalt be alternating current three phase four-wire, sixty cycles, 13200Yt7620 Volts.

18.2.2. The Consumer shall not use the electric power and energy furnished hereunder as an auxiliary or supplement to any other source of power.

18.2.3. Electric motors connected to the power source in excess of 1,000 horsepower shall be equipped with reduced voltage starters.

18.2.4. The Consumer shall not- sell electric power and energy purchased hereunder.

TtUS SPACE FOR PSC USE ONLY

THIS SPACE FOR PSC USE ONLY FORM 94-2.3S


7th Revised Sheet No. 52 Replacing 6th Revised Sheet No. 52 Carroll Electric Cooperative Corporation Name of Company Kind of Service: Electric Class of Service: Industrial Part III. Rate Schedule No.: 18 Title: SPECIAL CONTRACT - BEKAERT CORPORATION PSC File Mark Only

18.3. INTERRUPTIBLE DEMAND 18.3.1. All demand used by Consumer shall be designated interruptible demand. Service to

Consumer may be interrupted at any time upon demand by the Seller or Seller’s Wholesale Power Supplier (AECC) with at least three hours advance verbal or electronic notice. On behalf of the Seller the following persons are hereby designated to provide notification to the Consumer in the event of a notice of interruption: President, CEO, Vice President, Engineering & Operations or their designee. On behalf of the Consumer the following persons are hereby designated to accept notification by the Seller of a notice of interruption: Plant Manager or his/her designee. Such interruptions are not to exceed 200 hours in any calendar year. Service may be interrupted by AECC for up to the number of hours stated in the Interruptible Credit Rider when, in AECC’s sole judgment, such interruptions may prevent the interruption of service to other customers. Service may be interrupted up to fifty percent of the number of hours stated for any reason. This provision does not impair or limit AECC or Carroll Electric Cooperative Corporation’s rights to interrupt service in case of emergency. Hours interrupted due to system emergency shall not be included in the number of interruption hours. Consumer shall provide at least one year’s advance written notice to Seller and AECC of its intent to discontinue service under the interruptible credit rate and convert to firm service. Provisions of Termination Paragraph 18.25.1 shall continue to apply.

(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)(C)

18.4. NET MONTHLY RATE 18.4.1. The Demand Charge shall be $10.06 per kW of billing demand. 18.4.2. The Energy Charge shall be $0.0343 per kWh consumed. 18.4.3. The Consumer will be credited $5.32 per kW of billing demand per month as compensation

for availability of interrupted load. 18.5. CALCULATION OF DEMAND CHARGE 18.5.1. The current month kW demand shall be the highest one (1) hour kW demand occurring in

the current month.

APSC FILED Time: 9/23/2014 9:05:30 AM: Recvd 9/23/2014 8:56:33 AM: Docket 14-098-tf-Doc. 1

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APSC FILED nme: 7/21120~13:53:37 FM: Recvd 71211201 1 35224 PM: Docket 77-021-WDcc 704

ARKANSAS PU8LtC SERVICE. COMMISSION


Replacing I st Revised Sheet No, 53



Part Ill. Rate Schedule-No.: 18 P5C Fan WarkDM SPECIAL CONTRACT - BEKAERT CORPORATION

(Updated for U-281 I effective 07~01/201 I) (AT)

18.5.2. The billing kW demand shall be the average of thecurrent month kwdernand occumng in the current month and the preceding eleven (I I) months.

10.6. FAILURE TO INTERRUPT AT LQGATIONS WHERE SELLER OR AECC CAN PHYSICALLY INTERRUPT THE LOAD

18.6.1. If having received at least three hour's advance verbal or electronic notice of a request to interrupt, and the Consumer fails to interrupt, the Seller or AECC shatl interrupt Consumer's load,

18.7. FAILURE TO INTERRUPT AT LOCATIONS WHERE SELLER OR AECC CANNOT PHYSICALLY INTERRUPT THE LOAD

18.7.1. If having received at least three hour's advance vehat or electronic notice of a request to intempt, the Consumer fails to intempt, then Consumer shall be subject to interruption for one year following their failure to interrupt. In the event that Consumer fails to intempt, the Seller shall no longer receive interruptible credit for fhe Consumer from AECC and will no longer provide Consumer interruptible credits. When the above stated terms have been satisfied, the Seller shall receive service for the Consumer under AECC's firm rate and the Consumer shall no longer be subject to interruption or receive interruptible credit.

98.8. SUPPLEMENTAL SERVICE DURING PERIODS WHEN SERVICE WOULD NORMALLY BE INTERRUPTED

18.8.1. During periods when service would normally be intempted, AECC wilt make a good faith effort to continue service by making available to the Seller (for sewice to Consumer) for Consumer's taking Supplemental 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 Seller and Consumer shall have no control of AECC's judgment or recourse from it.

TMSSPACEFORPSCUSEONLY

FORMBkz3s

APSC FILED Time: 712112011 35337 PM: Rswd 7&1L?0113:52:24 PM: Docket i%OZI-WDoc. 704


Origlna! Sheet NO. 53.1

Replacing Sheet No. 53.1


Kind of Sem'ce: Elechie Class of Service: Industrial

Part 111. Rate Schedule No.: 18

SPECIAL CONTRACT - BEKAERT CORPORATION (Updated for U-2814 effective 0710I/ZOl I) (AT)

PSC F$e Merk ONy

18.8.2. The Consumer shall have the right to accept or reject this supplemental service each time an interruption under normal service is called for by AECC or Seller. At each time, AECC notifies the Seller that normal service will be interrupted and the Seller so notifies Consumer, the Seller will also notify the Consumer whether OF not Supplemental service is available. If Supplemental service is available, the hourly MWh amounts to besupplied as Supplemental service and the price per MWh to the Seller for such Supplemental service shall be quoted by Seller to the Consumer. Within 10 minutes of notification of the availability of Supplemental service, the Consumer shall notify Seller whether it chooses to interrupt or accept Supplemental sewice.

18,8.3. Failure of the Consumer to notify Seller of a decision to interrupt or accept Supplemental service within said I O minute period shall be deemed an election to interrupt. If Supplemental service is accepted by the Seller and the Consumer, AECC may notify directly the retail consumer of an interruption in supplemental service. The retail consumer must interrupt such Supplemental service within 5 minutes of the time such notice is given. Provisions of this Supplemental service shalt be subject to the criteria of the Regional Reliability Council of which AECC is a member.

18.9. SUPPLEMENTAL SERVICE CHARGE

18.9.1. When Seller chooses to accept Supplemental service on behalf of Consumer according to the above section, the Seller will be charged the price quoted by AECC and accepted by the Seller for such service. Such quoted price to the Seller will be AECC's expected total cost of providing supplemental service plus an adder equal to 10% of such expected total cost not-to exceed five dollars ($5.00) per MWh. Said amount shall be billed by Seller to Consumer.

THIS SPACE FOR PSC =E ONLY

APSC FILED firne: 818120ll llA620 AM: R w d 8181201 I 11:12:25 AM: Docket -Doc 1


1' Revision Sheet No. 53.2

Replaclng 0 rig i n a I Sheet No. 53.2


Kind of Service: Eleetric Class of Service: Industrial


SPECIAL CONTRACT - BEKAERT CORPORATION Tit'e: (Updated for U-281 f effective 07/01 1201 'I 1 (AT)

18.10, POWER FACTOR PENALTY I kVAR CREDlT RIDER

18.10.1 The power factor shall be determined to the nearest one-tenth of one percent at each delivery point at the Current Month kW Demand. 7he impact for mulfiple meter points at the same location shall be calculated as the net impact on the transmission system. Refer to Modification to Agreement between Bekaert Corporation and Carroll Electric Cooperative Corpomtion for additional information regarding power factor requirements.

(AT) (Ar) (Ar)

q8.10.2. SUMMER MONTHS

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

18.1 0.2.2. 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. WAR 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 kWIAPF))-Billing kW

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 $0.1 0 per kVAR for such difference.

TAN(ACOS(O.98))*Billing kW - TAN(ACSO(APF))*Bil[ing. Credit kVAR=

18.10.3. NON SUMMER MONTHS

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

FORM 86-295

P

APSC FILED time: 71211201 I 3:53:37 PM: Remd 7t211203 1 3:52:24 PM: Dmket 77-021-Lt-Doc. 704


Original Sheet No. 53.2.a

Repladng Sheet No. 53.2a



Part Ill. Rate Schedule No.: '18

titre: (Updated for U-2811 effective 07/0U2Ol I) Fsc no Mako* SPECIAL CONTRACT - BEKAERT CORPORATION

(AT)

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 a 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 shatl be multiplied by the 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 shalt be given each month equal to $0.10 per kVAR for such differences. 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.

FORM W23S

rn 2U8

APSC FILED Time: 7/21t2011 35357 PM: Rerrd 7t21L?Oli: 3:52:24 PM: Docket 77421-U-Dcc 704


Original Sheet No. 53.3

Rep I acing Sheet NO. 53.3


Kind of Service: Electric Class of Service: Industn'at


Tit'e' (Updated for U-2811 effective 07lOI/201 1) (AT) SPECIAL CONTRACT - 8EKAERT CORPORATION

18.1 1. VOLTAGE FLUCTUATION AND HARMONIC DISTORTION RIDER

18.1 I .I. APPLICATION

PSC FB% Marlr Ont$

This rider shalt be applicable to delivery points of common coupling within the Sellets system. AECC, in its sole discretion, shall determine the point of measurement and the following criteria for voltage fluctuations and harmonic distortion shall be met:

Individual Voltage Dips Individual Voltage Dips Individual Voltage Dips lndividuat Vobge Dips Individual Voltage Dips

Swing

Swing Swing Swing Swing

Swing

Frequency of Occurrence Maximum Allowable

1 Per Hour 3.0% 3 Per Hour 2.0% 8 Per Hour I .3% 1 PerMinute 0.0% 1 Fer Second 0.4%

% Voltage Dip

Fluctuation Frequency

I Per Second 5 Per Second 8 Per Second 14 Per Second 20 Per Second 25 Per Second

Maximum Allowable Voltage Fluctuation

0.4% 0.4% 0.4% 0.7% 1.0% 1.4%

Points between those shown above will be interpolated.

THISSPACE FORPSCUSEONLY

FORM W3S

APSC FILED Ttrne: 7klROll 3:53:37 PM: Rewd 712112011 3:52:24 PM: Docket f;r-oZ1-U-Doc. 704

ARKANSAS PUBLIC SERVICE COMMtSSlON


Rep 1 acing Sheet No. 53.4


Kind of Sewice: Electric Class of Service: Industrial

Part I l l . Rate Schedule No.: 18

SPECtAL CONTRACT - BEKAERT CORPORATION Titre: (Undated for U-2811 effective 07/01 I201 1 I IATl

PSC Fsa MarkOy

The necessary harmonic filtering equipment will operate in such a manner that the harmonic component ofvoItages at any connections to the utility system be no greater than the following:

The total harmonic distortion ('THD') shall not be greaterthan 1.5% of the fundamental voltage. (lEEE Standard 51 9 for 11 5 kV and above.)

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

18.12. FAILURE TO MEET CRITERIA

18.12.1, If these criteria are exceeded, AECC andlor-Seller shall have the right to immediately discontinue the furnishing of electric power until the cause@) of such excess(es) have been removed or remedied. Seller 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.

18.13. LlABUIY OF AECC AND SELLER 18.13.1. Neither AECC nor Seller shall be liable for any damages incurred by Consumer resulting from

electric power and energy interruptions occumng under the Interruptible Credit Rider. Consumer releases both Seller and AECC from liability resulting from interruptions under interruptible service provisions regardless of whether or not Consumer was prepared to be intempted when notice of interruption was given.

THlS SPACE FOR PSC USE ONLY

FORM W3S

ARKANSAS P U U C SERVICE COMMISSION APPROWED

APSC FILED rime: 7k21/20I13:53:37 FM: Rewd 712112011 35224 PM: Docket77421-U-Doc. 704


ZM Revised Sheet No. 54

Replacing 1 a Revised Sheet No. 54


I Kind of Service: E l e ~ + c Class of Service: Industrial

I Part 111. Rate Schedule No.: 18 PSC!=laMar)rw SPECIAL CONTRACT - BEKAERT CORPORATION

(Updated'for U-281 ?-effective 07lOll20l I) (AT)

18.14. FUTURE-REVISIONS IN-WHOLESALE TARIFF SERVICE TO SELLER (Ar)

18.A4.1. If rates, provisions andlor rules of the wholesale tariff that Seller purchases wholesale power

rules and rates contained herein.

(AT) (AT) (Ar>

at are modified in any way, then corresponding modifications shall be made to provisions,

18.15. MINIMUM MONTHLY CHARGE (MT)

18.15.1. The Consumer shall pay to the Seller each month during the term hereof not less than the IMT) (MT) (MT)

greater of the following: An amount equal to the net calculated bill or the demand charge (including pf adjustment) plus $50,000.

18.1 5.2. tn the event electn'c power and energy requirements herein provided are suspended or terminated by the Consumer, the Consumer shall pay as part of the final bill any whojesale

added to minimum bill charges.

(MT) (Mi)

(MT)

power costs attributable to the Consumer which the Seller will have to pay its supplier during the following eleven (I 1) months. Adjustments as described in paragraph 18.16. shall be

(MT) (MT)(CT)

18.16. ADJUSTMENTS (MT)

18.16.1. Billing under this Agreement shall be subject to t k following additional adjustments. (MT)

A. Cod of Energy Adjustment Clause - See Rider No. 1 (Mi)

8. Tax Adjustment Clause - See Rider No. 2 (M73

C. Cost of Debt Adjustment Clause - See Rider No. 3 (MT)

18.17. CREDIT FOR PRIMARY SERVICE:

18.17.1. Consumer shall receive a credit of four percent (4%) of net energy charge only as compensation for providing transformation from primary voltage to Consumer's voltage. The net energy charge as defined for this paragraph shall equal the energy charge of paragraph 18.4., plus the cost of energy adjustment, plus the cost of debt adjustment.

FORM -3s ARKANSAS PUBLlC SERWCE CUMMSScON

APPROWED

AFSC FILED mme: 712112031 35337 PM: R e d 7mR01 i 3:52:24 PM: Docket 77-021-lLDoc. 704



Replacing 1 st Revised Sheet No. 55


Kind of Service: Electric Class of Sewiee: Industrial


SPECIAL CONTRACT - BEKAERT CORPORATION Tit'e: (Updated for U-2811 effective 07/0l/20l1) (AT)

18.18. PAYMENT

18.18.1. The initial billing period shall start when the Consumer begins using electric power and energy.

18.18.2. Bills will be rendered monthly after the end of each calendar month. Bills for service hereunder shall be paid at the office ofthe Seller in Berryville or Bentonville, Arkansas, monthly within ten (10) days after the bit1 is received by the Consumer. If payment is not received within ten ( I O ) days after the bill is received by the Consumer, the payment may be considered as late. If the Consumer shall fail to make such payment within fifteen (15) days after such payment is due, the Seller may discontinue service to the Consumer upon giving miteen (15) days written notice to the Consumer of its intention so to do; provided, however, that such discontinuance of service shall not relieve the Consumer of any of its obligations under this Agreement.

18.18.3. When payment is late, Consumer will pay a late charge proportionately equal to any late charge normally imposed upon Seller by the party from whom it purchases its electric power and energy. AECC presently charges a late charge in the amount equal to one-half (In%) above the National Rural Utilities Cooperative Finance Corporation line of credit rate not to exceed five percent (5%) above the most recent (closest to past due date) published Federal Reserve discount rate.

FORM w3s






Part 111. Rate Schedule No,: da

SPECIAL CONTRACT - BEKAERT CORPORATION Tit'e: (Updated for U-2811 effective 07!0fIZOl I) (AT)

18.19. POINT OF DELIVERY

18.j 9.1. The Point of Delivery shall be where the Consumer attaches its service cables to an appropriate structure furnished by the Seller. The Seller shall provide four (4) 13,200 volt overhead circuits each having a capacity of 10,000 kW and terminated on Sellefs dead end structures at the point-of delivery. Three (3) of the circuits will be fed from one North Rogers substation transformer and one from another North Rogers substation transformer. The Consumer shall furnish a site for installation of the Sellets dead end structures. Duly authorized representatives of the Seller shall be permitted to enter the Consumer's premises at all reasonable times in order to cany out the provisions hereof. The Consumer shall own, operate, and maintain all structures, transformers, switching equipment, and other electrical facilities on the Consumeh side of the point of delivery; and shall hold the Seller harmless against any and all damages or claims for damages which might result from the operation of said facilities.

18.20. POINT OF MEASUREMENT

4 8.20.1. The point of measurement for billing shall be the point at which Seller purchases power at wholesale.

18.21. METER TESTING AND BILLING ADJUSTMENT

18.21.1. Seller shall test and calibrate meters, or cause them to be tested and calibrated, by comparison with accurate standards at intervals of twelve (12) months. Seller shall also make, or cause to be made, special meter tests at any time at Consumets request. The cost of all tests shall be borne or provided for by the Seller, provided, however, that if any special meter test made at Consumer's request shall disclose that the meters are recording accurately, Consumer shall reimburse Seller for the cost of such test.

FORM -3s

A R W W PUBUC SERVICE CQMMlSSIOi i APPROVED

APSC FILED Time: 7nIt20I I 3:53:37?M: R e d 712lt2Ol I 35224 PM: Docket 77-02i-U-Doc. 704



Replacing 1st ReGsed Sheet No. 57


Kind of Service: Electric Class of Service: Indusbial

Part 111. Rate ScheduIe No.: 18

SPECIAL CONTRACT - BEKAERT CORPORATION (Updated for U-2811 effective 0 7 ~ 0 f ~ 2 0 I l ) (AT)

. Meters registering not more than two percent (2%) above or below normal shall be deemed to be accurate. The readings of any meter which shall have been disclosed by test to be inaccurate shall be corrected for the ninety (90) days previous to such test in accordance with the percentage of inaccuracy found by such test. If any meter shall fail to register for any period, the parties shall agree as to the amount of energy furnished during such period and Seller shall render a bill therefore.

18.22. CONTINUITY OF SERVICE

18.22.1. The Seller shall use reasonable diligence to provide a constant and unintermpted supply of electric power and energy hereunder. If the supply of electric power and energy shall fait or be interrupted, or become defective through act of God, Governmental authority, action of the elements, public enemy, accident, strikes, labor trouble, required maintenance work, Le. such maintenance work that cannot be reasonably postponed or avoided, inability to secure right-of-way, or any other cause beyond the reasonable control of Seller, the Seller shall not be liable therefore or for damages caused thereby.

18.23. MEMBERS HIP

18.23.1. The Consumer shall become a member of the Seller and be bound by such rules and Regulations as may from time to time be adopted by the Seller.

FORM -35

APSC FILED TIrne: 7&1L?011353:37 PM: Rewd 712112011 3:52:24 PM: Docket 77-021-U-Doc. 704





Kind of Service: Electric Class of Senrice: Industrial

Part Ill. Rate Schedule No.: i a PsCFhtMarkDrdy SPECfAL CONTRACT - BEKAERT CORPORATION

Title: (Updated for U-2811 effective 07iOll201 1) (AT)

18.24. OPERATING DESIGNEE OF PARTIES TO THE AGREEMENT

18.24.1. Consumer hereby designates Mike Brannan as the authorized individual responsible for the operation and supervision of its electric system with whom Seller may deal and Consumer wilt promptly notify Seller in writing whenever there may be a change in designee. Seller hereby designates the General Manager of Seller for the same purpose.

18.25. TERM

18.25.1. The term of this Agreement shall become effective on the date first written above for a period of five (5) years and thereafter for subsequent five (5) year periods until terminated by written notice by either party to the other. Said notice shall be provided at least one year prior to the termination date specified in such notice. In the event Consumer terminates sewice prior to the date written above, then Consumer will pay Seller an early termination fee equal to $50,000, or the minimum monthly bill provided in paragraph 18.15. above, whichever is greater, for each month that this Agreement is prematurely terminated. These amounts are in addition to any other charges owing hereunder.

18.26. SUCCESSION AND APPROVAL

18.26.1. This Agreement shall be binding upon and inure to the benefit of the successors, legal representatives and assigns of the respective parties hereto.

FORM &c2ss

APSC FILED Time: 712112011 3:53:37 PM: R e d 712112031 3:52:24 PM: Dncket77-02l-U-Doc. 704





Kind of Service: Electric Class of Service: 1 n d u s tri a I


Tit'e: (Updated for U-2811 effective 07/OmOl I) (AT) SPECIAL CONTRACT - BEKAERT CORPORATION

18.26.2. The rates and charges for electrical senrice hereunder are subject to approval by the Arkansas Public Service Commission and, accordingly, this Agreement shall not become effective until such approval as may be required-by law is obtained in writing from the Arkansas Public Service Commission.

1 &26.3. Service under this Agreement is subject to the tariffs of the Seller as they are on file, or may in the future be filed, with the Arkansas Public Senrice Commission.

18.27. MISCELLANEOUS

18.27.1. Headings of articles in this Agreement have been inserted for convenience only and shall in no way-affect the interpretation of any term or provision hereof.

18.27.2. This Agreement shall be governed by and interpreted in accordance with the laws of the State of Arkansas.

18.27.3. Any waiver at any time by a party of its rights with respect to a default or with respect to any other matters arising in connection with this Agreement shall not be deemed a waiver with respect to any subsequent defauIt or other matter.

FORM W35

T H S SPACE FOR PSC USE ONLY




Kind of Senrice: Electric Class of Service: Industrial

Part Il l . Rate Schedule No.: 18

7-:*1*. SPECIAL CONTRACT - BEKAERT CORPORATION

APSC FILED Tlme: 7121/2011353:37 PM: Recvd 712112011 3:52:24 PM: Docket 77-021-&Doe. 704

ARKANSAS PUBLIC SERVICE COMMISSIOM

PSC n o Marlt Ortj

(Updated for U-2811 effective 071011201 1) (AT) 1 IllC

18.28, IN- WITNESS WHEREOF, the parties hereto haveexecuted this Agreement as of the day and year first above written.

CARROLL ELECTRIC COOPERATIVE CORPORATION

ATTEST

Winfred Prier * Secretary

By: George L. Williams * President of the Board

-I3 E KA E RT C 0 RP 0 RAT1 0 N AITEST:

Shed J. Coyle Secretary

BY: Rick McWhirt Plant Manager

*At Signatures On file Wi the Coopernth and CornrnSsslon as filed on orlgInal contract

THIS SPACE FOR PSC USE ONtY








Title: CHARGES RELATED TO CUSTOMER ACTIVITY PSC File Mark Only

19. CHARGES RELATED TO CUSTOMER ACTIVITY


19.1.1. To all customers taking electric service under the Cooperative’s retail rate schedules as they are now or as they may be in the future filed and approved by the Arkansas Public Service Commission.

19.2. MEMBERSHIP FEE

19.2.1. The Cooperative will charge a refundable membership fee of: ........................ $ 25.00 Only one membership fee per customer. Does not apply to other accounts to the same person.

19.3. DEPOSITS FROM APPLICANTS

19.3.1. The Cooperative may require a deposit from any applicant to guarantee payment for service, subject to the conditions in Rule 4.01. of the Commission’s General Service Rules.

19.4. DEPOSITS FROM CUSTOMERS

19.4.1. The Cooperative may only require a new deposit or an increase in the amount of a deposit from a customer in accordance with Rule 4.02. of the Commission’s General Service Rules.

19.5. CONNECTION FEE

19.5.1. The Cooperative will charge a fee of: .............................................................. $ 40.00 This charge shall apply to all service connections other than those where a reconnect fee applies. The charge shall apply only during regular office hours of Cooperative personnel (8:00 a.m. to 4:30 p.m., Monday through Friday).

19.5.2. The Cooperative will charge an after-hours fee of: ........................................... $ 65.00 This charge shall apply to all service connections made after regular office hours of the Cooperative and before 9:00 PM.


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19.6. COLLECTION FEE

19.6.1. The Cooperative will charge a fee of: ............................................................... $ 40.00 For an employee making a trip to the customer’s premises after the last day to pay, as printed on the shut-off notice and accepting payment of the past due amount, or while there making delayed payment arrangements with customer to pay in the office, or to visit the premises to collect at the customer’s request. At customer premises where the Cooperative has installed metering with remote disconnect/reconnect features, employees do not visit premises to collect because a CECC employee does not have to visit the premises in order to suspend or reconnect service.

19.7. RECONNECTION FEE – REGULAR OFFICE HOURS

19.7.1. The Cooperative will charge a fee of: ............................................................... $ 60.00 For reconnecting service during regular office hours of Cooperative personnel (8:00 a.m. to 4:30 p.m., Monday through Friday).

19.8. RECONNECTION FEE – OTHER THAN REGULAR OFFICE HOURS

19.8.1. The Cooperative will charge a fee of: ............................................................... $ 75.00 For reconnecting service during the hours of 4:30 p.m. to 9:00 p.m., Monday through Friday.

19.9. RETURNED CHECK FEE

19.9.1. 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.

19.10. METER TEST TRIP FEE

19.10.1. The Cooperative will charge a fee of: ............................................................... $ 55.00 When a special meter test is requested by the customer to determine its accuracy. 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.


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19.11. METER RESEAL FEE

19.11.1. The Cooperative will charge a fee of: ............................................................... $ 45.00 This charge will be assessed when a seal at the service entrance is found to be disturbed, and a new seal will be installed.

19.12. METER TAMPERING AND REOCCURING SAFETY VIOLATION FEES

19.12.1. The Cooperative will charge a fee of: ............................................................... $ 160.00For meter tampering. Meter tampering shall include any evidence of interference with the meter’s ability to effectively gauge the consumption of electricity. Such instances may include, but are not limited to, broken seals, jumpered meters and meters that have been reversed or removed. The customer is required to make a new deposit prior to reconnection of service.

19.12.2 The Cooperative will charge a fee of: ............................................................... $ 100.00For each trip by the Cooperative required to resolve a previously addressed violation of the NEC (National Electric Code) and/or other applicable safety standards.

19.13. METER READING FEE

19.13.1. The Cooperative will charge a fee of: ............................................................... $ 55.00 This charge will apply when Cooperative personnel are dispatched to a customer’s premise to obtain a meter reading, made necessary by a customer disallowing contract meter reader access.

19.14. NEW SERVICE APPLICATION FEE

19.14.1. The Cooperative will charge a fee of: ............................................................... $ 80.00 Upon receiving an application from a consumer for installation of electric service at a new service location. The Cooperative may refund all or part of this fee prior to a field visit to begin design work.

19.14.2. The Cooperative will charge a fee of: ............................................................... $ 55.00 For each additional new service on the same property, or within the same subdivision, for which the applicant simultaneously applies. The Cooperative may refund all or part of this fee prior to a field visit to begin design work.


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19.14.3. The Cooperative will charge a fee of: ............................................................... $ 100.00For the initial connections between the Cooperative’s facilities to the applicant’s meter pedestal/base. The applicant must ensure all site conditions are prepared according to the Cooperative’s specifications.

19.14.4. The Cooperative will charge a fee of: ............................................................... $ 50.00 For installation of the meter and/or additional trips required to establish service.

19.15. CONNECT FEE – SECURITY/STREET LIGHTS

19.15.1. The Cooperative will charge a fee of: ............................................................... $ 50.00 For installation of a security/street light at a new location.

19.16. SECURITY/STREET LAMP CONVERSION FEE

19.16.1. The Cooperative will charge a fee of: ............................................................... $ 55.00 This charge will apply when a customer requests a change in an existing security or street light service from an unshielded service to a shielded service, or from a shielded service to an unshielded service. This will also include changes for wattage and bulb type.

19.17. OTHER CHARGES RELATED TO CUSTOMER ACTIVITY

19.17.1. No fee will be charged when a customer or any authorized party requests a statement of the customer’s account record as described in the Commission’s General Service Rule 7.02.

19.17.2. No fee will be charged when a customer or any authorized party requests a statement of the customer’s energy consumption for the preceding 13 months.

19.17.3. All payments received after the twenty-second (22nd) calendar day after the date the bill was mailed shall be charged a late payment fee as per Rate Schedule No. 12, Terms of Payment Clause Rider No. 4.

19.17.4. No fee will be charged when a customer withdraws from a levelized billing plan more than once during a 12-month period.

19.17.5. No fee will be charged when a customer requests a meter reading report unless the meter reading fee applies.


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2nd Revised Sheet No. 64.1

Replacing 1st Revised Sheet No. 64.1





19.17.6. No finance charge will be assessed on delayed payment agreements made between the Cooperative and a customer.

19.17.7. No fee will be charged for additional meters used as special meters or provided for the customer’s convenience as stated in the Commission’s Special Rules – Electric 3.06.A.


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ARK. 1' : JHM.

ARKANSAS PUBLIC SERVICE COMMISSION S E ~ .HH.

Title: TRANSIENT VOLTAGE SURGE SUPPRESSION SERVICE

Oliqinal Sheet No. 64.2

Replacing Sheet No.

PSCFileMaIkW

FILED Carroll Electric Cooperative Corporation Name of Company

I Kind 01 Service: Electric Class of Sem'ce: Sin& Phase


21. TRANSIENT VOLTAGE SURGE SUPPRESSION SERVICE

21.1 DESCRIPTION OF SERVICE

21 .I .l. The Cooperative will install a transient voltage surge suppressor device at the customer's meter or at an alternate location as agreed to by both the Cooperative and the customer. The device may be either a meter socket or equivalent hardwired-type device. (Additional devices will be made available for surge protection under the purchase option described below.) Transient Voltage Surge Suppression Service is intended to reduce fhe magnitude of surges entering the location via the Cooperative's distribution system.

21.2. AVAILABILITY

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

21.3. PROGRAM

21.3.1. Upon receiving an executed Transient Voltage Surge Suppression Service Agreement, the Cooperative wilt install the surge protection device at the customer's meter or at an alternate location as agreed to by both the Cooperative and the customer.

21.4. FEE FOR SERVICE

21 -4.1. The fee for the above described sehrice 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: $5.90/month for one meter socket or equivalent hardwired suppressor. Ownership of the meter socket or equivalent hardwired suppressor will remain with the Cooperative.

Purchase Option: The customer may opt to purchase additionat surge protection equipment. This additional equipment shall be paid for initially or as part of the first monthly bilt following installation. Customer becomes owner of the additional equipment when the purchase option is executed.

cc-



0 ri 9 in a I Sheet No. 64.3

Replacing Sheet No.


Kind of Service: Electric Class of Service: Sinele Phase


Title: TRANSIENT VOLTAGE SURGE SUPPRESSION SERVICE

S E f HH.

PSC Ab Mark Only

21.5. LIMITATIONS OF SERVICE

21.5.1. Transient voltage surges are typical 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 wilt not be damaged in the future by transient voltage surges. The Cooperative's only responsibility herein is provision and installation of equipment.

21.6. AGREEMENT FOR SERVICE

21 -6.1 - The customer will request service by completing and signing a Transient Voltage Surge Suppression Service Agreement.

21.7. TERM

21 -7.1. The customer shall agree to receive Transient Voltage Surge Suppression Service for a minimum of 12 months. If prior to the end of the 1Bmonth period, the customer terminates the Transient Voltage Surge Suppression Service, the Cooperative shall immediately bill the customer for the remaining unpaid months of the agreement. If prior to the end of the 12-month period, the customer terminates electric service where the Transient Voltage Surge Suppressor device is installed, sells or vacates premise, or if the name of the account changes, then the Cooperative shall bill the customer for the remaining unpaid months as part of the final bill. The billing amount for the remaining months shall equal $5.90/month times the number of unpaid months of the Transient Voltage Surge Suppression Service Agreement, plus any unpaid fees for any additional devices requested.

FORM 84.23s

ARKANSAS PUBLIC SERVICE COMMSSION

1 2nd Revised Sheet No. 64.4

Replacing 1 st Revised Sheet No. 64.4

Carroll Electric Coowrative Cormration Name of Company



Title:

F t LED


THIS SPACE FOR PSC US€ ONLY

FORM 94-2.35 ARKANSAS PU8UC SEUVICE CUMMl88510N APPROVE0

ARKANSAS PUBLIC SERVICE COMMISSION 1


Replacing '1st Revised Sheet No. 64.5

Carroll Electric CooDerative Corooration Name of Company



I Title:


THIS SPACE MA PSC USE ONLY

MRM Q4-2.3S

ARKANSAS PtJBllC SERVICE COMM1SSION APPROVED


2nd Revised Sheet No. 64.6 Ft LED I

I


Carroll Electric CooPerative Cumoration Name of Company



Title: PSC Filo Msrlr Only

RESERVED FOR FUTURE US€


FORM 94.2.3s ARKANSAS PUBLIC SERVICE COMMISSION APPROVED




Carroll Electric Coocrerative CorPoration Name of Company



Title:

FILED


THfS SPACE FOR FSC USE ONLY

ARKANSAS PUBLIC SERVICE COMMISSION FOAM BP-2.3s APPROVED

NUV25ZNlZ a! 12 O2-1’92-TF


4th Revised Sheet No. 64.8

Replacing 3rd Revised Sheet No. 64.8





RESERVED FOR FUTURE USE.


APSC FILED Time: 11/13/2017 8:18:34 AM: Recvd 11/10/2017 1:24:36 PM: Docket 16-027-R-Doc. 276

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Replacing 1st Revised Sheet No. 64.9







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Replacing Original Sheet No. 64.10







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Replacing: Original Sheet No. 64.11

Name of Company: Carroll Electric Cooperative Corporation



Title: NET-METERING PSC File Mark Only


TABLE OF CONTENTS

Tariff Provisions ................................................................................................................ 64.11 Preliminary Interconnection Site Review Request ............................................................. 64.15

Standard Information .............................................................................................. 64.15 Terms and Conditions ............................................................................................ 64.16

Standard Interconnection Agreement for Net-Metering Facilities ...................................... 64.18 Standard Information .............................................................................................. 64.18 Interconnection Agreement Terms and Conditions ................................................. 64.19

Disclaimer ......................................................................................................................... 64.27

25. NET-METERING

25.1. DEFINITIONS

25.1.1. Avoided Cost

As defined in A.C.A. 23-18-603(1)

25.1.2. Net-Metering


25.1.3. Net Metering Customer


25.1.4. Net Metering Facility

APSC FILED Time: 11/20/2019 9:18:05 AM: Recvd 11/20/2019 9:17:39 AM: Docket 19-055-U-Doc. 44

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Replacing: 1st Revised Sheet No. 64.12







25.1.5. Electric Utility


25.1.6. Net Excess Generation


25.1.7. Renewable Energy Credit


25.1.8. Quantifiable Benefits


25.2. AVAILABILITY

25.2.1. Service under the provisions of this tariff is available to any residential or any other customer who takes service under standard rate schedule(s) 1, 2, 3, 4, 6 or 14 who is a Net-Metering Customer and who has obtained a signed Standard Interconnection Agreement for Net-Metering Facilities with an Electric Utility. 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.

APSC FILED Time: 1/19/2021 8:35:43 AM: Recvd 1/19/2021 8:35:03 AM: Docket 16-027-R-Doc. 535

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Original Sheet No. 64.12.1

Replacing: Sheet No.






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

25.2.2. 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.

25.3. MONTHLY BILLING

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

25.3.2. 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.

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

25.3.4. For Net-Metering Customers who receive service under a rate that does not include a demand component, the Electric Utility 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 Electric Utility during the billing period.

APSC FILED Time: 2/23/2021 2:17:42 PM: Recvd 2/23/2021 2:17:06 PM: Docket 16-027-R-Doc. 586

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25.3.5. For Net-Metering Customers who receive service under a rate that includes a demand component with a generating capacity of 1,000 kWh or less, the Electric Utility 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 Electric Utility during the billing period.

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

The Electric Utility shall also bill the Net-Metering Customer a grid charge.

Grid charge rate: $0.00.

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


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25.3.8. 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).

25.3.9. After application of 25.3.8. and upon request of the Net-Metering Customer pursuant to 25.3.11., any remaining Net Excess Generation shall be credited to one or more of the Net-Metering Customer’s meters (Additional Meters) in the rank order provided by the Net-Metering Customer.

25.3.10. Net Excess Generation shall be credited as described in 25.3.8. and 25.3.9. 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 Electric Utility purchase the Net Excess Generation credits in the Net-Metering Customer’s account at the Electric Utility’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). An Electric Utility shall purchase at the Electric Utility’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 Electric Utility;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 Electric Utility shall calculate the payment based on its Avoided Costs plus any additional sum determined under the Net Metering Rules for the current year.


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2nd Revised Sheet No. 64.14.1

Replacing: 1st Revised Sheet No. 64.14.1






25.3.11. Upon request from a Net-Metering Customer an Electric Utility must 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 Electric Utility.

(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 Electric Utility’s service area; shall be used to measure the Net-Metering Customer’s requirements for electricity; may be in a different class of service than the Generation Meter; shall be assigned to one, and only one, Generation Meter; shall not be a Generation Meter; and shall not be associated with unmetered service. However, the common ownership requirement shall not apply if more than two customers that are governmental entities or other entities that are exempt from state and federal income tax defined under 23-18-603(7)(c) co-locate at a site hosting the Net Metering Facility.

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

25.3.12. 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.

25.2.13. Grandfathering shall be governed by Ark. Code Ann. 23-18-604(b)(10).


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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 (if different from customer information) Name: ________________________________________________________________ Contact Person: ________________________________________________________ Mailing Address: ________________________________________________________ City: _________________________ State: _______ Zip Code: ___________________ Daytime Phone: __________________ Evening Phone: ________________________ E-Mail Address: ______________________________ Fax: ______________________


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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 Capacity Factor: __________________________________________ Expected annual production of electrical energy (kWh) of the facility calculated using industry recognized simulation model (PVWatts, etc): _______________________


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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: __________

II. TERMS AND CONDITIONS

Section 1. Requirements for Request For the purpose of requesting that the Electric Utility 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 Electric Utility 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 Electric Utility shall provide a copy of the Preliminary Interconnection Site Review Request to the customer upon request.


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Section 2. Utility Review Following submission of the Preliminary Interconnection Site Review Request by the customer the Electric Utility 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 Electric Utility shall make reasonable efforts to provide the customer with the results of the review within 30 calendar days. If the Electric Utility 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 Electric Utility to conduct a study or other analysis of the proposed interconnection site in the event that data is not readily available. The Electric Utility 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 Electric Utility’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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STANDARD INTERCONNECTION AGREEMENT FOR NET-METERING FACILITIES

I. STANDARD INFORMATION

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

Section 2. Owner Information Name: ________________________________________________________________ Contact Person: ________________________________________________________ Mailing Address: ________________________________________________________ City: _________________________ State: _______ Zip Code: ___________________ Daytime Phone: __________________ Evening Phone: ________________________ E-Mail Address: ______________________________ Fax: ______________________

Section 3. Generation Facility Information System Type: Solar Wind Hydro Geothermal Biomass Fuel Cell Micro Turbine Energy Storage Device (circle all that apply) Generator Rating (kW): DC Inverter Rating (kW): __________________________ AC Describe Location of Accessible and Lockable Disconnect: ______________________________________________ Inverter Manufacturer: Inverter Model: Inverter Location: ______________________ Inverter Power Rating: ________ Expected Capacity Factor: _________________________________________________


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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:


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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: __________

Section 6. E-mail Addresses for parties Customer’s e-mail address: _______________________________________________ Owner’s email 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 ("Electric Utility") 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:


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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 Electric Utility's applicable tariffs.

Section 3. Interruption or Reduction of Deliveries The Electric Utility 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 Electric Utility'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 Electric Utility shall have the right to disconnect and lock out the Customer's facility from the Electric Utility's electric system. The Customer's facility shall remain disconnected until such time as the Electric Utility 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 Electric Utility at the Electric Utility's meter.

Electric Utility shall furnish and install a standard kilowatt hour meter. Customer shall


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provide and install a meter socket for the Electric Utility's meter and any related interconnection equipment per the Electric Utility's technical requirements, including safety and performance standards.

The customer shall submit a Standard Interconnection Agreement to the Electric Utility 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 Electric Utility 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 Electric Utility’s existing facilities are not adequate to interconnect with the Net-Metering Facility, the Customer shall pay the cost of additional or reconfigured facilities prior to the installation or reconfiguration of the facilities.

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


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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 Electric Utility. Such approval shall not be unreasonably withheld or delayed. Notwithstanding the foregoing, the Electric Utility'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 Electric Utility of, and the Electric Utility 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 Electric Utility 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


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description of the modifications necessary to remedy the violations.

If the Customer makes such modification without the Electric Utility’s prior written authorization and the execution of a new Standard Interconnection Agreement, the Electric Utility 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 Electric Utility may enter the Customer's premises to inspect the Customer's protective devices and read or test the meter. The Electric Utility may disconnect the interconnection facilities without notice if the Electric Utility reasonably believes a hazardous condition exists and such immediate action is necessary to protect persons, or the Electric Utility'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 Electric Utility 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


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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 Electric Utility, 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 Electric Utility of any changes in the information provided herein.

All written notices shall be directed as follows:

Attention: Mr. Rob Boaz, President/CEO Carroll Electric Cooperative Corporation 920 Highway 62 Spur PO Box 4000 Berryville, AR 72616-4000


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Attention: [Customer] Name: Address: City: Email: ______________________________________ Customer notices to Electric Utility 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 Electric Utility, 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__.


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Customer: Electric Utility:

Carroll Electric Cooperative Corporation

By: By:

Title: Title:

Mailing Address: Mailing Address: 920 Highway 62 Spur PO Box 4000 Berryville, AR 72616-4000

E-mail Address: E-mail Address:

___________________________ ___________________________

Third-Party Owner (if applicable): _____

________________________________

By:______________________________

Title: ____________________________

Mailing Address: ___________________ _________________________________

_________________________________

E-mail Address: ____________________


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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 Carroll Electric Cooperative Corporation (CECC).

1. Electricity rates, basic charges, and service fees, set by CECC and approved bythe Arkansas Public Service Commission (Commission), are subject to change.

2. I understand that I will be responsible for paying any future increases to myelectricity rates, basic charges, or service fees from CECC.

3. My Net-Metering System is subject to the current rates of CECC, and the rulesand regulations of the Commission. CECC may change its rates in the futurewith approval of the Commission or the Commission may alter its rules andregulations, or both may happen. If either or both occurs, my system will besubject 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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On'gind SheetNo. 65

Replacing Sheet No.

CnmlI EIectric Cooperntive Cornomion N m e of ccmpnny

Kind of Senice: Electric

Part XV. Policy Schedule No. 1

Title: LEVELIZED BILLING PLAN

Class of Senke: Residcntinl

h H , b I1 19 AM '35

F f f., E D

PSC W e ?Aarlco$y

I. LEVELZED BILLING PLAN ARKANSAS PUBLIC SERVICE COMMISSION

1.1. APPLICABLE SERVICE AREA , I Ilt '

@ / v 2 8 19% QRDHt 1 9 9 - t 0 7 - 1.1. I. All allocated service territory

1.2. CUSTOMER CLASS

1.2 1 a Residential

1.3. AVAI7;ABILITY OF SERVTCE

1.3. I. Available to permanent residential customers for the purpose of assisting with averaging monthIy payments.

1.4. TERMS AM3 CONDITIONS

1.4.1.

1.4.2.

The eligibility criteria for IeveIized billing shaIl be the same as the criteria specified in General Sentice Rules 4.0 1 .A.(2) under which a utility may require a deposit. Xf the customer meets the requirements for no demsit, then they are also eligible €or the levelized biIIing plan. Once a customer has met the criteria for refunding a deposit, the customer will be eIigibIe for levelized billing.

Billins under this plan shaII be automaticaIIy terminated upon execution of a delayed payment agreement or upon suspension of service for any reason. In the event biIIing under this rider is terminated for any reason other than execution of a delayed payment azreement, then the accumuhted bdance of the customer's account attributable to this Ievelized billins plan shal1 be settled within 30 days.

ms SPACEFORPSCUSEONLY


JUN8 '95ORDER2 9 5 - 0 6 6 - T F

Oridnal ShcctNo. 66

RepIncing Shcet No.

Camll Electric Cooperative Cowomtion Name of company

Kind of Service: Electric Class ofScrvicc: Residential

Part VI. PoIicy Schedule No. I

Title: LEVELEED BlLLmG PLAN

JUH 6 11 19 AM '95

FIL.ED


1.5.1. Billing

A. The customer's monthly bill will be computed in accordance with the appIicabIe rate scheduIe(s) and the customer's account debited with such amount. The net amount payable for service for the current month Will be equal, to the nearest whole dollar, to the average monthly amount debited to the customefs account during the 12 months ending with the current month, PIUS or minus one-twelfth (UE) of the accumulated difference between previous debits and the amount payable under this plan.

B. Except as modified herein, all other provisions of the policy schedules and rate schedules shall apply.

THIS SPACE FORPSCUSE ONLY

ARKANSAS PUBLlC SERVICE COMMISSION APPROVED

Oric4naI SheetNo. 67

Replacing Sheet No.

C a d 1 Electric Caoomtive Camoration Name of Company

Kind of Smite: Electric

Part IV. PoIicy Schedule No. 2

Title: PROVISIONS FOR LANDLORDS AND TENANTS

Class of Scnfcc: Rcsidcntinl

F I I,., ED

2. PROVISIONS FOR LANDLORDS AND TENANTS

2.1. ACCOUNT IDENTFICATION

2.1. I. T h e Cooperative has established the followins procedures for identify ins accounts of landlordhenant arrangements where electric service is included with the lease or rent payments ,

A. A suitable form for applying for the provisions of the Commission's GeneraI Service Rule 6.19 is avaiIabIe in each Carroll EIectric Cooperative Corporation office and is given to the known parties that quaIifL and anyone who requests the information or if the Cooperative has reason to believe may qualify. The form explains the provisions for landlords and tenants and is used for identifying accounts where utility service is provided at an address different from the mailing address of the bill.

B. The general information provided to each new customer includes information expIaining the provisions for IandIords and tenants.

C. When an application is made for service, Cooperative personnel will inquire as to whether the account qualifies as a Iandlordltenant situation as described by the Commission's Genera1 Service Rule 6. I9.A.

m S SPACE FOR FSC USE ONLY

A N S A 8 PUBLIC SERVICE COMMISSION A PP A OVE D

Ori~nai SheetNo. 6R

Rep1 acing S heel No.

C m I l Electric Cooperative Comaration Name of Cornpuny

Kind of Service: Electric Class of Sen4ce: Residentid

Part IV. Policy Schedule No. 3

TitIe: EXTENDED DUE DATF, PLAN

1 JUH ti

3. EXTENDED DUF, DATE PLAN

3.1. The Extended Due Date Plan is available to qualifjring residential customers and is intended to enable CarroII Electric Cooperative Corporation 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 date will not be considered late on their bill payment.

3.2. AVAILABILITY

3.2.1, Customers whose income checks from any ofthe sources Iisted below are not normalIy received by the regular bill due date are eligible to appIy for an extended due date. Qualifying income sources are as follows:

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

B. Persons receiving Supplemental Security Tncome; or,

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

3.3, APPLICATION

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

I

W I S SPACE FOR PSC USE ONLY

Oridnnl SheetNo. 69

Rcplacing Shrct No.

Cam11 Elcctn'c Coonerative Cornoration Nnme of Company

Kind of Senice: Electric Class of Service: Residentid

Part VI. Policy Schedule No. 3

Title: EXTENDED DUE DATE PLAN

JUH

3.3.2. After acceptance of a customer by the Cooperative as a participant in the Extended Due Date Plan, the customer shalI supply to the Cooperative the date on which the monthly income is received (check receipt date). Such date will become a permanent part of the customer's record.

3.4. SETTING THE EXTENDED DUE DATE

3.4.1. 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 bilI due date. Based on this comparison, the following method of determining a bill due date will be used:

A Ifthe check receipt date occurs within the time span between the billins date and the biII due date, the normal bill due date of the account will remain in effect.

33. 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 Ieast three days after the check receipt date and onIy the extended due date will appear on the customer's bill.

3.4.2. If the customer does not pay a bilI by the close of business on the extended due date two times in a row or any three times in the last 12 months, the Cooperative wiII remove the customer from the plan. The Cooperative will notifjr the customer in writing when the customer has been removed ffom the plan for Iate payment.

3.4.3. The Cooperative will impose a late payment charse on plan participants who do not pay by the extended due date. The amount of this charse is determined as stated in 512.3.1. of Rate Schedule 12 "TERMS OF PAYMENT CLAUSE."

T H I S SPACE FOR PSC USE ONLY


Original SheetNo. 70

Replacing Sheet No.

Cam11 Electric Caouentive Corporation Name of Company

Kind of Service: Electric

Part IV. Policy Schedule No. 3

Title: EXTENDED DUF, DATE PLAN

Class of Service: Residentid

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

T H I S SPACE FORPSC USE ONLY

ARKANSAS PUBLIC SERVICE COMMISSION APPR W E D

O+nd ShcetNo. 71

Replacing Sheet No.

Carroll Electric Cooperntive Corporation Nme of Company

Kind of Service: Electric CIass of Service: Residentinl

Part W . PoIicy Schedule No. 4

Title: EXTENDED ABSENCE PAYMENT PLAN

1;

PSCFilehMody

4. EXTENDED ABSENCE PAYMENT PLAN

4.1, The folIowing options are avaiIabIe to a customer to avoid suspension of service during extended absences.

4.1.1. Bills coming due during the customer's absence may be paid in advance. The amount of the advance payment will be based on the custornets average monthly bill for the most recent 12 months. If less than 12 months usage history is available, the advance payment wiIl 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 unless the customer requests a refund. Ifthe 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 avaiIabIe for any underpayments.

4.1.2. The customer will be given the opportunity to enrol1 in the Automatic Bill Payment Plan whereby the monthly service bill will be paid automatically through the customer's checking or savings account.

4. I .3, The customer can arrange to have biIIs coming due durins the period of the absence mailed to an alternate address or third party during the absence.

4.2. The customer must noti@ the Cooperative in order to take advantase of any of these extended absence payment plans.

~ ~~


ARKANSAS PUBLIC SERVICE COMMISSION A PP R DVE D

JUN 8 '95 ORDER 2 9 5 - 0 6 6 - TF t

ARKANSAS PUBLIC SERVICE CO&l&lISSION

0 ri qin n I SheetNo. 72

Rep 1 ne in g Sheet No.

Cnmll Elccctric Coonemtive Comorntion Name of Company

Kind of Smvicc: Electric Class of Service:

Part IV. Policy Schedde No. 5

Title: METER TESTING PROGMMS PSC Fle mk oaly

5. MF,TER TESTING PROGUMS

5.1. METERING

5.1.1. Installation

A. The Cooperative wiII furnish and install the necessary rneter(s), and the customer shall, without reimbursement, provide and maintain a location satisfactory to the Cooperative for its installation.

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

5.1.2. Evidence of Consumption

A. The registration ofthe Cooperative's meter shall be accepted and received at all times and pIaces as prima facie evidence of the amount of service taken by the customer.

5.2. METER TESTMG

5.2. I. To ensure the accuracy requirements of Special RuIes - Electric 7.05.B., are met, before installation by the Cooperative, all new meters \vi11 be inspected and tested in a meter shop or laboratory.

THIS SPACE FOR FSC USE OhZY

ARKANSAS PUGLIC SERVICE COMMlSSlON APPROVED

Orie id SheetNo. 73

Replacing Shect No.

Carroll Electric Coaaemtive Corpontian Name of Company


Part W. Policy ScheduIe No. 5

Title: m T E R T F 3 m G PROGRAMS

6

5.2.2. The Cooperative will make speciaI tests of in-service meters at the request of a customer in accordance with Rule 5-18. of the Commission's Genera1 Service RuIes and Rules 7.05., 7-06., and 7.07. of the Special Rules - Electric.

5.2.3. In accordance with Special Rules - Electric 7.08.B., the Cooperative will conduct in- service tests for watt-hour, poIyphase, demand meter, and pulse recorders in accordance with the foIlowing schedule:

A. All single phase watt-hour meters are to be tested on a scheduIe not to exceed 16 years.

B. Self-contained polyphase meters are to be tested on a schedule not to exceed 16 years.

C. Block intervaI demand meters are to be tested on a scheduIe not to exceed 12 years.

D. In-service pulse recorders and pulse operated demand meters in combination with pulse initiator equipped watt-hour meters are to be tested on a schedule not to exceed two years andlor will be compared monthly to the meter registration.


ARKANSAS PUBLIC S€RVICE COMMlSSlON APPROVED

'95 ORDER 2 9 5 -0 6 6 - TF

Orim'nnI SheetNo. 74

RepIncing Sheet No.

Carroll Electric Coonerative Comorntion Name of Cornpnny


Part W. PoIicy ScheduIe No. 5

Title: METER TESTING PROGRAMS

II ZJ dM '35

I. If the registration agrees with the =two percent (2%) toferance outIined in 7.05.B,3., the pulse recorder is scheduled to be tested on a schedule not to exceed 16 years. If the recorder-meter registration checks do not agree within the =two percent (2%) tolerance, the demand metering equipment is tested.

2. Any meter not containing surge proof maeets is retired.

THIS SPACEFORPSC USEONLY

ARKANSAS PUBLIC SERVICE COMMISSION APPRWED

Original Sheet No. 7s

Replacing Sheet No.

Carmll El ectric Cooperative Conmation NmeofCompany

Kind ofsenice: Electric Class of Service: &

Part w. Porky Schedule No, 6 Title: STANDARD NOMINAL VOLTAGES

6. STANDARD NOMINAL VOLTAGES

6.1. NOMINAL VOLTAGES - SECONDARY 6.1 .l. The following secondary voltages are available from the Cooperative depending on the

customer's size, application, and availability from the distribution system:

A. Singlephase

1. I201240 Volts, 3-wire 1201208 Volts, 3-wire

€3. Three Phase

1. 208Y/120 Volts, 4-Wire 1201240 Volts, 4-wire 480Y/277 VoIts, 4-wire 240 Volts, 3-wire 480 Volts, 3-wire

6.2. NOMINAL VOLTAGES - PRIMARY

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

A. 13.2Y17.62 kv 24.9W14.4 kv

Carmll Eteetric Cooperrdive Corporntion Name of Company

K i d of Senice: E l d c Class of scrvice: fi Part IV, Policy Schedule No. 7 Title: SUPPLYING AND TAKING OF ELECTRIC SERVICE 1 PSCEikMaNWy

7.

7.1.

7.2.

7.3 *

SUPPLYING AND TAKING OF ELECIWC SERWCE

CONTINUITY OF ELECTRIC SERVICE

7. I . 1. The Cooperative will use all reasonable diligence in providing a regular and uninterrupted supply of electric sewice, but does not guarantee the electric service against interruptions or irregularities. In case the suppIy of electricity shall M 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.

MEMBERSHIPREQUREMENT

7.2.1. A customer shall be a member of the Cooperative, shall pay the membership fse and be bound by the articles of incorporation and bylaws of the Cooperative.

USE OF ELECTRIC SERVICE

7.3.1. A customer shall use swvice only for the purpose specified in the agreement for service and in accordance with the provisions of the rate schedule under which service is being supplied.

7.3.2. In no case shall a customer extend or connect his installation to lines across or under a street, alley, lane, court, avenue or other public space in order to obtain electn'c service for adjacent property through one meter even though such adjacent property be owned by the customer.

THISSFACEFORPSCUSEOKLY

Oridnal SheetNo. 77

RepIachg Shcct No.

Cam11 Elec~ric Coopemtive Cornontion N m e of Company

Kind of Service: Electric Class ofService:

Part VX Policy Schedule No. 7

TitIe: SUPPLYING AND T m G OF ELECTRIC SERVICE

7.4.

7.5.

REFUSAL OF SERVICE

7.4.2. The Cooperative may refuse to provide senrice to an applicant for sefvice for reasons as specified in General Service RuIe 3.04.

INSTALLATION OF SERVICE

7.5.1. Installation and Maintenance

A. Except as otherwise provided in these tariffs, in agreements for sentice or rate schedules, the Cooperative will install and maintain its Iines and equipment on its side of the point of deIiveiy, The Cooperative shaII not be required to instdill, inspect, or maintain any Iines or equipment except meters on the customer's side of the point of delivery. OnIy Cooperative employees are authorized to connect the Cooperative's service drop to the customer's service terminals.

7.5.2. Protection by the Customer

A. The customer shall protect the Cooperative's wiring and apparatus on the 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 arisiq out of carelessness, nesIect, or misuse by the customer or other unauthorized persons, the cost of making good such loss or repairing such damage shall be paid by the customer.

A!?WSAS PUBLIC SERVICE COMMlSSiON APPROVfD

On'kiinnl SheetNo. 75

Replacing Sheet No.

Cnrroll Electric Cooperative Camoration Name of Company

Kind of Service: Electric Clnss of Service: All

Part VI. PoIicy Scheduk No. 7

Title: SUPPLYING AND TAKING OF ELECTRIC SERVICE

JUH I I 20 AM $25

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

7.6. SUSPENSION OF SERVICE

7.6.1. The Cooperative may suspend service to an existing customer of the service for reasons as specified in Genera1 Service Rule 6.0 1.

7.7. SERVICE INTERRUPTIONS

7.7.1. Additionally, the Cooperative may interrupt service at any reasonable time for the purpose of essential repair, maintenance, or testing of Cooperative equipment and shall schedule such interruptions and make appropriate customer notifications in accordance with General Service Rule 8.04.

?MS SPACE FOR PSC USE ONLY

Ori~inal SheetNo. 79

Rep I ncin g Sheet No.

CnrrolI Elcctric Coonerativc Corpomtion Name of Company

Kind of Senice: Electric C h s of Service:

Part W. Policy Schedule No. 8

Title: CUSTOMER'S RIGHTS AND RESPOhTSIBILlTIES

II 20 dll '%

PSC Fdc Mark Cdy

8. CUSTOMER'S RIGETS AND RESPONSIBalTIES

8.1. In addition to the customer's rights and responsibilities as specified in the rules and regulations of the Commission, the customer assumes all responsibility on the customer's side of the point of delivery for the eIectric serrice supplied or taken, as well as for the electrical installation, appliances, and apparatus used in connection therewith, and shall save the Cooperative h d e s s 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 the customer's side of the point of delivery,

8.2- RIGHT-OF-WAY

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

5.3. ACCESS TO PREMISES

8.3. I. Duly authorized agents of the Cooperative shall at all reasonable hours have access to the premises ofthe customer for the purpose of inspecting, operatins, maintaining, removing or replacin,a Cooperative property, for the reading of Cooperative meters and all other purposes incidental to the supplying of service, and shaII be furnished such access at any reasonable time for ernersency repairs, removal, replacement, or operation of Cooperative facilities.

- .. ~~ ~

THIS S P S FOR PSC USE ONLY

Orieinal SheetNo. 80

Replacing Sheet No.

Carroll Electric Coonemtive Comorntion Nnme of Company

Kind of Senice: Electric

Part VI. Policy ScheduIe No. -8-

Clnss ofscrvice: Alf

TitIe: CUSTOMER’S RIGHTS AND MSPONSIBILXT’IES

JUH

8.4. CUSTOMER’S RIGHT TO STOP SERVICE

5.4. I . Unless the Cooperative has a specific contract to provide the customer service for a term of years under an agreement for eIectric service, the customer must notify the Cooperative at least five days prior to the date service is no longer required on the premises. If the Cooperative has a written agreement for electric service covering sewice being provided to the customer, the customer may discontinue service under the terns and conditions as set forth in such agreement for electric senice.

8.5. CUSTOMER’S INSTALLATION

8.5.1. Compliance with Recognized Standards

k The customets installation shall meet or exceed all requirements of the National Electrical Safety Code and all state and local regulations applicable thereto, at the time of such installation.

8.5.2. Service from Cooperative

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

THS SPA= FORPSC USE ONLY

ARKANSAS PUBLlC SERVICE COMMLSSION APPROVED

ARKANSAS m L r c SERVICE COMMISSION

Orieinnl StreetNo. 31

Replacing Sheet No.

Cnrroll Electric Cooperative Corporation Name of Company

Kind of Service: Electric Clnss of Sentice:

Part TV. PoIicy ScheduIe No. 8

TitIe: CUSTOMER’S RIGHTS AND RESPONSIBILITIES

FILEG

B. The point of attachment of Cooperative facilities to the customer‘s building and the nature and characteristics of service will be given in writing for all new installations and for aIterations or additions to existing installations. The Cooperative WilI not be responsible when such information is given verbaIIy.

X.5.3. Nature and Use of Installations

k The customer will select and operate his equipment in such manner that it will not adversely affect the Cooperative‘s electric service either to the customer or to others. When the Cooperative suppIies three phase service, the customer wilI controI his use of the electric service so that the load at the point of deIivery wilI be maintained in reasonable electrical balance between the phases.

8.5.4. Grounding

A. The customer shall be responsibIe for the installation and maintenance of an electrical ground which meets or exceeds a11 requirements of the NationaI Electrical Safety Code, and all state and local regulations applicable thereto at the time ofsuch instaIIation for grounding the neutral bus of the senice entmce panel, main disconnecting switch, or main circuit breaker.

THIS SPACE FORPSC USE 0ET.Y

ARKANSAS PUBLIC SERVICE COMMISSION APP2OVEO

JUN 8 ‘95 OAOER 2 9 5 - 0 6 6 - T F

ACK. FirBLlC. 5 E N . COHH. . ] b G ! .4<F~ER5

SECFkC: i A S Y 2F COHH. ARK4NSAS PUBLTC SERVXCE COMMISSION

Rep 1 acing Sheet No.

Cartoll 'Electric Coonmtive Corporation Nme of Company

Kind of Scrvice: Electric Class of Service:

Part ZV. Policy ScheduIe No. 9

Title: BILLING

JUH t; I1 20 A1 '55

PScFiteMarkOrrly

9.1. mTERIIEADINGAND BILLING

9.1.1. The Cooperative shaII determine the method of obtainins the meter reading each month to be used in biIIing the customer for electric service supplied.

9.1.2. Nonreceipt of bills by the customer shall not release or diminish the obligation ofthe customer with respect to payment thereof.

9.2. RECONNECTION

9.2.1. Electric service that has been suspended because of the customefs failure to pay a delinquent bill shall be restored duriq the regular working hours of Cooperative personnel (8:OO a.m. to 4:30 p.m., Monday through Friday) and a reconnection fee, as approved by the Commission, shall be paid in addition to settlement of the delinquent bill and other appIicabIe charses. Electric service may be restored after regular working hours when arrangement or payment of the bills and fees are made during the regular working hours specified above. However, when arrangements are made after regdar employee working hours for reconnection of meters suspended for dehquency, an after- hours reconnection fee, as approved by the Commission, shall be collected prior to reconnection of the service. If the account was disconnected for deIinquency on Friday or a day precedinz a Cooperative observed holiday, the regular reconnection fee would be charged.


On'Qiinal SheetNo. 83

R cp 1 n c in g Sheet No.

C n m l l Electric Coopcmtive Cornomtion Nnme o€ Company

Kind ofservice: Electric

Part VI. PoIicy Schedule No. 9

Title: BELING

Class of Sewice: &

9.3.

9.4.

9.5.

SEPAhUE BILLING ' FOR EACH POINT OF DELIVERY

9.3.1. Service at separate locations or addresses will not be combined for billing. At each point of delivery, service shaII be metered and billed separately for each customer served. Whenever for any reason the Cooperative furnishes service to a singe customer at two or more points of metering, each point of metering shall be considered a separate point of delivery except as may othenvise be provided in a specid ageement for electric service.

BILLING ADJUSTMENTS

9.4.1. In the event that any routine or special test of a Cooperative watt-hour meter discloses an average accuracy ofregistration in error by more than &:two percent (2%) as determined by the method prescribed in the Meter Testing Programs tarifF, a correction to the customer shall be made in accordance with Rule 5.19. of the Commission's General Service Rules.

SELECTION OF U T E SCHEDULE

9.5. I. When a prospective customer makes appIication for electric service, the Cooperative will select the rate schedule most favorable to the customer for the 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 info mat ion.

9.5.2. If the Cooperative bills erroneousIy for reasons other than meter mor, refunds or back bilIing shall be made in accordance with Rule 5.19. of the Commission's General Senice Rules.

TfIJS SPACE FORPSC USE ONLY

ARKANSAS PUBLIC SEHVlCE COMMISSION APPRDVED

JUN 8 '95 ORDER 2

ARKANSAS PuBLrc SERVICE COMMISSION

Oricinnl SheetNo. 84

Replacing Shcet No.

Carroll Electric Coopemtive Cornomlion Name of Cmpnny

Kind of Service: EIectric

Part IV. Policy ScheduIe No. IO

TitIe: POLE IDENTIFXCATlON

Class of Service: Alt:

IO.

10.1.

10.2.

POLE IDENTITICATTON

The Cooperative will use an aIuminurn tas one and one-half inches (1 'I") in height with the abbreviation "CECC" embossed on it to identify poles owned by the Cooperative. The aluminurn tag will be attached to the pole with one inch (1") galvanized nails, approximately five to six feet (5-6') above the ground.

The Cooperative wilI install a numbered tas which reflects the focation of poles by township, section, and grid number on every junction poIe, dead-end pole, and any pole with specid equipment attached. This tag will also be made of ahminum, one and one-half inches (1 %") in height, with the identification number embossed on it and will be attached to the pole with one inch (I") galvanized nails, approximateIy five to six feet (5-63 above the ground.

THIS SPACE FOR FSC USE ONLY

ARKANSAS PUBLTC SERVICE COMMTSSTON

Orieinnl SheetNo. 85

Rqlncing Sheet No.

Cnmll Electric Cooperative Cornoration Name of compnny

Kind of Smvice: ]Electric

Part Policy ScheduIe No. 11

Title: VOLTAGE VF,"ICATION PLAN

Class of Senfce: &

11. VOLTAGE VERFICATTON PLAN

11.1. ELECTRIC VOLTAGE VERIFICATION PLAN

I 1. I. I. By December 3 1, 1997, Carroll Electric Cooperative Corporation wilI have permanently instdIed, at each of its distribution substations, equipment that verifies voItage levels by recording continual voltage readings.



Replacing Sheet No.

CarrolI Electric Cooperative Corporation Name of Company

I Kind of Service: EIectric Class of Service: All

Part IV. Policy Schedule No.: 12 WE Fde Uah Ony EMERGENCY LOAD CONSERVATION AND

Tit'e: CURTAILMENT PLAN

12. EMERGENCY LOAD CONSERVATlON AND CURTAILMENT PLAN (AT)

12.1. INTRODUCTION

Carroll Electric Cooperative Corporation (Cooperative) and the Electric Cooperatives of Arkansast (ECOA) function together to design and maintain an Emergency Load Conservation and Curtailment Plan (ELCCP).

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

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

When called upon by Arkansas Electric Cooperative Corporation (AECC), the Reliability Coordinator or the Transmission Operato

k % % ! % ~ ~ L I ~ SERbtCE COMMJS;SIO~ to achieve the necessary load reduction. tiv will im lement the ELCCP

A P PRUV E D

' Arkansas Electric Cooperative Corporation, Arkansas Valley Electric Cooperative Corp. (Ozark, Arkansas); Ashley- Chicot Electric Cooperative, Inc. (Hamburs, Arkansas); C&L Electric Coopcmtivc Corp. (Star City, Arkansas); Cam11 Electric Cooperative Coy. (Benyville, Arkansas); Clay County Electric Coopentivc Corp. (Corning, Arkansas); Craighcad EIectric Cooperative C o p (Jonesboro, Arkansas); Farmers Electric Coopcrativc Corporation (Newport, Arkansas); First Electric Cooperative Corp. (Jacksonville, Arkansas); Mississippi County Electric Coopcntivc, Inc. (Blytheviffc. Arkansas); North Arkansas Electric Cooperative. Inc. (Salem, Arkansas); Ouachita Electric Cooperative Cop. (Camden, Arkansas); Ozarks Electric Cooperative Coy. (FayetteviIle, Arkansas); Petit Jean Electric Cooperative Cow. (Clinton, Arkansas); Rich Mountain Elcctric Coopcrative, Inc. (Mena, Arkansas); Soutli CentnI Arkansas Electric Coopcrativc, Inc. (Arkadelphia, Arkansas); Southwcst Arkanses Electric Cooperative Cop. (Texarknnp, Arkansas); and Woodruff Electric Coopcrative Cop. (Forrest City, Arkansas).



Replacing Sheet No.

CarroII Electric Cooperative Corporation Name of Company

Kind of Service: Electric Class of Senrice: All

Part IV. Policy Schedule No.: 12 PSC File Mah Only EMERGENCY LOAD CONSERVATION AND

C U RTAlLM ENT PLAN Tit'e:

12.2. ELCCP OVERVIEW

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

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

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

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

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

LEVEL 1 Interruptible Loads (IC) Sewed Under an IC Rider

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

LEVEL 2 Reduce Any Non-Essential Cooperative Facilities

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

Examples: Lighting loads, non-essential equi summer and 65 degrees in winter), and turnin


Origlnal SheetNo. 88

Replacing Sheet No.

1 ARK. PUBLIC S E N COHF


Kind of Service: Electric Class of Senrice: All

Part 1V. Policy Schedule No.: 12 PSC Fire Mark my EMERGENCY LOAD CONSERVATION AND

CURTAILMENT PLAN

12.2. ELCCP OVERVIEW (continued)

LEVEL 3 Voluntary Reductions (General)

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

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

LEVEL 4 Voluntary Reductions (Prearranged)

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

LEVEL 5 Use of Cooperative and Other ECOA Load Management Systems

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

LEVEL 6 Reduce Voltage

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

LEVEL 7 Manual Switching

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

In making that selection, AECC and Cooperative take into account the need to maintain critical loads essential to the health, safety a n d A y q k M f i m i - @ . SERVICE COMMISSION

APPROVED

U 42.3. REPORTING PROCEDURES

1 0 o s 9 Uoon imdementation of the ELCCP, the (APSC) and oiher appropriate governmental agencies shall be notified by either AECC andlor Cooperative. As soon as practical or as required, AECC andlor Cooperative will file necessary follow-up reports to meet APSC andlor other governmental agency requirements.

ARKANSAS PUBLIC SERVICE COMTvlTSSION

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