Rappahannock Electric Cooperative€¦ · Rappahannock Electric Cooperative Details of Ratemaking...

Rappahannock Electric Cooperative Details of Ratemaking Adjustments

Adjustment Nos.

Description Line No . Operating Revenue

1 Base Rate 2 Riders 3 WPCA 4 Schedule LP-2 5 Growth Adjustment 6 Subtotal 7 Fee Revenues 10 Other Revenue 11 Total Revenue 12 13 Production & Purchased Power 15 Margin Stabilization 16 Other Operating Expenses 17 Depreciation 18 Tax Expense - Property 19 Tax Expense - Other 20 Total Operating Expenses 21 22 Operating Margins 23 24 Less : Interest on Cust Deposits 25 Charitable and Educ Donations 26 Operating Margins - Adjusted 27 28 Plus:Capital Credits Accrued 29 Other Income 30 Less : Interest on Long Term Debt 31 Other interest Expense 32 Other Expense 33 Total Margin 34 35 Rate Base 36 Net Utility Plant 37 Allowance For Working Capital 38 Other Rate Base Deductions 39 Total Rate Base

Exhibit No. Witness: CBL & JDG

Schedule 4A Page I of 6

2-1

Column 2 Reclassify Total Pronerty Tax

(Col . 1) (Col . 2)

2-2 2-3

Property Tax-w/ Working Capital 2 ad di~ 29i~!g (Col . 3) (Col . 4)

$ (4,282,781) $ (4,282,781) $ $

$ 4,282,781 $ $ 4,282,781 $

$ $ (4,282,781) $ 4,282,781 $

$ (528,014) $ $ $ (528,014)

$ (528,014) $ $ $ (528,014)

W

Exhibit No. Witness : CBL & JDG

Schedule 4A Page 2 of 6

6-1 thru 6-7 6-8 6-9 6-10 6-11 6-12

Purchased Column 6 Operating Power

Total Revenues Expenses Uncollectibles Payroll FICA 401 K (Col . 5) (Col . 6) (Col . 7) (Col . 8) (Col . 9) (Col . 10) (Col . 11)

$ 3,047,880 $ 3,047,880 $ $ - $ - $ $ $ (3,503,875) $ (3,503,875) $ $ - $ - $ - $ $ (10,755,237) $ (10,755,237) $ $ - $ - $ - $ $ (1,428,768) $ (1,428,768) $ $ - $ - $ - $ $ (524,573 $ (524,573 $ $ - $ - $ - $

$ (13,164,573) $ (13,164,573) $ $ $ - $ - $

$ (13,164,573) $ (13,164,573) $ $ $ - $ $

$ (2,637,999) $ - $ (2,637,999) $ $ - $ - $ $ 3,946,615 $ - $ 3,946,615 $ $ - $ - $ -

$ 2,692,770 $ - $ - $ 780,038 $ 948,358 $ 67,973 $ 55,695 $ 370,152 $ $ - $ - $ - $ - $ $ 277,665 $ $ - $ $ - $ - $

$ 4,649,203 $ $ 1,308,617 $ 780,038 $ 948,358 $ 67,973 $ 55,695

$ (17,813,776) $ (13,164,573) $ (1,308,617) $ (780,038) $ (948,358) $ (67,973) $ (55,695)

$ (17,813,776) $ (13,164,573) $ (1,308,617) $ (780,038) $ (948,358) $ (67,973) $ (55,695)

$ 651,157 $ $ - $ $ $ $ $ 3,300,397 $ $ - $ $ $ $

$ (20,463,016) $ (13,164,573) $ (1,308,617) $ (780,038) $ (948,358) $ (67,973) $ (55,695)

$ 5,070,485 $ - $ - $ $ $ $ $ (781,567) $ - $ - $ $ $ $ $ 362,151 $ - $ - $ $ $ $

$ 4,651,069 $ - $ - $ $ $ $

11-A W

W



6-13 6-14 6-15 6-16 6-17 6-18 6-19

Pension Prepay Pension Cafeteria Major Storm Amortization Expense Plan Rate Case ROW Expense IT Expense

(Col . 12) (Col . 13) (Col . 15) (Col . 15) (Col . 16) (Col . 17) (Col . 18)

$ 789,108 $ (72,958) $ 125,122 $ 74,500 $ (185,914) $ (406,562) $ 3,947

$ 789,108 $ (72,958) $ 125,122 $ 74,500 $ (185,914) $ (406,562) $ 3,947

$ (789,108) $ 72,958 $ (125,122) $ (74,500) $ 185,914 $ 406,562 $ (3,947)

$ (789,108) $ 72,958 $ (125,122) $ (74,500) $ 185,914 $ 406,562 $ (3,947)

$ (789,108) $ 72,958 $ (125,122) $ (74,500) $ 185,914 $ 406,562 $ (3,947)

F" w Im %J w a



6-20 6-21 6-22 6-23 6-24 6-25 6-26

Property Cap. Rate Transportation Interest Insurance Change Expense Dues Depreciation Ta:g Income (Col . 19) (Col . 20) (Col . 21) (Col . 22) (Col . 23) (Col . 24) (Col . 25)

$ 71,113 $ 296,978 $ 122,076 $ 23,298 $ - $ - $ $ - $ - $ - $ - $ 370,152 $ - $ $ - $ - $ - $ - $ - $ 277,665 $

$ 71,113 $ 296,978 $ 122,076 $ 23,298 $ 370,152 $ 277,665 $

$ (71,113) $ (296,978) $ (122,076) $ (23,298) $ (370,152) $ (277,665) $

$ (71,113) $ (296,978) $ (122,076) $ (23,298) $ (370,152) $ (277,665) $

$ $ $ $ $ $ $ 651,157

$ (71,113) $ (296,978) $ (122,076) $ (23,298) $ (370,152) $ (277,665) $ 651,157

w



6-27 6-28 6-29 6-30

Interest Working Other Expense NUP Capital Rate Base (Col . 26) (Col . 27) (Col . 28) (Col . 29)

$ $ $

$ $

$ 3,300,397 $ $ $

$ (3,300,397) $ $ $

$ - $ 5,070,485 $ $ $ - $ $ (781,567) $ -

$ - $ - $ $ 362,151

$ - $ 5,070,485 $ (781,567) $ 362,151

I~A w a 141

w

Exhibit No. Witness : CBL & JDG


8-1 8-2 8-3 8-4 11-1 11-2 Adjustment to Adjustment to

Base Rate WPCA and Rate Adjustment to Working Remove Adjustment to Column 8 Revenue Rider Roll-in U ncollectible Capital Schedule TIVIR Uncollectible

Total Ad*ustment Adoustment Account Rate Base Discount Account (Col . 30) (Col . 32) (Col . 33) (Col . 34) (Col . 35) (Col . 36) (Col . 37)

$ 99,705,098 $ 99,705,098 $ - $ - $ - $ 4,864,966 $ $ (9,826,572) $ - $ (9,826,572) $ - $ - $ - $ $ (78.951,697) $ $ (78.951,697) $ - $ - $ $

$ 10,926.829 $ 99,705,098 $ (88,778,269) $ $ $ 4,864,966 $

$ 10,926,829 $ 99,705,098 $ (88,778,269) $ $ 4,864,966 $

$ 39,337 $ $ $ 39,337 $ $ $ 17,514

$ 39,337 $ $ $ 39,337 $ $ - $ 17,514

$ 10,887,492 $ 99,705,098 $ (88,778,269) $ (39,337) $ $ 4,864,966 $ (17,514)

$ 10,887,492 $ 99,705,098 $ (88,778,269) $ (39,337) $ $ 4,864,966 $ (17,514)

$ 10,887,492 $ 99,705,098 $ (88,778,269) $ (39,337) $ $ 4,864,966 $ (17,514)

$ 4,850 $ $ $ $ 4,850 $ $ 2,159

$ 4,850 $ $ $ $ 4,850 $ $ 2,159

H w 43 %J w

Rappahannock Electric Cooperative Detail of Ratemaking Adjustments For the 12 Months Ending December 31, 2012

Adj No. Description

2-1 Tax Expense - Property

2-2 Tax Expense - Property

2-3 Allowance for Working Capital

6-1 Base Rate Revenue

H Exhibit No.

Witness: CBL & JD40 Schedule 40 Page 1 of

Explanation of Operatinp Expense Adoustments Amount H

Adjustment to Reclassify Property Tax $ (4,282,781)

Adjustment to Reclassify Property Tax 4,282,781

Adjustment to Working Capital to Reflect Reclassified Taxes (528,014)

Adjust Base Rate Distribution Revenue for Unbilled Sales and Customer Growth

6-la Base Rate Revenue Adjust Base Rate ESS Revenue for Unbilled Sales and Customer Growth

6-2 Rider Surcharge Adjust to annualize Rider RS- 12 revenue based on rate year sales

6-3 Rider Surcharge Adj ust to annualize Rider RS- 13 revenue based on rate year sales

64 Rider Surcharge Adjust to annualize Rider NT revenue based on rate year sales

6-5 Fuel - WPCA Revenue Adjust to Annualize VrPCA Revenue Based on Rate Year Sales and the Current REC Fuel Rate

6-6 Purchased Power To Adjustment Bear Island Schedule LP-2 Revenue

6-7 Growth Adjust Adjustment to Roll Unbilled Revenue into Rate Year Sales Revenue Calculations

6-9 Purchased Power To adjust Purchased Power Expense for ODEC rate change

6-9 Other 0 & M Expense Adjustment to Uncollectible Accounts Expense

6-10 Other 0 & M Expense Adjustment to Payroll Expense

6-11 Tax Expense - Other Adjustment to Payroll Taxes Expense

6-12 Other 0 & M Expense Adjustment to 401 K Employer Contribution Expense

6-13 Other 0 & M Expense Adjustment to Reflect Pension Prepayment Amortization

6-14 Other 0 & M Expense Adjustment to Pension Expense

6-15 Other 0 & M Expense Adjustment to Cafeteria Plan Expense

6-16 Other 0 & M Expense Adjustment to Rate Case Expense

891,343

2,156,536

(1,080,903)

(2,824,487)

401,515

(10,755,237)

(1,428,768)

(524,573)

1,308,617

780,038

948,358

67,973

55,695

789,108

(72,958)

125,122

74,500


Adj No. Descrii)tion

6-17 Other 0 & M Expense







6-24 Depreciation & Amort Expense

6-25 Tax Expense - Property and Sales

6-26 Interest Income

6-27 Interest Expense

6-28 Net Utility Plant

6-29 Allowance for Working Capital

Exhibit No. Witness: CBL & JD43

Schedule 4 Page 2 of~

Explanation of Overatin?, Expense Adoustments Amount )4

Adjustment to Right of Way Clearing Expense (185,914)

Adjustment to Normalize Major Storm Damage

Adjustment to Information Technology Expenses

Adjustment to Property Insurance and Workers' Compensation

Adjust to Reflect Capitalization / Expense Limits Policy Change

Adjustment to Remove Non-recurring reimbursment of Transportatation Expense

Adjustment for Dues and Subscriptions

Adjustment to Depreciation Expense to reflect plant in service as of 5/31/2013 Adjustment to Property Tax to Reflect Taxable Plant at 5/31/2013, to Roll Sales and Use Tax Into Base Rates

Adjustment to Interest Income

Adjustment to Reflect Interest Expense on Long-Term Debt Through the Rate Year

Adjustment to Net Utility Plant to 5/31/2013 Level

Adjustment to Working Capital to Reflect Adjustments to O&M Expenses and Deferred Fuel Balance as of 5/31/2013

(406,562)

3,947

71,113

296,978

122,076

23,298

370,152

277,665

651,157

3,300,397

5,070,485

(781,567)

6-30 Other Rate Base Deductions Adjustment to Customer Deposits and Customer Advances as of 5/31/2013 159,510


AdJ No. Description

8-1 Base Rate Revenue

8-2 Roll-in Rider Surcharge & WPCA

8-3 Uncollectible Accounts

8-4 Working Capital

11-1 Schedule TMR Discounts

11-2 Uncollectible Accounts

11-3 Working Capital


Schedule 4B Page 3 of 3

Explanation of Operating Expense Adjustments Amount

Adjustment to increase base rate revenue to reflect the proposed retail rates 99,705,098

Adjustment to decrease revenue for the roll-in of rider surcharges and the (88,778,269) WPCA

To adjust uncollectible accounts expense for proposed revenues 39,337

To adjust working capital for 45 days of the uncollectible accounts expense adjustment 4,850

Adjustment to increase base rate revenue to remove Schedule TNIR discounts 4,864,966

To adjust uncollectible accounts expense for proposed revenues 17,514

To adjust working capital for 45 days of the uncollectib)e accounts expense adjustment 2,159

Ila w 0 W4

1~a

RAPPAHANNOCK ELECTRIC COOPERATIVE RATE SCHEDULES AND RIDERS

CLEAN

Exhibit No.-

I-A

Witness: DFK & JDG W Schedule : 5A 0 Pagel of4l 114

W

TRANSITION MIGRATION RIDER - NT

SCHEDULE TMR PA

APPLICABLE TO TRANSITIONING CUSTOMERS ON SCHEDULES A, B-1, B-3, and LP-1

ADJUSTMENT TO MITIGATE THE EFFECT OF MIGRATING TO SCHEDULES A, B-1, B-3. AND LP-1

Effective July 1, 2014, the bills to Transitioning Customers shall be decreased by the applicable credits and discounts as listed in the table below. The billing factors shall be adjusted annually in accordance with the Migration Plan as approved by the Commission in Case No. PUE-2013-00052 . Schedule TMR shall expire no later than June 30, 2017 .

The applicable Transition Mitigation Rider factor will be applied each month while in effect until changed, as prescribed by procedures approved by the Virginia State Corporation Commission .

This credit shall be applied against any minimum charge set out in the rate schedule and is credited to the Customers bill before any tax surcharge is levied against the Customer's total bill .

Transitioning Customers are customers of the Cooperative who receive service within the territory acquired by Rappahannock Electric Cooperative as approved in PUE-2009-000100 .

Schedule Factor Unit Schedule A Customers formerly served First 1,000 kWh $-0.00850 per kWh on Schedule R-NT Over 1,000 kWh $- 0.00050 per kWh Schedule B-1 Customers with demand Access Charge $-7.80 per customer less than 25 kW and Next 700 kWh $ 0.00000 per kWh formerly served on Over 700 kWh $-0.00500 per kWh Schedules C-NT and G-NT Schedule B-3 Customers with demand Access Charge - Single Phase $- 7.80 per customer greater than 25 kW and Access Charge - Three Phase $-13.25 per customer formerly served on First 100 kW $- 0.75000 per kW Schedules C-NT & G-NT Over 100 kW $ 0.00000 per kW

First 100 kWh/kW $- 0.00240 per kWh Next 100 kWh/kW $ 0.00000 per kWh Next 200 kWh/kW $ 0.00000 per kWh Over 400 kWh/kW $ 0.00240_ per kWh

Schedule LP-11 Customers with demand 57.99% per dollar of greater than 200 kW and distribution formerly served on revenue Schedule G-NT

Effective: Bills issued On and After July 1, 2014 through June 30, 2015.

Exhibit No . Witness : DFK & J Schedule: 5A Page 2 of 41

W RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA

POWER COST ADJUSTMENT CLAUSE SCHEDULE PCA-11

AVAILABILITY

Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission .

11 . APPLICABILITY

This schedule is applicable to and becomes a part of each electric rate schedule in which reference is made to Power Cost Adjustment Rider, Schedule PCA-1 .

The Cooperative shall apply a uniform per kWh charge or credit to applicable sales in accordance with the following terms. All definitions and calculations shall be in reference to the total Cooperative system but shall exclude any kWh sales, kWh purchases, Energy Supply Service revenues, and power costs related to service to any customer under an electric service tariff that separately provides for a direct pass through of purchased power expense .

Ill . DEFINITIONS

PCA Power cost adjustment factor .

ESS Revenue Revenue produced by the base Energy Supply Service part of each tariff .

ESS Base $0.07244 per kWh sold reflecting the annual system average base ESS Revenue per kWh sold .

kWhs The total projected kWh to be purchased in the applicable rate year times the Loss Factor.

PCP The projected total cost of purchased power for the applicable rate year from all sources, including costs associated with the Energy Adjustment part of the ODEC Tariff, that will be charged to Accounts 555 through 557.

0 Any Over Recovery balance recorded on the Cooperative's balance sheet as of the most recent accounting month available.

Schedule PCA-1 Power Cost Adjustment Rider Page 1

Filed State Corporation Commission Effective for service rendered on and after July 1, 2014 .

Rappahannock Electric Cooperative Schedule PCA-11 Page 2

IV.

DEFINITIONS (continued)

Exhibit No . Witness: DIFK & JDG Schedule : 5A Page 3 of 41

U Any Under Recovery balance recorded on the Cooperative's balance sheet as of the most recent accounting month available.

EA ODEC's Energy Adjustment rate from time to time, expressed in $ per kWh.

SEPA Factor One minus the ratio of annual SEPA kWh purchased to total annual kWh purchased based on historical data .

Loss Factor One minus the estimated kWh loss percentage based on historical data.

FORMULA

In any month there is a change in : a) the ODEC base rates, b) the SEPA Capacity rate, or c) the SEPA capacity allocation, for application in each month thereafter until changed in accordance with this tariff, a PCA will be computed as follows :

PCA PCP-0+U ESS Base + EAr kWhs

Where ; EAr will be zero unless there is a change in the EA relative to the EA used for PCp in which case EAr will be calculated as follows and the PCA will be modified to reflect the new EAr:

EAr = (New EA - EA included in PCp) x SEPA Factor - Loss Factor

V OVER AND UNDER RECOVERY AMOUNT

The over or under recovery of power cost will be calculated and booked monthly based on the difference between actual purchased power costs in the month (including any charge or credit for an ODEC margin stabilization adjustment) and revenues booked in the month equal to the base ESS Revenues; plus, the PCA revenues ; less, the product of booked kWh sales for the month times $0.00080., Booked revenues and kWh sales will be net of any applicable unbilled adjustments.

$0.00080 represents cost per kWh of the allocated non-purchased power costs included in the base G&T rates.

Interim Schedule PCA-1 Power Cost Adjustment Rider Page 2

)4 W 0-

C5

Filed State Corporation Commission Effective for bills rendered on and after July 1, 2014.

Rappahannock Electric Cooperative Schedule PCA-1 Page 3

Exhibit No. H Witness: DFK & JD&J Schedule: 5A Page 4 of 41

W 40

(Over) and Under Recovery Amounts, if any, will be credited or debited to accounts 2532.0 Deferred Credit - PCA or 1860 .59 Deferred Debit - PCA, with <0 corresponding credits or debits to 555.14 Purchased Power - PCA. 10A

VI MODIFICATIONS TO THE PCA

The intent of the PCA is to recover the Cooperative's purchased power cost on a dollar for dollar basis. At any time, the Cooperative may re-calculate the PCA to minimize (over) or under recovery of power cost if actual data and more current information for the remainder of the applicable rate year indicate that the PCp, kWhs, or both have changed enough to warrant a change in the PCA, or if the (Over) or Under Recovery Amounts become excessive. At a minimum, the PCA will be recalculated once in any twelve month period to adjust for any accumulated Over or Under Recovery Amount.

Vil RATE YEAR

The rate year is the twelve month period beginning with the month in which a change in the PCA will occur that is not solely due to a change in EAr.

Interim Schedule PCA-1 Power Cost Adjustment Rider

Filed State Corporation Commission Effective for bills rendered on and after July 1, 2014 .

Page 3

RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA

POWER COST ADJUSTMENT RIDER SCHEDULE PCA-11 (IN

Exh i bit No.- Witness: DFK & JDG Schedule : SA Page 5 of 41

AVAILABILITY


APPLICABILITY

This schedule is applicable to and becomes a part of each electric rate schedule in which reference is made to Power Cost Adjustment Rider, Schedule PCA-11 .

The Cooperative shall apply a uniform per kWh charge or credit to applicable sales in accordance with the following terms. All definitions and calculations shall be in reference to the total Cooperative system but shall exclude any kWh sales, kWh purchases, Generation and Transmission Supply revenues, and power costs related to service to any customer under an electric service tariff that separately provides for a direct pass through of purchased power expense.

DEFINITIONS

PCA Power cost adjustment factor .

ESS Revenue Revenue produced by the base Energy Supply Service part of each tariff .

ESS Base Not applicable

kWhs Not applicable

PCP Not applicable.

0 Any Over Recovery balance recorded on the Cooperative's balance sheet as of the most recent accounting month available.

U Any Under Recovery balance recorded on the Cooperative's balance sheet as of the most recent accounting month available .

Schedule PCA-1 Power Cost Adjustment Rider Page I

I,& W Q 14pa W

Filed State Corporation Commission Effective for service rendered on and after January 1, 2014.

1~ .a

Rappahannock Electric Cooperative W

Interim Schedule PCA - I Exhibit No.- <0 Witness : DFK & JDG %J

Page 2 Schedule : 5A W Page 6 of 41

IV . FORMULA

PCA = Rider RS1 2-1 + Rider RS1 3-1 + WPCA Fuel Factor

V. OVER AND UNDER RECOVERY AMOUNT

The over or under recovery of power cost will be calculated and booked monthly based on the difference between actual purchased power costs in the month (including any charge or credit for an ODEC margin stabilization adjustment and excluding any Transition Payments) and revenues booked in the month equal to the base ESS Revenues; plus, the PCA revenues; less, the product of booked kWh sales for the month times $0.00030 .1 Booked revenues and kWh sales will be net of any applicable unbilled adjustments .

(Over) and Under Recovery Amounts, if any, will be credited or debited to accounts 2532.0 Deferred Credit - PCA or 1860.59 Deferred Debit - PCA, with corresponding credits or debits to 555.14 Purchased Power - PCA.

V1 . MODIFICATIONS TO THE PCA

The intent of the PCA is to recover the Cooperative's purchased power cost on a dollar for dollar basis . At any time, the Cooperative may re-calculate the PCA to minimize (over) or under recovery of power cost if actual data and more current information for the remainder of the applicable rate year indicate that the conditions have changed enough to warrant a change in the PCA, or if the (Over) or Under Recovery Amounts become excessive .

VII . RIDER FIS 11 -1 -NT

Applicable to customers of the Cooperative who receive service within the territory acquired by Rappahannock Electric Cooperative as approved in PUE-2009-000100 .

a. A charge of $0.01128 per kWh, and ; b. A charge of $ 0.00172 per kWh be applied through June 30, 2014, in

accordance with the conditions prescribed in requirement 2) of the Final Order in Case No. PUE-20009-00101 .

$0.00030 represents cost per kWh of the allocated non-purchased power costs included in the base G&T rates.

Interim Schedule PCA-1 Power Cost Adjustment Rider Page 2

Filed State Corporation Commission Effective for service rendered on and after January 1, 2014.


FARM, HOME AND CIVIC SERVICE SCHEDULE A

AVAILABILITY

Exhibit No. Witness : DfK & JDG Schedule: 5A Page 7 of 41


APPLICABILITY

Applicable to farms, single residences, private schools, church sanctuaries, volunteer fire departments, volunteer rescue squads, civic clubs and similar non-profit community service organizations, along the lines of the Cooperative for all uses . The rated capacity of any motor served under this schedule in excess of ten horsepower (10 h.p .) shall be subject to the approval of the Cooperative as to type and starting characteristics, to prevent disturbance of service to other consumers . With the exception of church sanctuaries, the maximum demand to be provided under Schedule A shall be 200 kW.

TYPE OF SERVICE

60 hertz, single-phase, at available secondary voltage, and multi-phase, where available, at available secondary voltage, under special contract .

IV MONTHLY RATE

A. Distribution Delivery Charges :

Access Charges-Single-Phase Service Multi-phase Service

$10 .00 per month $12.15 per month

Energy Delivery Charges: First 300 kWh per month Over 300 kWh per month

B. Electricity Supply Service Charges:

All kWh per month

@ $0.04065 per kWh @ $0.02835 per kWh

@ $0.07676 per kWh

Note: The above Delivery Service and Energy Supply Service charges apply to those Customers who have the Cooperative as their energy service provider . Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier other than the Cooperative as their energy provider .

Schedule A Effective: On all Bills issued on and After July 1, 2014

H W

W 0

V.

V1 .

Vil

Exhibit No. Witness : DJFK & JDG

Rappahannock Electric Cooperative Schedule : 5A Schedule A Page 8 of 41

Page 2 W

MINIMUM MONTHLY DELIVERY CHARGE

The minimum monthly delivery charge shall be the Access Charge under Part A of the Monthly Rate above unless otherwise provided for under special contract.

POWER COST ADJUSTMENT CLAUSE

The amount of charges calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's Power Cost Adjustment Clause, Schedule PCA-1 .

TERMS OF CONTRACT

Open order, unless the customer or the Cooperative requests a contract specifying a mutually agreed upon term . In no case, however, shall the term of any contract be less than one (1) year.

Schedule A Effective : On all Bills Issued on and After July 1, 2014


SMALL GENERAL SERVICE SCHEDULE B-1

IV

Exhibit No . Witness: Dk & JDG Schedule: 5A Page 9 of 41

AVAILABILITY


APPLICABILITY

Applicable to all types of Customers for service along the'lines of the Cooperative, for all uses unless another rate schedule is specifically applicable . The maximum demand to be provided under Schedule B-1 shall be 25 kW .

TYPE OF SERVICE

60 hertz, single-phase, at available secondary voltages .

MONTHLY RATE


Access Charges: Single-Phase Service $28 .00 per month

Energy Delivery Charges: All kWh delivered @ $.02893 per kWh

B. Electricity Supply Service Charges :

All kWh @ $.06915 per kWh

V

Note: The above Delivery Service and Energy Supply Service charges apply to those Customers who have the Cooperative as their energy service provider . Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier other than the Cooperative as their energy provider .

.MINIMUM MONTHLY DELIVERY CHARGE

The minimum monthly delivery charge shall be the Access Charge under Part A of the Monthly Rate above. For Customers requiring more than 15 kVA of transformer capacity, the minimum monthly distribution delivery charge shall be increased at the rate of one dollar ($1 .00) for each additional kVA or fraction thereof required . The foregoing will apply unless otherwise provided for under special contract .

Schedule B-1 Effective: On All Bills Issued on and After July 1, 2014

W 0

IVA

Exhibit No.- Witness: DFK & JDG

Rappahannock Electric Cooperative Schedule : 5A Schedule B-1 Page 10 of 41

Page 2

Vi . POWER COST ADJUSTMENT CLAUSE


Vil

Vill

DETERMINATION OF BILLING DEMAND

The billing demand shall be the highest average kilowatt load measured over any period of fifteen (15) consecutive minutes during the month for which the bill is rendered as indicated or recorded by a demand meter.

CONDITIONS OF SERVICE

The rated capacity of motors in excess of ten horsepower (10 h.p .) shall be subject to the approval of the Cooperative as to type and starting characteristics, to prevent disturbance of service to other Customers .

X TERMS OF CONTRACT

Open order, unless the Customer or the Cooperative requests a contract specifying a mutually agreed upon term . In no case, however, shall the term of any contract be less than one (1) year .

Schedule B-1 Effective : On Ali Bills Issued on and After July 1, 2014

1-h W

W a



AVAILABILITY

Exhibit No. Witness : Dk & JDG Schedule : 5A Page I I of 41

Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission.

APPLICABILITY

Applicable to multi-phase Customers, and any single-phase Customer whose actual demand exceeds 25 kW in the current month or preceding 11 months, for all uses unless another rate schedule is specifically applicable . The maximum demand to be provided under Schedule B-3 shall be 200 kW.

111 . TYPE OF SERVICE

60 hertz, multi-phase where available, at available secondary voltages .

IV . MONTHLY RATE


Single-Phase Access Charge @ $28.00 per month

Multi-Phase Access Charge : @ $47.50 per month

Demand Delivery Charge : First 100 kW of billing demand delivered @ $1 .50 per kW Over 100 kW of billing demand delivered @ $9.00 per kW

Energy Delivery Charges : First 100 kWh per kW delivered @ $0.02896 per kWh Next 100 kWh per kW delivered @ $0.02596 per kWh Next 200 kWh per kW delivered @ $0.01696 per kWh Over 400 kWh per kW delivered @ $0.01396 per kWh


Energy Charges : First 100 kWh per kW @ $0.07381 per kWh Next 100 kWh per kW @ $0.07239 per kWh Next 200 kWh per kW @ $0.06559 per kWh Over 400 kWh per kW @ $0.05249 per kWh

~A

W

0

W4

W

Schedule B-3 Effective: On All Bills Issued on and After July 1, 2014

Rappahannock Electric Cooperative Schedule B-3 Page 2

Exhibit No.- I~A Witness : DFK & JDG W Schedule : 5A 42 Page 12 of 41 041

W

Note : The above Delivery Service and Energy Supply Service charges apply to those Customers who have the Cooperative as their energy service provider. Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier, other than the Cooperative, as their energy provider.

V. MINIMUM MONTHLY DELIVERY CHARGE

The minimum monthly delivery charge shall be the Access Charge under Part I of the Monthly Rate above. For Customers requiNng more than 45 kVA of transformer capacity, the minimum monthly distribution delivery charge shall be increased at the rate of $1 .00 for each additional kVA or fraction thereof required . The foregoing will apply unless otherwise provided for under special contract .

VI . POWER COST ADJUSTMENT CLAUSE


VII . DETERMINATION OF BILLING DEMAND


Vill . CONDITIONS OF SERVICE

The rated capacity of motors in excess of ten horsepower (10 h - p .) shall be subject to the approval of the Cooperative as to type and starting characteristics, to prevent disturbance of service to other Customers .

IX . TERMS OF CONTRACT


Schedule B-3 Effective : On All Bills Issued on and After July 1, 2014

Rappahannock Electric Cooperative Schedule LP- I Page I

RAPPAHANNOCK ELECTRIC COOPERATIVE . Fredericksburg, VA

LARGE POWER SERVICE SCHEDULE LP-1

AVAILABILITY

Exhibit No. Witness: DFK & JDG Schedule : 5A Page 13 of 41


APPLICABILITY

Applicable to all Customers along the lines of the Cooperative contracting for a load of 100 kW or more .

TYPE OF SERVICE

Multi-phase, 60 hertz, at available voltage .

MONTHLY RATE


IV

Access Charge : @ $100 .00 per month

Demand Delivery Charges : First 100 kW of billing demand delivered @ $1 .50 per kW Next 400 kW of billing demand delivered @ $1 .25 per kW Next 1,500 kW of billing demand delivered @ $ 1 .10 per kW Over 2,000 kW of billing demand delivered @ $1 .00 per kW

Energy Delivery Charges: First 100 kWh per kW delivered @ $0.01778 per kWh Next 100 kWh per kW delivered @ $0.01558 per kWh Next 200 kWh per kW delivered @ $0.01018 per kWh Over 400 kWh per kW delivered @ $0.00818 per kWh

Voltage Discount (kW) : 2 kilovolt (kV) to 15 kV $0.25 per kW Over 15 kV $0.50 per kW

Schedule LP-1 Effective: On All Bills Issued on and After July 1, 2014

I-A W

W 0

Rappahannock Electric Cooperative Schedule LP-1 Page 2

IV . MONTHLY RATE (Continued)

B. Electricity Supply Service (ESS) Charges:

Demand Charge : All kW of ESS Billing Demand

Exhibit N,.-Witness: DFK & JDG Schedule : SA Page 14 of 41

@ $8.15 per kW

Energy Charges: First 100 kWh per kW of ESS Billing Demand @ $0.05417perkWh Next 100 kWh per kW of ESS Billing Demand @ $0.05017perkWh Next 200 kWh per kW of ESS Billing Demand @ $0.04857perkWh Over 400 kWh per kW of ESS Billing Demand @ $0.04647perkWh

V

V1 .


The minimum monthly delivery charge under IV . A of the Monthly Rate shall be the greatest of the amounts determined by the following :

A . $250.00 .

B . $0.50 times the highest average kW of demand measured in any 15-minute interval during the current billing month .

C . The minimum specified in any contract currently in force .

DETERMINATION OF BILLING DEMANDS

A. The monthly distribution delivery demand delivered applicable to IV . A . shall be the greatest of:

a . Except as determined under VI . A. 2 . (below)

i . The highest average kW of demand measured in any 15-minute interval during the current billing month, or

ii . Forty percent (40%) of the highest billing demand, as determined by subparagraph A, section I or subparagraph B, section 1, for the preceding eleven (11) months, or

iii . 100 kW.

b. For Customers whose billing demand as determined under VI . A. 1 . above exceeds 1,000 kW, an alternate method of determining billing demand, described below, is available upon request by the Customer. The Customer shall pay the Cooperative an amount equal to the cost of furnishing and installing all equipment required for determining the off-peak and on-peak demands . The equipment shall remain the property of the Cooperative. The alternate monthly billing demand shall be the higher of:


I~A W

W a


Exhibit No. Witness: D17K & Mr, Schedule : SA Page 15 of 41

DETERMINATION OF BILLING DEMANDS (CONT.) i . The highest average kW of demand measured in any 15-minute interval

during the on-peak hours of the current billing month, plus forty percent (40%) of the excess of this amount determined in a similar manner during off-peak hours, or

H. Forty percent (40%) of the highest billing demand, as determined by VI . A. 1 . (i) or VI . A. 2. (i) for the preceding eleven (11) months .

B. The ESS Billing Demand shall be the highest average kW of demand measured in any 15-minute interval during the current billing month.

C. On-peak hours shall be the same as those specified in the Rate Schedule under which the Cooperative purchases power and energy from its principle wholesale power supplier, currently the hours between 10:00 a.m. and 10:00 p .m ., Mondays through Fridays, for the months of June through September . All other hours shall be considered off-peak hours .

Note : The above Delivery Service and Energy Supply Service charges apply to those Customers who have the Cooperative as their energy service provider . Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier other than the Cooperative as their energy provider

Vil

Vill

IX .

POWER FACTOR

The Customer agrees to maintain unity power factor as nearly as practicable . The Cooperative reserves the dght to measure such power factor at any time . Should such measurements indicate that the power factor at the time of the maximum demand is less than 90 percent (90%) lagging, the demand for billing purposes may be the demand as indicated or recorded by the demand meter multiplied by 90 percent (900/6), and divided by the percent power factor .

WHOLESALE POWER COST ADJUSTMENT CLAUSE

The amount of charge calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's Power Cost Adjustment Clause, Schedule PCA-1 .

TERM OF CONTRACT

The term of contract for purchase of electricity under this schedule shall be the term mutually agreed upon and set forth in a w6ften contract, if such is required, but in no case shall the term of contract be less than one (1) year .

14 W 40 %J W 0


Rappahannock Electric Cooperative Schedule HD-1 Page I


LARGE POWER HIGH DIVERSITY SERVICE SCHEDULE HD-1

IV

V.

AVAILABILITY

Exhibit No. Witness: DFK & Mr, Schedule: SA Page 16 of 41

Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission, except those who have an Electricity Supplier other than the Cooperative as their energy provider .

APPLICABILITY

Applicable upon request to Customers otherwise served under the LP-1 Schedules and contracting for a load of 500 kW or more .

CONDITIONS OF SERVICE

A. The Customer shall pay to the Cooperative charges in accordance with Schedule EF based on the cost of furnishing and installing all additional equipment required to take service under this Schedule .

B . The Customer may select service under Schedule HD-1 provided that the Customer takes service under Schedule HD-1 for a minimum of twelve (12) consecutive months .

TYPE OF SERVICE


MONTHLY RATE


Access Charge : @ $200.00 per month

Demand Delivery Charge : All kW of Maximum Billing Demand delivered @ $ 1 .10perkW

Energy Delivery Charges : First 100 kWh per kW delivered @ $0.02150 per kWh Next 100 kWh per kW delivered @ $0.01930 per kWh Next 200 kWh per kW delivered @ $0.01390 per kWh Over 400 kWh per kW delivered @ $0.01190 per kWh

Schedule HID-1 Effective: On All Bills Issued on and After July 1, 2014

i-A W 0 SJ W 0 ki

Rappahannock Electric Cooperative Schedule HD-1 Page 2

V. MONTHLY RATE (CONT.)


Wholesale Billing Demand:

Exhibit No. Witness: DFK & JDG Schedule: 5A Page 17 of 41

1 . The charges for Wholesale Billing Demand will be based on the prevailing ODEC transmission level demand rates adjusted to compensate for the applicable distribution losses on a customer specific basis.

2. Excess Demand charge of $2.38 per kW of Excess Demand will apply each month.

Energy Charges:

1 . The Customers kWh usage for the month times the prevailing ODEC Transmission Energy Rate adjusted to compensate for the applicable distribution losses .

2. The Customer's kWh usage for the month times the corresponding monthly ODEC Energy Cost Adjustment adjusted to compensate for the applicable distribution losses

V1

VII


The minimum monthly delivery charge under the above rate shall be the greater of the amounts determined by the following :

A. The Access Charge plus the demand charges under Section V, Part A .

B. The minimum specified in any contract currently in force.


The billing demands for each month shall be:

A. Distribution Delivery Demand - The greater of : a) the highest average kW of demand measured in any 15 minute interval during the current billing month, or b) 500 kW.

B. Wholesale Billing Demand - Wholesale Billing Demand, or Demands, will be based on the Customers actual demand or demands measured coincident with the billing demands as defined in the prevailing ODEC rate applicable to the Cooperative .

C. Excess Demand - The highest average kW of demand measured in any 15 minute interval during the current billing month less the Monthly CP Demand . Monthly CP Demand shall be the Customer's maximum hourly integrated demand occurring in

Schedule HD-1 Effective: On All Bills Issued on and After July 1, 2014

I-A

W 0 %J

W

Rappahannock Electric Cooperative Schedule HD-1 Page 3

Exhibit No.-Witness : DFK & JDG

Schedule : 5A Page 18 of 41

the CP Hour . The hour of the CP (CP hour) is the hour of each month in which the ODEC Monthly Delivered Demand applicable to the Cooperative is determined .

Vill

ix

X

PEAK PERIOD NOTIFICATION

The Cooperative shall provide peak period notification by use of the Cooperative's load management system, telephone system, or other appropriate means. The Customer has sole responsibility for reducing electric load upon receiving notification .

POWER FACTOR

The Customer agrees to maintain unity power factor as nearly as practicable . The Cooperative reserves the right to measure such power factor at any time . Should such measurements indicate that the power factor at the time of the maximum demand is less than 90 percent (90%) lagging, the demand for the billing purposes may be the demand as indicated or recorded by the demand meter multiplied by 90 percent (90%) and divided by the percent power factor .

TERM OF CONTRACT

The term of contract for purchase of electricity under this schedule shall be the term mutually agreed upon and set forth in a written contract, if such is required, but in no case shall the term of contract be less than one (1) year.

Schedule HID-1 Effective : On All Bills Issued on and After July 1, 2014

I-A W

W

RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, Virginia

INTERRUPTIBLE SERVICE RIDER SCHEDULE IS-1

AVAILABILITY

Exhibit No . Witness : DFK & JDG Schedule : 5A Page 19 of 41

Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission. Schedule IS-1 is not available to a customer receiving energy supply service from a Competitive Service Provider nor to a customer providing demand response services to the Regional Transmission Entity (RTO), either directly or by way of a third-party Curtailment Service Provider .

APPLICABILITY

Applicable upon request to Customers taking service under Schedule B-3 or LP-1 and having at least 25 kW of interruptible load . All provisions of B-3 and LP-1 are still applicable . The Customer shall pay to the Cooperative charges in accordance with Schedule EF based on the cost of furnishing and installing all additional equipment required to receive the benefits of Schedule IS-1 .

TYPE OF SERVICE


IV MONTHLY INTERRUPTIBLE DEMAND CREDIT

Each October through the following September, the monthly Interruptible Demand Credit will be calculated as the product of the Interruptible Demand times the sum of the then effective RTO Capacity and transmission level Transmission Rates as reflected in the ODEC wholesale rate . The interruptible demand credit shall not apply unless the Customer's interruptible demand is at least 50 kW.

V DETERMINATION OF INTERRUPTIBLE DEMAND

Each October, the Interruptible Demand shall be calculated by subtracting the average 60-minute kilowatt load of the Customer occurring during all called periods of interruption in the most recent twelve months from the average of the ESS billing demands calculated in accordance with section VI-B of Schedule LP-1 for the months in which there were called periods of interruption .

Schedule IS-1 Effective: On All Bills Issued on and After Julyl, 2014

H W

W

Rappahannock Electric Cooperative Schedule IS-1 Page 2

V1 . PERIODS OF INTERRUPTION

Exhibit No. - Witness: DFK & JDG


W

40

Notice of period of interruption will be by a signal provided by the Cooperative's Load Management System, telephone, or other appropriate means.

The period of interruption shall begin:

1 At the beginning of the next following clock hour if the control signal is sent five (5) to fifteen (15) minutes before the end of the hour ; or

2. Five (5) minutes after the control signal is sent, if the signal is sent at any other time ; or

3 . A mutually agreed upon time by phone or other appropriate means.

The period of interruption shall end:

Fifteen (15) minutes after the last control signal is sent ; or

2 . A mutually agreed upon time by phone or other appropriate means.

If the period of interruption is less than an hour, it is a partial control period and the hourly demand shall be prorated accordingly . Under special circumstances to be determined solely by the Cooperative and applied uniformly to all Customers receiving service under this Schedule, these partial control periods and other periods of interruption, or portions thereof, may be considered invalid if it is to the Customers advantage to do so. It is always the responsibility of the Customer to interrupt its load .

Schedule IS-1 Effective: On All Bills Issued on and After Julyi, 2014


CLOSED HEAVY INDUSTRIAL SERVICE Schedule LP-2

AVAILABILITY

Exh i bit No . Witness : DFK & ]DO Schedule : SA Page 21 of 41

Available to any industrial Customer of the Cooperative contracting for a load of 10,000 kilowatts or more and whose load will be served from a delivery point of the Cooperative's wholesale supplier of electric power and energy devoted exclusively to the service of that Customer . This schedule for service is available only to those Customers receiving service as of January 1, 1981 .

TYPE OF SERVICE

Multi-phase, 60 hertz at available voltage .

MONTHLY CHARGES

Monthly charges shall be:

A . An amount equal to all the monthly charges levied by the wholesale power supplier on the delivery point from which the Customer is supplied, plus

B . An amount equal to one-three hundred sixtieth (1/360) of the total cost to the Cooperative for facilities required to make electric service available to the Customer, plus

C. An amount equal to one third (1/3) of the quarterly interest payments required to service the total debt capital required, less specific exclusions, from the Cooperative to make electric service available to the Customer, plus

D . An amount equal to the current annual composite depreciation rate for distribution plant times the total cost, less specific exclusions, to the Cooperative for facilities required to make electric service available to the Customer (reduced to a monthly basis) . In the event that the depreciation rate is to be changed, notice shall be given to the State Corporation Commission and the Customer at least sixty (60) days prior to such change, plus

E. An amount equal to .2802 percent times the total cost to the Cooperative, less specific exclusions, for facilities required to make electric service available to the Customer . This amount shall cover operating, maintenance, administration and general expenses of the Cooperative, plus

W

F. An amount equal to the sum of all sales, use, receipts, utility, property (less specific exclusions), and any other taxes paid by the Cooperative and applicable to the service rendered hereunder for the sole benefit of the Customer .

Schedule LP-2 Effective : On All Bills Issued on and After July 1, 2014


Exhibit No. Witness: DTK & JDG Schedule: 5A Page 22 of 41

Note : Only charges B through F apply if the Customer has an Electricity Supplier other than the C ooperative as their energy provider .

IV .

V

V1 .

Vil

Vill .

PAYMENT

Bills for service and charges hereunder shall be paid at one of the offices of the Cooperative or such place that the Cooperative may specify to Customer in writing . Such payments shall be due on the tenth (1 01h ) day following the date the bill is mailed or otherwise delivered to Customer for service furnished during the preceding monthly billing period .

LATE PAYMENT CHARGE

In the event Customer delays payment beyond the tenth (10'h) day following the day that the bill is mailed or delivered, there shall be a late payment charge levied which shall be equal to one and one-half (1 1/2) percent per month on the balance due beyond ten (10) days.

SECURITY DEPOSIT

The Customer shall post with the Cooperative a security bond, letter of credit or other security in an amount and form acceptable to and approved by the State Corporation Commission which security deposit shall be used to secure payment to the Cooperative of all obligations of the Customer.

DISCONNECTION OF SERVICE

If the Customer shall fail to make such payment within ten (10) days after such payment is due, the Cooperative may disconnect service to the Customer upon giving ten (10) days written receipted notice to the Customer of its intention to do so unless Customer has made such payment prior to such disconnection of service .

TERM OF CONTRACT

The term of contract for the purchase of electric power and energy shall be the term mutually agreed upon and set forth in a written contract .

~'A

W

W

40



LARGE POWER SUBSTATION DIRECT SERVICE SCHEDULE LP-3

Exhibit No._ Witness : DFK & JDG Schedule: 5A Page 23 of 41

1 . AVAILABILITY


11 . APPLICABILITY

Applicable to Customers Applicable to Customers with monthly capacity requirements of 5,000 kilowatts (kW) or more that can be served from a 138,000/34,500 volt load center substation located within five (5) miles of the point of delivery to the Customer . Also applicable to Customers whose delivery point is at the low voltage side of a substation where high side delivery is from transmission facilities of at least 34,500 volts .

Ill . TYPE OF SERVICE


IV. MONTHLY RATE


1 . Applicable to qualifying Customers taking service from the Cooperative as of November 1, 2009 .

Access Charge : @ $315.00 per month

Demand Delivery Charge : @ $ 1 .10 per kW

Energy Delivery Charge : @ $0.00250 per kWh

2. Applicable to qualifying Customers taking service from the Cooperative on Schedule PP-NT as of June 30, 2014 .

Access Charge :

Demand Delivery Charge:

Energy Delivery Charge:

@ $315.00 per month

@ $1 .28 per kW

@ $0.00250 per kWh

W

Schedule LP-3 Effective: On all Bills Issued on and After July 1, 2014


Rappahannock Electric Cooperative Schedule : 5A

Schedule LP-3 Page 24 of 41

Page2

MONTHLY RATE (continued)

3. Applicable to qualifying Customers initiating service after November 1, 2009 and to any Section IV-A-1 or 2 Customer upon the upgrade or replacement of existing substation and related facilities serving the Customer, excluding routine maintenance:

Access Charge :

Demand Delivery Charge :

@ $315.00 per month

@ $0.18 per kW

Facilities Charge : A facilities charge equal to the installed costs of dedicated local facilities times the applicable factor as follows :

Without a contribution-in-aid of construction :

Standard Utility Plant (Normal Depreciation) 1 .37% Non-Standard Utility Plant (10-yr Depreciation) 2.22%

Non-Standard Utility Plant (5-yr Depreciation) 3.50%

With a contribution-in-aid of construction :

Standard Utility Plant (Normal Depreciation) .81% Non-Standard Utility Plant (10-yr Depreciation) 1 .11% Non-Standard Utility Plant (5-yr Depreciation) 1 .54%

Dedicated local facilities may include an allocated portion of joint use facilities.


Wholesale Billing Demand:

1 . The charges for Wholesale Billing Demand will be based on the prevailing ODEC transmission level demand rates adjusted to compensate for the applicable distribution losses on a customer specific basis .

2. In addition, an Excess Demand charge of $2.38 per kW of Excess Demand will apply each month.

Energy Charges :

The Customers kWh usage for the month times the prevailing ODEC Transmission Energy Rate adjusted to compensate for the applicable distribution losses .

I-& W a %J W

Schedule LP-3 Effective : On all Bills Issued on and After July 1, 2014


Rappahannock Electriic Cooperative Schedule : 5A Schedule LP-3 Page 25 of 41 Page3

MONTHLY RATE (continued) B . Electricity Supply Service Charges : (continued)

2 . The Customer's kWh usage for the month times the corresponding monthly ODEC Energy Cost Adjustment adjusted to compensate for the applicable distribution losses

Note : The above Delivery Service and Energy Supply Service charges apply to those Customers who have the Cooperative as their energy service provider . Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier other than the Cooperative as their energy provider .

V MINIMUM-MONTHLY DELIVERY CHARGE

The minimum monthly delivery charge under the above rate shall be the greater of the amount determined in accordance with Section IV-A or the amount specified in any contract currently in force .

VI DETERMINATION OF BILLING DEMANDS


B . Wholesale Billing Demand - Wholesale Billing Demand, or Demands, will be based on the Customer's actual demand or demands measured coincident with the billing demands as defined in the prevailing ODEC rate applicable to the Cooperative .

C . Excess Demand - The highest average kW of demand measured in any 15 minute interval during the current billing month less the Monthly CP Demand . Monthly CP Demand shall be the Customer's maximum hourly integrated demand occurring in the CP Hour . The hour of the CIP (CP hour) is the hour of each month in which the ODEC Monthly Delivered Demand applicable to the Cooperative is determined .

Vil POWER FACTOR

The Customer agrees to maintain unity power factor as nearly as practicable . The Cooperative reserves the right to measure such power factor at any time. Should such measurements indicate that the power factor at the time of the maximum demand is less than 90 percent (90%) lagging, the demand for billing purposes may be the demand as indicated or recorded by the demand meter multiplied by 90 percent (90%), and divided by the percent power factor.

Vill TERM OF CONTRACT

The term of contract for purchase of electricity under section IV-A-2 of this schedule shall be the term mutually agreed upon and set forth in a written contract, if such is required, but in no case shall the term of contract be less than one (1) year .

W

W

0 ~A


Exhibit No.-Witness: DFK & JDG Schedule: 5A

Rappahannock Electric Cooperative Page 26-of 41 Schedule LP-3 Page4

TERM OF CONTRACT (continued)

All facilities needed to be installed, upgraded, replaced, or added to in order for service to be delivered under section IV-A-2 of this schedule shall be supplied under a written contract with a mutually agreqd upon term, but in no case, shall the term of the contract be less than seven (7) years.

Consumers supplied under section IV-A-2 of this schedule may terminate the associated contract at any time by : 1) notifying the Cooperative of their intent to terminate the contract ; and 2) making a one-time payment equal to the un-amortized value of the facilities supplied under the contract, plus, if applicable, the cost to remove the facilities .

H W



TIME OF USE SERVICE SCHEDULE R-TOU

AVAILABILITY

Exhibit No.-Witness : DFK & JDG Schedule : 5A Page 27 of 41

Available, on a voluntary and limited basis, to consumers in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission, and where the consumer takes service at one delivery point through one kilowatt-hour meter.

APPLICABILITY

Applicable to customers otherwise served under Schedule A. This rate shall be limited to the availability of appropriate meters, and may be limited further by the saturation and/or impact on the Cooperative's electric system of members utilizing this rate schedule in a general area . Net Metering customers are not eligible for this rate .

TYPE OF SERVICE


IV MONTHLY RATE


Access Charges : Single-phase Service Multi-phase Service

Energy Delivery Charges : First 300 kWh per month Over 300 kWh per month


All On-Peak kWh - June - September

All On-Peak kWh - October - May

All Off-Peak kWh

V

$10.00 per month $12.15 per month

* $0.04065 per kWh * $0.02835 per kWh

@ $0.42494 per kWh

@ $0.13649 per kWh

@ .$0.04340 per kWh

DETERMINATION OF ON-PEAK AND OFF-PEAK KWH

A. On-Peak kWh - Summer includes the months of June through September and is defined as kWh used between the hours of 3:00 p.m. and 7:00 p.m . on weekdays, excluding Memorial Day, July 4th, and Labor Day . On-Peak kWh - Non-Summer includes the months of October through May and is defined as kWh used on

1-h W 40 %J W

Schedule R-TOU Effective: On Bills issued On and After July 1, 2014 Page 1

Exhibit No . Witness : DFK & JDG FA Schedule : 5A W

Schedule RJOU Page 28 of4l 40 IWIJ

Page 2 W 0

weekdays between the hours of 6:00 a.m . and 9:00 a.m ., and between 5:00 p.m . 10 and 8:00 p.m., excluding Thanksgiving Day, Christmas Day, and New Years Day. a

PA B. Off-Peak kWh is defined as all kWh not included in (A) above.

V1 . MINIMUM MONTHLY DELIVERY CHARGE

The minimum monthly delivery charge shall be the Access Charge under Part A of the Monthly Rate above unless otherwise provided for under special contract .

VII . POWER COST ADJUSTMENT CLAUSE


Vill . TERMS OF CONTRACT

Open order, unless the consumer or the Cooperative requests a contract specifying a mutually agreed upon term . In no case, however, shall the term of any contract be less than one (1) year .

Schedule R-TOU Effective: On Bills Issued On and After'July 1, 2014 Page 2


PRIVATE OUTDOOR AREA LIGHTING SERVICE - NT (Closed December 13,1985)

SCHEDULE AL

Exhibit No.-Witness: DFK & JDG Schedule : 5A Page 29 of 41

AVAILABILITY

Available In the territory acquired by the Cooperative in Case No. PUE-2009-00101, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporate Commission .

APPLICABILITY

Service un ' der this Schedule is available only for installations served on this rate

schedule prior to December 13, 1985 . The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

MONTHLY RATE

A . Distribution Delivery Charges :

Monthly Distribution :

Twe of Fixture Delivery Charcle

400 Watt High Pressure Sodium (HPS) $25.61 400 Waft Mercury Vapor (MV) $18.44 1000 Watt Mercury Vapor (MV) $29.82

Standard Wood Poles Length Monthly Charge

35 feet $3.54 40 feet $3.88

Overhead Circuit $0.013 per foot for each foot of span length


J.A W Q *4 W

Type of Fixture Lumen kWh/Month Monthly Charge

400 Waft HPS 50,000 Lumen 167 kWh $7.52 400 Waft MV 21,500 Lumen 162 kWh $7.29 1000 Waft MV 60,000 Lumen 386 kWh $17.38

Rappahannock Electric Cooperative Schedule AL Page 2

IV

V.

VI

POWER COST ADJUSTMENT

Exhibit No. Witness : DFK & J-DG Schedule: SA Page 30 of 41

All kilowatt-hours under this schedule will be adjusted as per Schedule PCA-1 .

TERM OF CONTRACT

Service is sold under contract to take continuous service under this schedule for a minimum period of five (5) years for Distribution Delivery Charges .

In the event of early termination, the Customer shall pay either the balance of the contract responsibility or the net cost of installation and removal of the facilities installed by the Cooperative to serve the Customer, whichever is less .

GENERAL

All lamps are lighted from dusk to dawn every night, or for approximately 4,200 hours perannum.

The Customer shall obtain written approval from public authorities for lights to be located on public thoroughfares .

The Customer shall select the location of all poles installed on the Customer's property under the provisions of this schedule, and poles will be relocated only on payment by the Customer of the cost of such relocation . The Customer shall be responsible for all damages to, or loss of, the Cooperative's property located on the Customer's premises, unless resulting from causes beyond the Customer's control .

When the Customer requires the Cooperative to furnish facilities in excess of those normally supplied by the Cooperative, the Customer shall pay the Cooperative's excess investment, with the maintenance of the special equipment subject to :

(1) Time and ability to obtain replacement, and

(2) Advance payment of the then excess cost over standard for each replacement .

When lighting is served from an overhead circuit, the Customer may elect to own and maintain the poles and circuits upon which the Cooperative will install the lighting fixture . Customer-owned facilities shall be approved by the Cooperative .

When lighting is served from an underground circuit, the Customer shall own, install, and maintain all necessary concrete bases for poles to be installed in accordance with Cooperative specifications . The Customer shall also own, install and maintain all facilities including circuits, conduit and pedestals necessary to supply Service to the base of the pole .

Schedule AL Effective: On All Bills Issued on and After July 1, 2014

1-211 W a %J W


Exhibit No.-witness: DFK & JDG Schedule : 5A Page 31 of 41

Vil . CUSTOMER OWNED EQUIPMENT - COMPANY OPERATES AND MAINTAINS

Whenever the Customer furnishes, installs, and owns the entire lighting system using equipment approved by and installed in a manner acceptable to the Cooperative, the Cooperative may at its discretion, operate and maintain the system at the following monthly rates .

A . Monthly Rate :

Type of Fixture

100 Waft Mercury Vapor (MV) 175 Waft Mercury Vapor (MV)

B . Electricity Supply Service Charges :

Type of Fixture kWh/Month

100 Waft MV 175 Watt MV

45 kWh 74 kWh

Delivery Charge

$4.50 $4.77

Monthly Charge

$0.94 $1 .57

The Company's responsibility under the aforementioned charges for maintaining the Customer owned lighting system is limited to photo control, relamping, cleaning fixtures and painting poles requiring painL When the Customees equipment is intermediate in size to those listed above the Customer shall pay the monthly charges applicable to the next larger size .

I-^ W a %j W 10

Schedule AL Effective: On All Bills Issued on and After July 1, 2014


STREET AND HIGHWAY LIGHTING SERVICE - NT SCHEDULE MSL

Closed to new services after June 30, 2014

COOPERATIVE-OWNED AND MAINTAINED EQUIPMENT

A.

B

Exhibit No.- Witness: DFK & JDG Schedule : 5A Page 32 of 41

Availability

Available in the territory acquired by the Cooperative in Case No. PUE-2009-00101, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporate Commission .

Applicability

Applicable for lighting service sold for the lighting of public streets,' public highways and other public outdoor areas where such service can be supplied from the existing general distribution system .

This schedule is also applicable within private property that is open to the general public, such as private walkways, streets, and roads, when the property and buildings are under common ownership and when supply from the Cooperative's distribution system is directly available and when lighting service is contracted for by the owner thereof . The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

C. Monthly Rate

Distribution Delivery Charges:


Tvoe of Fixture - Overhead Supoly

High Pressure Sodium (HPS) - Wood Pole

Delivery Charge

70 Watt HPS $ 8.02 100 Waft HPS $ 8.40 200 Waft HPS $ 14.37 400 Waft HPS $ 18.12

Mercury Vapor (MV) - Wood Pole (restncled to installations as of October 1, 1 993) 175 Waft MV $ 8.12

1-b W

W

Mercury Vapor (MV) - Wood Pole (restricted to installations as of October 3, 1991) 250 Waft MV $ 11 .68 400 Watt MV $ 13.85

Exhibit No. Witness: DIFK & JDC; Schedule : 5A

Rappahannock Electric Cooperative Page 33 of 41 Schedule MSL Page 2

Distribution Delivery Charge - Monthly Rate (continued)

Type of Fixture - Underground Supply Delivery Charge

High Pressure Sodium (HPS)

Standard Pole - Low Mounting 70 Waft HPS $ 17.38 100 Waft HPS $ 17.78

Standard Pole - High Mounting 100 Waft HPS $ 20.98 200 Waft HPS $ 22.90 400 Waft HPS $ 27.19

Rectangular Enclosed - Standard Pole - High Mounting 200 Watt HPS $ 33.55 400 Waft HPS $ 36.24

Rectangular Enclosed - Multiple units for each additional fixture per pole 200 Waft HIPS $ 17.57 400 Waft HPS $ 20.26

Mercury Vapor (MV) Standard Pole - Low Mounting (restricted to installations as of October 1, 1993)

175 Waft MV $ 12.86

Standard Pole - High Mounting (restricted to installations as of October 3, 199 1)

400 Waft MV $ 23.78

All lamps are lighted from dusk to dawn every night, or for approximately 4,200 hours per annum. However, at the request of the Customer, individual lamps may be operated continuously 24 hours per day. The monthly rate for each light continuously operated shall be the applicable rate above, plus 60% of the base overhead supply wood pole monthly rate .

When the circuit length exceeds 150 feet per light, there will be an additional monthly charge of $0.013 per foot for each foot of span length . (This provision is restricted to locations served as of December 13, 1985.)

#-A W

W

Schedule MSL Effective: On All Bills Issued on and After July 1, 2014

Exhibit No. Witness: DfK & JDG Schedule : 5A

Rappahannock Electric Cooperative Page 34 of 41 Schedule MSL Rage 3

Monthly Rate (continued)

2 . Electricity Supply Service Charges :


70 Waft HPS 5,800 Lumen 37 kWh $1 .67 100 Waft HPS 9,500 Lumen 51 kWh $2.30 200 Waft HPS 22,000 Lumen 86 kWh $3.87 400 Waft HPS 50,000 Lumen 167 kWh $7.52

175 Waft MV 8,150 Lumen 74 kWh $3.33 250 Waft MV 11,500 Lumen 103 kWh $4.64 400 Watt MV 21,500 Lumen 162 kWh $7.29

D. Power Cost Adjustment


E . Term of Contract

Ten (10) years initially for Distribution Delivery Charges, renewable annually thereafter .

F. General

For installations on or after December 13, 1985, the Customer will pay the estimated cost for all facilities not included in the Cooperative's standard installation .

When lighting equipment is replaced or relocated at the Customer's request before the end of the term of the agreement, with equipment of like or lesser lumen output, the Customer shall pay the removal costs for the old facilities and the installation costs of the new facilities .

When the Cooperative supplies service for underground installations, the Customer shall pay for, or at the option of the Cooperative, supply the cost for any excavating, backfilling, reconstructing and resurfacing necessary for the installation and maintenance of the underground cable .

The standard overhead installation includes mounting street light equipment on an existing wood pole carrying secondary circuits . The standard overhead supply-metal

pole and underground supply-standard pole installation includes one pole per light . The Customer is responsible for all the costs associated with furnishing and installing any concrete bases for poles. Such installation shall be made to Cooperative specifications and in a manner acceptable to the Cooperative .

When a new street lighting distribution system is required or whenever the Customer requests an installation that is not in conformity with the standard installation, the Customer shall pay the following:

~-A

W

W

Schedule IVISIL Effective: On All Bills Issued on and After July 1, 2014

Exhibit No.- Witnm: DFK & JDG

Rappahannock Electric Cooperative Schedule : 5A Page 35 of 41

W

Schedule MSL Page 4 W

General (continued) 1 . For distribution facilities -- estimated installed cost of distribution facilities in 0

excess of those normally supplied by the Cooperative to make service available .

2 . For street light equipment -- Cooperative's excess investment in special poles or fixtures over that of standard equipment, with the maintenance of the special equipment subject to :

(1) time and ability to obtain replacement, and

(2) advance payment of the then excess cost over standard for each replacement.

3. For bridges and subway lightng -- the Cooperative will supply poles, fixtures and circuit with the Customer supplying conduit, raceways, and other necessary equipment including maintenance thereof.

11 . CUSTOMER-OWNED AND MAINTAINED EQUIPMENT - COMPANY SUPPLIES UNMETERED ENERGY

A. Availability

Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporate Commission.

B. Applicability

Applicable for lighting service sold for the lighting of public streets, public highways and other public outdoor areas consisting of Customer-owned foundations, posts, brackets, and luminaires, when the electric energy supplied to such equipment is unmetered and furnished by the Cooperative from the existing general Distribubon System .

This schedule is also applicable within private property, such as private walkways, streets, roads, and when supply from the Cooperative's Distribution System is directly available and when lighting service is contracted for by the owner thereof . The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

Available for high pressure sodium light sources only and are served from a low voltage (120 volt) electric circuit .

The rate is not available to serve Customer-owned lighting systems in an area where there will be a mix of Cooperative-owned and Customer-owned systems.


Exhibit No. Witness : DfK & JDG Schedule : 5A

Rappahannock Electric Cooperative Page 36 of 41 Schedule MSL Page 5

C. Monthly Rate

1 . Distribution Delivery Charges:


Member Owned Fixture - Hiah Pressure Sodium Deliverv Charae

70 Watt HPS $3.72 100 Watt HPS $3.99 200 Watt HPS $5.56 400 Watt HIPS $8 .52

2. Electricity Supply Service Charges :


70 Waft HPS 5,800 Lumen 37 kWh $1 .67 100 Waft HPS 9,500 Lumen 51 kWh $2.30 200 Watt HPS 22,000 Lumen 86 kWh $3.87 400 Watt HPS 50,000 Lumen 167 kWh $7.52

When the Customer's equipment is intermediate in size to those listed above, the Customer shall pay the monthly rate applicable to the next larger size .

D . Power Cost Adjustment


E. Term of Contract

Service is sold under this schedule for a minimum period of thirty (30) days for Distribution Delivery Charges .

F . Responsibilities

The Customer is responsible for furnishing and installing all street fighting equipment, which includes posts, foundations, brackets, and luminaires complete with ballasts, light sensitive switches, and lamps using equipment approved and installed in a manner acceptable to the Company. All Customer-owned lighting equipment is to be installed prior to connection to the Cooperative's service circuits . All maintenance of the Customer's lighting equipment shall be the responsibility of the Customer . The Cooperative will furnish, install, connect, own, and maintain the electric service circuits required to connect the Customer's lighting equipment to the Cooperative's Distribution System . If the Customer requests and the Cooperative agrees, the Cooperative may install all Customer-owned lighting equipment at the Customer's expense .

If the Cooperative is called to do maintenance on Customer-owned lighting equipment, a charge will be made for time and materials required to do said maintenance . Also, the Customer is responsible for providing non-standard material .

S&edule MSL Effective: On All Bills Issued on and After July 1, 2014

Rappahannock Electric Cooperative Schedule IVISL Page 6

G. Con nection/Disconnection Fee

Exhibit No. Witness: DFK & JD(; Schedule : 5A Page 37 of 41

The fee for connecting or disconnecting a street light shall be $15.00 per light with a $40.00 minimum per trip . Any work required in addition to that of connecting or disconnecting a light will be charged to the Customer based on the estimated cost to do the work .

H. Removal Charge

Cooperative-owned facilities, which are no longer needed to provide service to the Customer's lighting system, will be removed by the Cooperative . If the removal involves more than disconnecting the Customer's equipment as covered under 11 . G ., the Customer will be charged the estimated cost to remove the Cooperative's equipment . Removal of the Customer-owned equipment shall be at the Customer's expense .

W

a

INA



OUTDOOR LIGHTING SERVICE - NT SCHEDULE OLN

Closed to new services after June 30,2014


AVAILABILITY


APPLICABILITY

Applicable for lighting service sold for outdoor lighting supplied from the existing overhead secondary and contracted for by a private Customer . The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

MONTHLY RATE



Type of Fixture Delivery CharQe

100 Watt High Pressure Sodium (HPS)' $ 8.59 200 Watt High Pressure Sodium (HpS) 2 $ 14.89 175 Watt Mercury Vapor (MV) 1 $ 8.88 400 Waft Mercury Vapor (MV) 2 $ 16.57

B . Electricity Supply Service Charges :

TvDe of Fixture Lumen kWh/Month Monthlv Charae

100 Watt HPS 9,500 Lumen 51 kWh $ 2.30 200 Watt HPS 22,000 Lumen 86 kWh $ 3.87 175 Watt MV 8,150 Lumen 74 kWh $ 3.33 400 Watt MV 21,500 Lumen 162 kWh $ 7.29

'Cooperative will provide lamp, photo-electric relay control equipment, fixture, and upsweep arm not over four (4) feet in length, and will mount same on an existing pole carrying secondary circuits .

2 Cooperative will provide lamp, photo-electric relay control equipment, fixture, and upsweep arm not over six (6) feet in length, and will mount same on an existing pole carrying secondary circuits .

IRA

W

W

<0

bxhiblt NO.-Witness: DFK & JDG Schedule : 5A W

Rappahannock Electric Cooperative Page 39 of 41 Schedule OLN Page 2

B . Electricity Supply Service Charges (continued)

When facilities, in addition to those specified previously are required to provide H outdoor lighting service, the Customer will pay in advance thecost of installing all additional facilities . For the Cooperative's facilities installed prior to December 13, 1985, the monthly rental charges will continue as follows :

1 . $2.74 for each standard distribution wood pole required, 2. $0.013 per foot for each foot of span length of wires required, and 3. $2.74 of each kilovolt-ampere of transformer capacity installed .

The Customer may elect to own and maintain poles and secondary circuits on his property to accommodate the installation of the outdoor lighting fixture . Such poles and circuits shall meet Cooperative specifications .

IV . POWER COST ADJUSTMENT


V . TERM OF CONTRACT

Service is sold under contract to take continuous service under this rate schedule for a minimum period of three (3) years or longer for Distribution Delivery Charges .


V1 . GENERAL

All Cooperative-owned facilities necessary for service under this schedule shall be maintained by the Cooperative and all such service and maintenance will be performed only during the Cooperative's regular scheduled working hours . The Cooperative shall be allowed two working days after notification by the Customer to replace all burned-out lamps .

All lamps are lighted from dusk to dawn every night, or for approximately 4,200 hours per annum.

The Customer shall obtain written approval from public authorities for lights to be located on public thoroughfares .

The Customer shall select the location of all poles installed on the Customer's property under the provisions of this schedule. Pole relocation or removal will be at the Customer's expense . All pole locations shall conform to all safety standards, and state and municipal regulations . The Customer shall be responsible for all damages to, or loss of, the Cooperative's property located on the Customer's premises, unless resulting from causes beyond the Customers control .

Schedule OLN Effective: On All Bills Issued on and After July 1, 2014


OUTDOOR LIGHTING SCHEDULE OL

IV.


AVAILABILITY


APPLICABILITY

Applicable upon request to Customers along the lines of the Cooperative for street, highway, and ground lighting .

INSTALLATION CHARGE

The complete installation is to be furnished, maintained, and operated by the Cooperative and will remain the property of the Cooperative . All installation charges shall be in accordance with Article V1, Section H of the Cooperative's Terms and Conditions.

MONTHLY RATE



Type of Fixture

*175 Watt Mercury Vapor *250 Waft Mercury Vapor *400 Waft Mercury Vapor *1,000 Waft Mercury Vapor

*90 Waft High Pressure Sodium 100 Waft High Pressure Sodium 150 Watt High Pressure Sodium 400 Watt High Pressure Sodium


Type of Fixture

*175 Watt Mercury Vapor *250 Watt Mercury Vapor *400 Watt Mercury Vapor *1,000 Waft Mercury Vapor

Schedule OL Effective: On All Bills Issued on and After July 1, 2014

Delivery Charge

$ 7.00 $11 .17 $12.91 $25.50

$ 7,45 $ 7.57 $ 8.49 $18.22

kWh/Month Monthly Charge

70 $ 3.15 100 $ 4.50 150 $ 6.75 360 $16.21

F-A W

W -0

Rappahannock Electric Cooperative Schedule OL Page 2

B. Electricity Supply Service Charges (continued):


*90 Watt High Pressure Sodium 36 100 Waft High Pressure Sodium 40 150 Waft High Pressure Sodium 60 400 Watt High Pressure Sodium 150

V TYPE OF FIXTURE

txnjbjt No.-Witness: DFK & JDG Schedule : SA Page 41 of 41

Monthly Charge

$1 .62 $1 .80 $2.70 $6.75

The type of fixture and method of installation shall be in accordance with the Cooperative standards .

*Replacement or new installations of fixtures marked by asterisk are not available under this rate .

Service for all units marked by an asterisk as listed in Section III will continue to be supplied at those locations being serviced at the rates set forth . In the event such an existing unit is discontinued at the Customer's option, it shall no longer be available at that location . No additional such units will be supplied, and in the event any such unit shall fail, and cannot be made operative in the field by either a bulb or electric eye replacement, at the Customer's option the Cooperative will, at the Cooperative's cost, after reasonable notification to the Customer, either (a) remove and not replace the defective fixture or (b) replace the same with a Cooperative high pressure sodium vapor fixture of the Customer's choice which will, thereafter, be billed at the appropriate rate .

VI POWER COST ADJUSTMENT CLAUSE

The amount of charges calculated at the above rate is subject to increase or decrease ynder provisions of the Cooperative's Power Cost Adjustment Clause, Schedule PCA-1 .

TERM OF CONTRACT Vil

The term of contract for service under this schedule shall be such as may be mutually agreed upon, but not less than one (1) year, and to continue thereafter until terminated by a thirty (30) day written notice by either party .

Schedule OL Effective: On All Bills Issued on and After July 1, 2014

PA W

0 1WJ

W

j..a w

RAPPAHANNOCK ELECTRIC COOPERATIVE RATE SCHEDULES AND RIDERS

BLACKLINE

Exhibit No. Witness: DFK & JD(~A Schedule : 5A W Page I of 39 0

%J RAPPAHANNOCK ELECTRIC COOPERATIVE W

Fredericksburg, VA 4M 10

FARM, HOME AND CIVIC SERVICE SCHEDULE A

IV

AVAILABILITY


APPLICABILITY

Applicable to farms, single residences, private schools, church sanctuaries, volunteer fire departments, volunteer rescue squads, civic clubs and similar non-profit community service organizations, along the lines of the Cooperative for all uses . The rated capacity of any motor served under this schedule in excess of ten horsepower (10 h.p .) shall be subject to the approval of the Cooperative as to type and starting characteristics, to prevent disturbance of service to other consumers. With the exception of church sanctuaries, the maximum demand to be provided under Schedule A shall be 200 kW'.

TYPE OF SERVICE


,MONTHLY RATE

A. Distribution Delivery Charges:

Access Charges: Single-Phase Service Multi-phase Service

Energy Delivery Charges : First 300 kWh per month Over 300 kWh per month



@$0.0406542 per kWh @$0.028354-2 per kWh

All kWh per month @$0.07676647-4 per kWh

Note: The above Delivery Service and Ene[gy Supply Service changes apply to those Customers who have the Cooperative as their energy service provider . Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier.; other than the Cooperative-. as their energy provider .

Schedule A Effective : On all Bills Issued on and After July 1 . 2014

Exhibit No.- Witness: DFK & JlPG

Rappahannock Electric Q Schedule : 5A W &beAuLe-A Page 2 of 39 EAM22

W 0



1 . WHOLESALE-POWER COST ADJUSTMENT CLAUSE

The amount of charges calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's VVhelesale Power Cost Adjustment Clause, Schedule WPCA-1 .

VII . TERMS OF CONTRACT

Open order, unless the customer or the Cooperative requests a contract specifying a mutually agreed upon term . In no case, however, shall the term of any contract be less than one (1) year.

Schedule A Effective : On all Bills Issued on and After NevembeF 4, 2GM-q!y~2014~

Exhibit No.- Witness: DFK & J9P Schedule : 5A W Page 3 of 39 0

1%J RAPPAHANNOCK ELECTRIC COOPERATIVE W

Fredericksburg, VA a-


AVAILABILITY


APPLICABILITY

Applicable to all types of Customers for service along the lines of the Cooperative, for all uses unless another rate schedule is specifically applicable . The maximum demand to be provided under Schedule B-1 shall be 200-25 kW.

TYPE OF SERVICE

60 hertz, single-phase and Fnulti phase where available, at available secondary voltages .

,MONTHLY RATE


IV

Access Charges: Single-Phase Service $28.00 per month Multi phase SeFV*Ge $47.60 peF menth

Energy Delivery Charges: All kWh delivered @$.02893699 per kWh


All kWh @$.069154884 per kWh

Note: The above Delive(y Service and Energy Supply Service charges apply to those Customers who have the Cooperative as their energy service Provider . Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier; other than the Cooperative-, as their enengy Provider.

Schedule B-1 Effective: On All Bills Issued on and After July 1 . 2014

ExhibitNo.-Witness: DFK & JDI~

Rappahannock Electric Cooperative Schedule : 5A W Schedule B-1 Page 4 of 39 0 Page 2 IQ

W a

J. MINIMUM MONTHLY DELIVERY CHARGE

The minimum monthly delivery charge shall be the -Access Charge under Part A of the Monthly Rate above. For Customers requiring more than 15 kVA of transformer capacity, the minimum monthly distribution delivery charge shall be increased at the rate of one dollar ($1 .00) for each additional kVA or fraction thereof required . The foregoing will apply unless otherwise provided for under special contract .

1 1 . VVHOLESALE-POWER COST ADJUSTMENT CLAUSE

The amount of charges calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's Whelesale Power Cost Adjustment Clause, Schedule WPCA-1 .

VI 1 . DETERMINATION OF BILLING DEMAND


Vill . CONDITIONS OF SERVICE

The rated capacity of motors in excess of ten horsepower (10 h . p.) shall be subject to the approval of the Cooperative as to type and starting characteristics, to prevent disturbance of service to other Customers.


Open order, unless the Customer or the Cooperative requests a contract specifying a mutually agreed upon term. In no case, however, shall the term of any contract be less than one (1) year.

Schedule B-1 Effective : On All Bills Issued on and After July 1 . 2014NeyembeF 1,

Exhibit No. Witness: DAK & JW Schedule : 5A W Page 5 of 39 0 *'J

RAPPAHANNOCK ELECTRIC COOPERATIVE W Fredericksburg, VA a


1. AVAILABILITY


APPLICABILITY

Applicable to multi-phase Customers, and any single-phase Customer whose actual demand exceeds 25 kW in the current month or preceding 11 months, or all uses unless another rate schedule is specifically applicable . The maximum demand to be provided under Schedule B-3 shall be 200 kW.

Ill . TYPE OF SERVICE

60 hertz, multi-phase where available, at available secondary voltages .

IV. MONTHLY RATE


Single-Phase Access Charge (a) $28.00 per month

Multi-Phase .Access Charge: @ $47.50 per month

Demand Delivery Charge: First 100 kW of billing demand delivered Over 100 kW of billing demand delivered

Energy Delivery Charges: First 100 kWh per kW delivered Next 100 kWh per kW delivered Next 200 kWh per kW delivered Over 400 kWh per kW delivered


Energy Charges: First 100 kWh per kW Next 100 kWh per kW Next 200 kWh per kW Over 400 kWh per kW

@ $1 .50 per FAenthkW @ $9.00 per menthkW

@$0.0289657 per kWh @$0.0259657 per kWh @$0.0169667 per kWh @$0.0139W per kWh

@$0.07381&1-95 per kWh @$0.072395M per kWh @$0.06559437-3 per kWh @$0.052493063 per kWh

Schedule B-3 Effective : On All Bills Issued on and After July 1 . 2014

8gppAbA=ck Electric C ,9~chedule Q-3 E!9,M 2 2


Exhibit No.- Witness : DFK & JDG,')


The minimum monthly delivery charge shall be the Access Charge under Part I of the Monthly Rate above . For Customers requiring more than 45 kVA of transformer capacity, the minimum monthly distribution delivery charge shall be increased at the rate of $1 .00 for each additional kVA or fraction thereof required . The foregoing will apply unless otherwise provided for under special contract.

VI . WHOLESALE-POWER COST ADJUSTMENT CLAUSE


VI 1. DETERMINATION OF BILLING DEMAND


VIII . CONDITIONS OF SERVICE

The rated capacity of motors in excess of ten horsepower (10 h . p.) shall be subject to the approval of the Cooperative as to type and starting characteristics, to prevent disturbance of service to other Customers.



Schedule B-3 Effective : On All Bills Issued on and After July 1 . 2014 NeyembeF 1,

RaPpAbaimock Electric QQ~~ ,9chedule LEA- euq_1=2


LARGE POWER SERVICE SCHEDULE LP-1

IV

AVAILABILITY



APPLICABILITY

Applicable to all Customers along the lines of the Cooperative contracting for a load of 100 kW or more.

TYPE OF SERVICE

Multi-phase, 60 hertz, at available voltage.

.MONTHLY RATE


Access Charge: @ _$1 00.00 per month

Demand Delivery Charges: First 100 kW of billing demand delivered @_---$1 .50 per kW Next 400 kW of billing demand delivered @_---$1.25 per kW Next 1,500 kW of billing demand delivered @_.7--$ 1 . 10 per kW Over 2,000 kW of billing demand delivered @_.---$1 .00 per kW

Energy Delivery Charges: First 100 kWh per kW delivered @$0.02096 1778 per kWh Next 100 kWh per kW delivered @$0.01876 1558 er kWh gg_p Next 200 kWh per kW delivered @$0.01335 1018 per kWh Over 400 kWh per kW delivered @$0.01136 0818 per kWh

Voltage Discount (kW) : 2 kilovolt (kV) to 15 kV $0.25 per kW Over 15 kV $0 .50 per kW

B. Electricity Supply Service (ESS) Charges:

W a

Schedule LP-1 Effective : On All Bills Issued on and After July 1 . 201ANeyembeF 1, 2009

ppahannock Electric C _&hedule LP-11 Bqg=e_2-,~

Demand Charge: All kW of ESS Billing Demand

Exhibit No. Witness: DFK & JI)d Schedule : 5A Page 8 of 39 C.

@_7--$-8.15 per kW

Energy Charges : First 100 kWh per kW of ESS Billing Demand @$0.0287605417LIDer kWh Next 100 kWh per kWof ESS Billing Demand @$0.0247505017perkWh Next 200 kWh per kW of ESS Billing Demand @$0.02316 4857 per kWh Over 400 kWh per kW of ESS Billing Demand @$0.0240504647 per kWh

V

V1.

,MINIMUM MONTHLY DELIVERY CHARGE

The minimum monthly delivery charge under IV . A of the Monthly Rate shall be the greatest of the amounts determined by the following :

A. $250.00.

B. $0.50 times the highest average kW of demand measured in any 15-minute interval during the current billing month.

C. The minimum specified in any contract currently in force.

.DETERMINATION OF BILLING DEMANDS

A. The monthly distribution delivery demand delivered applicable to IV . A. shall be the greatest of:

1 . Except as determined under VI . A. 2. (below)

i . The highest average kW of demand measured in any 15-minute interval during the current billing month, or

ii . Forty percent (40%) of the highest billing demand, as determined by subparagraph A, section 1 or subparagraph B, section 1, for the preceding eleven (11) months, or

iii . 100 kW.

2. For Customers whose billing demand as determined under VI . A. 1 . above exceeds 1,000 kW, an alternate method of determining billing demand, described below, is available upon request by the Customer . The Customer shall pay the Cooperative an amount equal to the cost of furnishing and installing all equipment required for determining the off-peak and on-peak

Schedule LP-1 Effective : On All Bills Issued on and After July 1 . 2014NeveFnbeF 1,

Rappahannock Electric C Schedule Ll?_-1 Eag-e-3-2

Exhibit No. Witness: DFK & JDG Schedule : SA Page 9 of 39

demands. The equipment shall remain the property of the Cooperative. The alternate monthly billing demand shall be the higher of:

i . The highest average kW of demand measured in any 15-minute interval during the on-peak hours of the current billing month, plus forty percent (40%) of the excess of this amount determined in a similar manner during off-peak hours, or

ii . Forty percent (40%) of the highest billing demand, as determined by VI . A. 1 . (i) or VI . A. 2. (i) for the preceding eleven (111) months.

VI . DETERMINATION OF BILLING DEMANDS (CONT.)

V11

B. The ESS Billing Demand shall be the highest average kW of demand measured in any 15-minute interval during the current billing month.

C. On-peak hours shall be the same as those specified in the Rate Schedule under which the Cooperative purchases power and energy from its principle wholesale power supplier, currently 7igl) a.m . to 1 040 p. Fn ., Mondays thFough r-Fidays the menths of 06tebeF thMugh May,-and-the hours between 10:00 a.m. and 10:00 p. m., Mondays through Fridays, for the months of June through September. All other hours shall be considered off-peak hours.

Note : The above Delivery Service and EneLgy Supply Service charges apply to those Customers who have the Cooperative as their enerw service provider. Only the Distribution Delivery Service charges apply to those Customers who have an Electricity Supplier other than the Cooperative as their energy provider

POWER FACTOR

The Customer agrees to maintain unity power factor as nearly as practicable . The Cooperative reserves the right to measure such power factor at any time . Should such measurements indicate that the power factor at the time of the maximum demand is less than 90 percent (90%) lagging, the demand for billing purposes may be the demand as indicated or recorded by the demand meter multiplied by 90 percent (90%), and divided by the percent power factor.

Schedule LP-1 Effective : On All Bills Issued on and After July 1 . 2014NeYeFnbeF 1,

4) 0

Rappabamock Electric Schedule L -Enp_4a

Vill

I Ix .

WHOLESALE POWER COST ADJUSTMENT CLAUSE

Exhibit No.-Witness : DFK & JDG Schedule : SA Page 10 of 39

The amount of charge calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's Wholesale Power Cost Adjustment Clause, Schedule WPCA.

TERM OF CONTRACT

The term of contract for purchase of electricity under this schedule shall be the term mutually agreed upon and set forth in a written contract, if such is required, but in no case shall the term of contract be less than one (1) year.

I-A W

W 40 IN3 0 1`4

Schedule LP-1 Effective : On All Bills Issued on and After July 1 . 2014NeyembeF 1,

Exhibit No . Witness : DFK & Joe

Rappahannock Electric C Schedule : 5A W Schedule HD_-1 Page I I of 39 0 Bur- 1 .2

RAPPAHANNOCK ELECTRIC COOPERATIVE C2 Fredericksburg, VA

LARGE POWER HIGH DIVERSITY SERVICE SCHEDULE HDA

AVAILABILITY

Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission, except those who have an Electricily Supplier, other than the Cooperative, as their energy provide .

II . APPLICABILITY

Applicable upon request to Customers otherwise served under the LP-1 Schedules and contracting for a load of 500 kW or more .

Ill . CONDITIONS OF SERVICE

A. The Customer shall pay to the Cooperative charges in accordance with Schedule EF based on the cost of furnishing and installing all additional equipment required to take service under this Schedule .

B. The Customer may select service under Schedule HD-1 provided that the Customer takes service under Schedule HD-1 for a minimum of twelve (1 2) consecutive months.

IV . TYPE OF SERVICE

Multi-phase, 60 hertz, at available voltage.

V. MONTHLY RATE


Access Charge:

Demand Delivery Charge: All kW of Maximum Billing Demand delivered

Energy Delivery Charges: First 100 kWh per kW delivered

per kWh

per kWh Next 100 kWh per kW delivered

@ $200.00 per month

@ $ 1 .10 per kW

@ $0.02095 2150

@ $0.01875 1930

Schedule HD-1 Effective: On All Bills Issued on and After NeyembeF 1, 20MI&I ~2014

Rappahannock Electric Cooperative SC,hedule HD--j Enp=22

per kWh

per kWh

V.

VI

Next 200 kWh per kW delivered

Over 400 kWh per kW delivered

MONTHLY RATE (CONT.)


GP-Wholesale Billing Demand :

Exhibit No. Witness : DFK & 19-Q Schedule : 5A Paize 12 of 3 9

@ $0.043,36 1390

@ $0.01436 1190

1 The changes for Wholesale Billinq Demand will be based on the prevailing ODEC transmission level demand rates Gusteme~s GR Demand feF the Fnenth times the pFevailinq ODEG TFansmissien Demand Rate djusted to compensate for the applicable distribution losses an a customer specific basis .

2. _ Excess Demand charqg-,.-2f--@ $2 .38 per kW of Excess Demand will apply each month.

Energy Charges: 1 . The Customers kWh usaae for the month times the r)revailina ODEC

Transmission Ener-gy Rate adiusted to compensate for the applicable distribution losses .

2. The Customer's kWh usage for the month times the corresponding month1v ODEC Enerav Cost Adiustment adiusted to COMDensate for the apolicable distribution losses


The minimum monthly delivery charge under the above rate shall be the greater of the amounts determined by the following :

A. The Access Charge plus the demand charges under Section V, Part A.

Schedule HDA Effective: On All Bills Issued on and After NeyembeF 1, 2GNI~i~20~14

Rappabamock Electric QQQPff3lime Schedule HD--1 BW_e 32

Vil

Vill

IX

B. The minimum specified in any contract currently in force.

,DETERMINATION OF BILLING DEMANDS

The billing demands for each month shall be:

Exhibit No.- Witness : DFK & JDG

Schedule : 5A Pap,e 13 of 39

A. Distribution Delivery Demand - The greater of: a) the highest average M of demand measured in any 15 minute interval during the current billing month, or b) 500 M.

B. GP-Wholesale Billing Demand - Wholesale Billing Demand, or Demands, will be based on the Customers actual demand or demands measured coincident with the billing demands as defined in the prevailing ODEC rate applicable to the Cooperative .

. The hGUF of the CP (GP heuo the h9UF of eaGh FnGRth iR WhiGh

Old DeFMA.e.n. Allenthly DeliveFed Demand deteFFnined f8F the "VE AFea- PUFGuan eminuen's Whelesale Fate, Rate SGhedule GD. The GIR Demand rhall be

the Gustemer-!s maximum hOUFIY inteffated demaRd GGGUFFiRg in the GIR HGUF .

C. Excess Demand - The highest average M of demand measured in any 15 minute interval during the current billing month less the Monthly CP Demand . Monthly CP Demand shall be the Customer's maximum hourly integrated demand occurring in the CP Hour . The hour of the CP (CP hour) is the hour of each month in which the ODEC Monthly Delivered Demand applicable to the Cooperative is determined .

,PEAK PERIOD NOTIFICATION

The Cooperative shall provide peak period notification by use of the Cooperative's load management system, telephone system, or other appropriate means. The Customer has sole responsibility for reducing electric load upon receiving notification .

ROWER FACTOR

The Customer agrees to maintain unity power factor as nearly as practicable . The Cooperative reserves the right to measure such power factor at any time . Should such measurements indicate that the power factor at the time of the maximum demand is less than 90 percent (90%) lagging, the demand for the billing purposes may be the demand as indicated or recorded by the demand meter multiplied by 90 percent (90%) and divided by the percent power factor .

H W a Sj W 40

NJ

Schedule HID-1 211 1 2_0 1 4 Effective: On All Bills Issued on and After Neyembw 1, 20M

Rappahannock Electric C Schedule HD--1 EN:p=42

The amount Gf GhaFge GaIGUIated at the above Fate is rubjeGt tG iRGFease OF deGFease undeF PFGVi6iGnS of the GeepeFative's Wholesale PeweF Cost AEljustmeRt Clause, Sr.hedule "WPGA."

The term of contract for purchase of electricity under this schedule shall be the term mutually agreed upon and set forth in a written contract, if such is required, but in no case shall the term of contract be less than one (1) year .

ExhibitNo.-Witness: DFK & JD~

Schedule: 5A 0 Page 14 of 39 414

w a

Schedule HID-1 Effective: On All Bills Issued on and After NevembeF 1, 20MIg!y~2014~

Exhibit No.- Witness : DFK & J_DG I-A Schedule : 5A W Pam 15 of 39 C


INTERRUPTIBLE SERVICE RIDER SCHEDULE IS-1

IV

V

AVAILABILITY

Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission . Schedule IS-1 is not available to a customer receivina enerav su service from a Competitive Service Provider nor to a customer providing demand response services to the Regional Transmission Entity (RTO), either directly or by way of a third-party Curtailment Service Provider .

APPLICABILITY

Applicable upon request to Customers taking service under Schedule B-3 or LP-1 and having at least 50-25 kW of interruptible load . All provisions of B-3 and LP-1 are still applicable . SGhedule IS 1 us not appliGable a6 a FideF tG SGhedule LP 1 RA The Customer shall pay to the Cooperative charges in accordance with Schedule EF based on the cost of furnishing and installing all additional equipment required to receive the benefits of Schedule IS-1 .

TYPE OF SERVICE


MONTHLY INTERRUPTIBLE DEMAND CREDIT

Each October throuah the followina SeDtember . the monthiv InterrUDtible Demand Credit will be calculated as the product of the Interruptible Demand times the sum of the then effective RTO Capacity and transmission level Transmission Rates as reflected in the ODEC wholesale rate . $6.99 peF kW of InteFFUptible DeFAaR he interruptible demand credit shall not apply unless the Customer's interruptible demand is at least 50 kW.

DETERMINATION OF INTERRUPTIBLE DEMAND

Each October_:~the Monthly Interruptible Demand shall be calculated by subtracting the Fnaximum averaqe 60-minute kilowatt load of the Customer occurring during all called-periods of interruption in the most recent twelve months dUF;Ag the Fn from the average of the ESS billing demands calculated in accordance with section VI-B of Schedule LP-1 for the months in which there were called r)eriods of interruptionef juRe thMugh SeptembeF as GaIGulated iR aGGOFdanGe with 6eGtiGR VI B Of SGhedule LIP 1 i PFGY*ded, howeveF, the FereFded dernands feF the meAth must indiGate that the GustemeF'6 maxwmum 60 Fnmnute kelewatt lead was at least 50 less than the demand FneaSUFed in the hGUF PF09F tG OF following the GOFFespending

Schedule IS-1 Effective: On All Bills Issued on and After NevembeF 1, 20MU~201~4

Exhibit No.- Witness : DFK & JDG 14 Schedule : SA

Pap,e 16 of 39 W

nPrund af entprr-Intonn d-l-rhmn nt lp :;qt fiffi-o nprnPRt (SCIPAI Af thA MPFiAdr, af 'Rip-m-IntuAn W

Rappahannock Electric Cooperative Schedule IS-1 Page 2

V1 . PERIODS OF INTERRUPTION

Notice of period of interruption will be by a signal provided by the Cooperative's Load Management System, telephone, or other appropriate means .

The period of interruption shall begin:

At the beginning of the next following clock hour if the control signal is sent five (5) to fifteen (15) minutes before the end of the hour ; or

2. Five (5) minutes after the control signal is sent, if the signal is sent at any other time ; or

3. A mutually agreed upon time by phone or other appropriate means.

The period of interruption shall end:

Fifteen (15) minutes after the last control signal is sent; or

2. A mutually agreed upon time by phone or other appropriate means.

If the period of interruption is less than an hour, it is a partial control period and the hourly demand shall be prorated accordingly. Under special circumstances to be determined solely by the Cooperative and applied uniformly to ail Customers receiving service under this Schedule, these partial control periods and other periods of interruption, or portions thereof, may be considered invalid if it is to the Customers advantage to do so . It is always the responsibility of the Customer to interrupt its load .

Schedule IS-1 Effective : On All Bills Issued on and After NeveFnbeF 1, 2QWjqkj 2_014

Exhibit No Witness: DFK & JDGI-b Schedule : 5A W Pa%te 17 of 39

RAPPAHANNOCK ELECTRIC COOPERATIVE W Fredericksburg, Virginia 4Z

CLOSED HEAVY INDUSTRIAL SERVICE Schedule LP-2

AVAILABILITY

Available to any industrial Customer of the Cooperative contracting for a load of 10,000 kilowatts or more and whose load will be served from a delivery point of the Cooperative's wholesale supplier of electric power and energy devoted exclusively to the service of that Customer . This schedule for service is available only to those Customers receiving service as of January 1, 1981 .

11 . TYPE OF SERVICE

Multi-phase, 60 hertz at available voltage.

Ill . MONTHLY CHARGES

Monthly charges shall be :

A. An amount equal to all the monthly charges levied by the wholesale power supplier on the delivery point from which the Customer is supplied, plus

B. An amount equal to one-three hundred sixtieth (1/360) of the total cost to the Cooperative for facilities required to make electric service available to the Customer, plus

C. An amount equal to one third (1/3) of the quarterly interest payments required to service the total debt capital required, less specific exclusions, from the Cooperative to make electric service available to the Customer, plus

D . An amount equal to the current annual composite depreciation rate for distribution plant times the total cost, less specific exclusions, to the Cooperative for facilities required to make electric service available to the Customer (reduced to a monthly basis) . In the event that the depreciation rate is to be changed, notice shall be given to the State Corporation Commission and the Customer at least sixty (60) days prior to such change, plus

E. An amount equal to .2802 percent times the total cost to the Cooperative, less specific exclusions, for facilities required to make electric service available to the Customer . This amount shall cover operating, maintenance, administration and general expenses of the Cooperative, plus

F. An amount equal to the sum of all sales, use, receipts, utility, property (less specific exclusions), and any other taxes paid by the Cooperative and applicable to the service rendered hereunder for the sole benefit of the Customer .

Schedule LP-2 Effective : On All Bills Issued on and After July 1 . 2014

Exhibit No._ H Rappahannock Electric Cooperative Witness : DFK & JM Schedule LP-2 Schedule : 5A Q Pacle 2

Page 18 of 39 %J

RappahaAAGGk E!eGtF*G GeopeFative gGhedule LP-2 Page 2

IV

V

VI

VII .

Vill

Note: Only changes B throu-qh F apply if the Customer has an Electricity Supplier othe than the Cooperative as their energy Provider.

PAYMENT

Bills for service and charges hereunder shall be paid at one of the offices of the Cooperative or such place that the Cooperative may specify to Customer in writing . Such payments shall be due on the tenth (1 Oth) day following the date the bill is mailed or otherwise delivered to Customer for service furnished during the preceding monthly billing period .

LATE PAYMENT CHARGE

In the event Customer delays payment beyond the tenth (10th) day following the day that the bill is mailed or delivered, there shall be a late payment charge levied which shall be equal to one and one-half (1 %) percent per month on the balance due beyond ten (10) days .

SECURITY DEPOSIT

The Customer shall post with the Cooperative a security bond, letter of credit or other security in an amount and form acceptable to and approved by the State Corporation Commission which security deposit shall be used to secure payment to the Cooperative of all obligations of the Customer .

.DISCONNECTION OF SERVICE

If the Customer shall fail to make such payment within ten (10) days after such payment is due, the Cooperative may disconnect service to the Customer upon giving ten (10) days written receipted notice to the Customer of its intention to do so unless Customer has made such payment prior to such disconnection of service.

TERM OF CONTRACT

The term of contract for the purchase of electric power and energy shall be the term mutually agreed upon and set forth in a written contract .

Schedule LP-2 Effective : On All Bills Issued on and After Neyenqbw 1, 24MUly 1 2_014

Exhibit No.- Witness : DFK JM Schedule: 5A W

Page 19 of 39

RAPPAHANNOCK ELECTRIC COOPERATIVE W Fredericksburg, VA 4Z

LARGE POWER SUBSTATION DIRECT SERVICE SCHEDULE LP-3

AVAILABILITY


APPLICABILITY

Applicable to Customers ADDlicable to Customers with monthIv caDacitv reauirements of 5.000 kilowatts (kW) or more that can be served from a 138,000/34,500 volt load center substation located within five (5) miles of the Doint of deliverv to the Customer. Also armlicable to Customers whose delivery point is at the low voltage side of a substation where high side delivery is from transmission facilities of at least 34,500 volts .

TYPE OF SERVICE


IV MONTHLY RATE


Applicable to qualifying Customers taking service from the Cooperative as of November 1, 2009 .

Access Charge: @ $315.00 per month

Demand Delivery Charge: @ $1 .10 per kW

Energy Delivery Charge: @ $0.00250 per kWh

2 . Armlicable to aualifvina Customers takina service from the CooK)erative on Schedule PP-NT as of June 30, 2014 .

Access Charge: (a)- $315.00 per month

Demand Delivery Charge: (CD- $1 .28 per kW

Ener-gy Delivery Charge: (cD- $0.00250 per kWh

Schedule LP-3 Effective : On all Bills Issued on and After July 1 . 2014

Rappahannock Electric Cooperafiva $chedule LP-3 ENL-22

MONTHLY RATE (continued)

Exhibit No . Witness: DAK & g)d Schedule : 5A Page 20 of 39

2,3. Applicable to qualifying Customers initiating service after November 1, 2009 and to any Section IV-A-1 or 2 Customer upon the upgrade or replacement of existing substation and related facilities serving the Customer, excluding routine maintenance:

Access Charge :

Demand Delivery Charge:

@ $315.00 per month

@ $0.18 per kW

Facilities Charge: A facilities charge equal to the installed costs of dedicated local facilities times the applicable factor as follows:

Without a contribution-in-aid of construction :

Standard Utility Plant (Normal Depreciation) 1 .37% Non-Standard Utility Plant (10-yr Depreciation) 2.22%

Non-Standard Utility Plant (5-yr Depreciation) 3.50%

With a contribution-in-aid of construction :

Standard Utility Plant (Normal Depreciation) .81% Non-Standard Utility Plant (1 0-yr Depreciation) 1 .11% Non-Standard Utility Plant (5-yr Depreciation) 1 .54%

Dedicated local facilities may include an allocated portion of joint use facilities .


G.PWholesale Billing Demand:

1 . -The chames for Wholesale Billing Demand will be based on the prevailing ODEC transmission level demand rates GustemeF'S GR Demand fGF the menth times the pFevailinq GDEG M2B1ngFa i i Demand Rate-adjusted to compensate for the applicable distribution losses on a customer specific basis .

Schedule LP-3 Effective : On all Bills Issued on and After NeyeffibeF 1 uly 1, 2014, 2009

Rappahannock Electric Cooperative 5phedule LP-3 ENg.-32

ExhibitNo.-Witness: DFK & JDG

Schedule : 5A " Paize 21 of 39 W

%J W

-In addition, an 2 . GaPaGity AlIGGatoenE-Excess Demand-. cha Le:@qf --$12.38 per kW of

Excess Demand will apply each month.T-he er-evailing ODEG ehar-ges -feF the GustemeF'S BOAOeHefeapaeity eests admusted to eempensate feF the appligable distFibution les ,

Energy Charges:

1 . TThe Customer's kWh usage for the month times the prevailing ODEC Transmission Energy Rate adjusted to compensate for the applicable distribution losses .

2. The Customer's kWh usaae for the month times the corresDondina monthiv ODEC Enerav Cost Adiustment adiusted to comoensate for the applicable distribution losses

V.

V1 .

Note : The above Delivery Service and Energy Supply Service charges apply to those Customers who have the Cooperative as their ener-gy service Provider. Only the Distribution Delivery Service charges apply to those Customers who have an Electricity SupplierT other than the Cooperative-, as their energy Provider .


The minimum monthly delivery charge under the above rate shall be the greater of the amount determined in accordance with Section IV-A or the amount specified in any contract currently in force .



B. GP MeFithlyWholesale Billing Demand - Wholesale Billing Demand, or Demands, will be based on the Customer's actual demand or demands measured coincident with the billinq demands as defined in the prevailing ODEC rate applicable to the Cooperative. The heUF ef the GP (CP heUF) is the hGUF of eaGh Fnenth OF; WhiGh the Old Demene ' ' - ', -eliveFed Demand is deteffnined fOF the WE AFea" puFsuant to Old Deminien's Whelesale Fate, Rate SGhedule 01D . The GP Demand shall be the GusterAeF'S maximum hGUF1Y enteoFated demand the GP HeUF .

Schedule LP-3 Effective : On all Bills Issued on and After NevembeF 1-uly 1 . 2014, 2009

Vil

Exhibit No.- Witness : DFK & 1W

Rappahannock Electdc Cooperataye Schedule: 5A W $chgdul - Page 22 of 39 EN"_ W

a Sr.hedule 1=12-3 Page 3 FJI

DETERMINATION OF BILLING DEMANDS (CONT.)

C. Excess Demand - The highest average M of demand measured in any 15 minute interval during the current billing month less the Monthly CP Demand . Monthly CP Demand shall be the Customer's maximum hourly integrated demand occurring in the CP Hour. The hour of the CP (CP hour) is the hour of each month in which the ODEC Monthly Delivered Demand applicable to the Cooperative is determined .

Vill . POWER FACTOR

The Customer agrees to maintain unity power factor as nearly as practicable. The Cooperative reserves the right to measure such power factor at any time . Should such measurements indicate that the power factor at the time of the maximum demand is less than 90 percent (90%) lagging, the demand for billing purposes may be the demand as indicated or recorded by the demand meter multiplied by 90 percent (90%), and divided by the percent power factor .

The term of contract for purchase of electricity under section IV-A-2 of this schedule shall be the term mutually agreed upon and set forth in a written contract, if such is required, but in no case shall the term of contract be less than one (1) year .

All facilities needed to be installed, upgraded, replaced, or added to in order for service to be delivered under section IV-A-2 of this schedule shall be supplied under a written contract with a mutually agreed upon term, but in no case, shall the term of the contract be less than seven (7) years.

Consumers supplied under section IV-A-2 of this schedule may terminate the associated contract at any time by : 1) notifying the Cooperative of their intent to terminate the contract ; and 2) making a one-time payment equal to the un-amortized value of the facilities supplied under the contract, plus, if applicable, the cost to remove the facilities .

Schedule LP-3 Effective : On all Bills Issued on and After NeveFnbeF 1july 1 . 2014, 2009

Exhibit No. Witness: DFK & JDG Schedule : 5A Page 23 of 39


TIME OF USE SERVICE SCHEDULE R-TOU

IV

AVAILABILITY

Available, on a voluntary and limited basis, to consumers in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporation Commission, and where the consumer takes service at one delivery point through one kilowatt-hour meter.

APPLICABILITY

Applicable to customers otherwise served under Schedule A. This rate shall be limited to the availability of appropriate meters, and may be limited further by the saturation and/or impact on the Cooperative's electric system of members utilizing this rate schedule in a general area. Net Metering customers are not eligible for this rate .

TYPE OF SERVICE

60 hertz, single-phase, at available secondary voltage, and multi-phase, where available, at available secondary voltage, under special contract.

MONTHLY RATE


Access Charges: Single-phase Service Multi-phase Service

Energy Delivery Charges: First 300 kWh per month Over 300 kWh per month

B . Electricity Supply Service Charges:


@$0.0406542 per kWh @$0.0283542 per kWh

All On-Peak kWh-- Summer @$0.4249417-536 per kWh

All On-Peak kWh - Non-Summer (cD- $0.13649 per kWh

All Off-Peak kWh

V

@$0.043402032 per kWh

DETERMINATION OF ON-PEAK AND OFF-PEAK KWH

A. On-Peak kWh - Summer includes ' in the months of May through September and is

defined as kWh used between the hours of 3:00 p.m . and 7:00 p.m. on weekdays, excluding Memorial Day, July 4th, and Labor Day. On-Peak kWh - Non-Summer includes FGF the months of October through April and is defined a i, on peak kWh

Schedule RJOU Effective: On Bills Issued On and After July 1 . 2014 Page 1

W a

Exhibit No. Witness : DAK & JDG I~A

Schedule RJOU Schedule : 5A PaiRe 24 of 39

W 0

Page 2 1-4 W

defined as kWh used on weekdays between the hours of 6:00 a.m . and 9:00 a.m ., a 10

and between 5:00 p.m . and 8:00 p.m., excluding Thanksgiving Day, Christmas Day, and New Year's Day.

B. Off-Peak kWh is defined as all kWh not included in (A) above.

Vi . MINIMUM MONTHLY DELIVERY CHARGE


1 . WHGLESALELPOWER COST ADJUSTMENT CLAUSE

The amount of charges calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's Wholesale Power Cost Adjustment Clause, Schedule "WPCA-1 ."

Vill . TERMS OF CONTRACT

Open order, unless the consumer or the Cooperative requests a contract specifying a mutually agreed upon term . In no case, however, shall the term of any contract be less than one (1) year .

Schedule RJOU Effective : On Bills Issued On and After July 1 . 2014 Page 2


PRIVATE OUTDOOR AREA LIGHTING SERVICE - NT (Closed December 13,1985)

SCHEDULE AL


Exhibit No.- Witness: DFK & JDG H

Schedule: 5A W Page 25 of 39 0

J W a

AVAILABILITY

Available in the territory acquired by the Cooperative in Case No. PLIE-2009-00101, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporate Commission .

APPLICABILITY

Service under this Schedule is available only for installations served on this rate schedule prior to December 13, 1985 . The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

MONTHLY RATE



Tyge of Fixture Delivery Charge

400 Waft High Pressure Sodium (HPS) $25.614.40 400 Waft Mercury Vapor (MV) $186 . 488 1000 Waft Mercury Vapor (MV) $296.8244

Standard Wood Poles Length Monthly Charge

35 feet $3.54 40 feet $3.88

Overhead Circuit $0.013 per foot for each foot of span length



400 Waft HPS 50,000 Lumen 167 kWh $7.523-63 400 Watt MV 21,500 Lumen 162 kWh $ - 1000 Watt MV 60,000 Lumen 386 kWh $17.388.16

Schedule AL Effective : On All Bills Issued on and After July 1 . 2014JaAuaPt4-,244-0


Exhibit No._ Witness: DFK & JDG Schedule: 5A W Page 26 of 39

W 0

All kilowatt-hours under this schedule will be adjusted as per Schedule WPCA-1-NT begiARiAg jUly 1 , 201 1 .

Service is sold under contract to take continuous service under this schedule for a minimum period of five (5) years for Distribution Delivery Charges .


V-4-.

All lamps are lighted from dusk to dawn every night, or for approximately 4,200 hours perannum .

The Customer shall obtain written approval from public authorities for lights to be located on public thoroughfares.

The Customer shall select the location of all poles installed on the Customers property under the provisions of this schedule, and poles will be relocated only on payment by the Customer of the cost of such relocation . The Customer shall be responsible for all damages to, or loss of, the Cooperative's property located on the Customer's premises, unless resulting from causes beyond the Customer's control.

When the Customer requires the Cooperative to furnish facilities in excess of those normally supplied by the Cooperative, the Customer shall pay the Cooperative's excess investment, with the maintenance of the special equipment subject to :

(1) Time and ability to obtain replacement, and

(2) Advance payment of the then excess cost over standard for each replacement.

When lighting is served from an overhead circuit, the Customer may elect to own and maintain the poles and circuits upon which the Cooperative will install the lighting

Schedule AL Effective : On All Bills Issued on and After July 1 . ZQUJanuapy-l-,~

fixture . Customer-owned facilities shall be approved by the Cooperative.


Delivery Charge

When lighting is served from an underground circuit, the Customer shall own, install, and maintain all necessary concrete bases for poles to be installed in accordance with Cooperative specifications . The Customer shall also own, install and maintain all facilities including circuits, conduit and pedestals necessary to supply Service to the base of the pole .

Whenever the Customer furnishes, installs, and owns the entire lighting system using equipment approved by and installed in a manner acceptable to the Cooperative, the Cooperative may at its discretion, operate and maintain the system at the following monthly rates.

A. Monthly Rate :

Type of Fixture

100 Waft Mercury Vapor (MV) 175 Waft Mercury Vapor (MV)



100 Waft MV 175 Waft MV

45 kWh 74 kWh

$0.94 $1 .57

The Company's responsibility under the aforementioned charges for maintaining the Customer owned lighting system is limited to photo control, relamping, cleaning fixtures and painting poles requiring paint. When the Customer's equipment is intermediate in size to those listed above the Customer shall pay the monthly charges applicable to the next larger size .

Exhibit No.-Witness: DFK & JDG

Schedule: 5A Page 27 of 39

$4.50 $4.77

Monthly, Charge

Schedule AL Effective : On All Bills Issued on and After July 1 . ZQUJanuafj~-


STREET AND HIGHWAY LIGHTING SERVICE - NT SCHEDULE MSL


COOPERATIVE-OWNED AND MAINTAINED EQUIPMENT

A. Availability


Available in the territory acquired by the Cooperative in Case No . PUE-2009-001 01, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporate Commission .

B. Applicability

Applicable for lighting service sold for the lighting of public streets, public highways and other public outdoor areas where such service can be supplied from the existing general distribution system .

This schedule is also applicable within private property that is open to the general public, such as private walkways, streets, and roads, when the property and buildings are under common ownership and when supply from the Cooperative's distribution system is directly available and when lighting service is contracted for by the owner thereof. The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

C . Monthly Rate



Type of Fixture - Overhead Supply Delivery Change

High Pressure Sodium (HPS) - Wood Pole 70 Waft HPS $8.027-.68 100 Waft HPS $8.4 200 Waft HPS $14.3713.66 400 Waft HPS $18.12

Mercury Vapor (MV) - Wood Pole (restricted to installations as of October 1, 1993) 175 Waft MV $8.127-.40

Mercury Vapor (MV) - Wood Po/e (restricted to installations as of October 3, 199 1)

~A W 0 1%J W

Schedule MSL Effective : On All Bills Issued on and After July 1 . 2014JaRUaPJ4-,2-0-W

Exhibit No. Witness: DFK & JD6" Schedule : 5A W Page 29 of 39 0

14

250 Waft MV $11.6810.7-1 W

400 Watt MV $1 3.8542-.49

Rappahannock Electric Cooperative Schedule MSL Page 2

Distribution Delivery Charge - Monthly Distribution (continued)

Type of Fixture - Underground Supply Delivery Cha[ge

High Pressure Sodium (HPS) Standard Pole - Low Mounting

70 Waft HPS $17.3804 100 Waft HPS $17.7834

Standard Pole - High Mounting 100 Waft HPS $20.9854-200 Watt HPS $22.90G8 400 Waft HPS $27.195-.N

Rectangular Enclosed - Standard Pole - High Mounting 100 VVa# HIPS $ 31 .17-200 Watt HPS $33.55243 400 Waft HPS $36.24

Rectangular Enclosed - Multiple units for each additional fixture per pole 100 VV

- tt HP8 $ 16.17-

200 Watt HPS $17.57645 400 Watt HPS $20.2

Mercury Vapor (MV)

Standard Pole - Low Mounting (restricted to installations as of October 1, 1993)

175 Watt MV $12.864-4

Standard Pole - High Mounting (restricted to installations as of October 3, 1991) 269 Watt MV $ 20.80 400 Waft MV $23.782.22

All lamps are lighted from dusk to dawn every night, or for approximately 4,200 hours per annum. However, at the request of the Customer, individual lamps may be operated continuously 24 hours per day. The monthly rate for each light continuously operated shall be the applicable rate above, plus 60% of the base

Schedule IVISL Effective: On All Bills Issued on and After July 1 . L0_14JanuaPt4-.4=

overhead supply wood pole monthly rate .


Distribution Delivery Charge - Monthly Distribution (continued)

Exhibit No . witness: DFK & JDG Schedule : 5A Page 30 of 39

When the circuit length exceeds 150 feet per light, there will be an additional monthly charge of $0.013 per foot for each foot of span length. (This provision is restricted to locations served as of December 13, 1985.)

2 . Electricity Supply Service Charges :

Type of Fixture Lumen

70 Waft HPS 100 Waft HPS 200 Waft HPS 400 Waft HPS

175 Waft MV 250 Waft MV 400 Waft MV

5,800 Lumen 9,500 Lumen

22,000 Lumen 50,000 Lumen

8,150 Lumen 11,500 Lumen 21,500 Lumen

E-D. VOelesale Power Cost Adjustment

kWh/Month

37 kWh 51 kWh 86 kWh

167 kWh

74 kWh 103 kWh 162 kWh

Monthly Charge

$1.670-.7-7 $2.304-06 3.87 $L.523-.63

$3 .334-4WE $4 .642-16 $7.293-42

All kilowatt-hours under this schedule will be adjusted as per Schedule WPCA-1-NT beginning july 1, 201 1 .

FLE. Term of Contract

Ten (10) years initially for Distribution Delivery Charges, renewable annually thereafter.

G-.F . General

For installations on or after December 13, 1985, the Customer will pay the estimated cost for all facilities not included in the Cooperative's standard installation .

When lighting equipment is replaced or relocated at the Customer's request before the end of the term of the agreement, with equipment of like or lesser lumen output,

W 0

Schedule MSIL Effective : On All Bills Issued on and After July 1 . 20144anuapy-l-,244-0

Exhibit No.- Witness : DFK & JD& Schedule : 5A W Page 31 of 39

the Customer shall pay the removal costs for the old facilities and the installation W costs of the new facilities .


EG. General (continued)

When the Cooperative supplies service for underground installations, the Customer shall pay for, or at the option of the Cooperative, supply the cost for any excavating, backfilling, reconstructing and resurfacing necessary for the installation and maintenance of the underground cable.

The standard overhead installation includes mounting street light equipment on an existing wood pole carrying secondary circuits . The standard overhead supply-metal

pole and underground supply-standard pole installation includes one pole per light . The Customer is responsible for all the costs associated with furnishing and installing any concrete bases for poles. Such installation shall be made to Cooperative specifications and in a manner acceptable to the Cooperative.

When a new street lighting distribution system is required or whenever the Customer requests an installation that is not in conformity with the standard installation, the Customer shall pay the following :

For distribution facilities -- estimated installed cost of distribution facilities in excess of those normally supplied by the Cooperative to make service available.

2 . For street light equipment - Cooperative's excess investment in special poles or fixtures over that of standard equipment, with the maintenance of the special equipment subject to :

(1) time and ability to obtain replacement, and

(2) advance payment of the then excess cost over standard for each replacement.

3. For bridges and subway lighting -- the Cooperative will supply poles, fixtures and circuit with the Customer supplying conduit, raceways, and other necessary equipment including maintenance thereof.

CUSTOMER-OWNED AND MAINTAINED EQUIPMENT - COMPANY SUPPLIES UNMETERED ENERGY

A. Availability

Schedule MSL Effective : On All Bills Issued on and After July 1 . L014JaAuaPt4-,204-0


Available in all territory served by the Cooperative, subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporate Commission .


B . Applicability

Applicable for lighting service sold for the lighting of public streets, public highways and other public outdoor areas consisting of Customer-owned foundations, posts, brackets, and luminaires, when the electric energy supplied to such equipment is unmetered and furnished by the Cooperative from the existing general Distribution System.

This schedule is also applicable within private property, such as private walkways, streets, roads, and when supply from the Cooperative's Distribution System is directly available and when lighting service is contracted for by the owner thereof. The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

Available for high pressure sodium light sources only and are served from a low voltage (11 20 volt) electric circuit.

The rate is not available to serve Customer-owned lighting systems in an area where there will be a mix of Cooperative-owned and Customer-owned systems .

C. Monthly Rate



Member Owned Fixture - Hi-gh Pressure Sodium

70 Waft HPS 100 Waft HIPS 200 Waft HPS 400 Waft HPS

2. Electricity Supply Service Charges:

Type of Fixture Lumen kWh/Month

70 Waft HPS 5,800 Lumen 37 kWh 100 Waft HIPS 9,500 Lumen 51 kWh 200 Waft HPS 22,000 Lumen 86 kWh 400 Waft HPS 50,000 Lumen 167 kWh

Delivery Charge

$3.72 $3 .99 $5.56 $8.52

Monthly Cha[ge

$1 .67077-7 $2.301 .06 3.87

$Z.52"3

When the Customer's equipment is intermediate in size to those listed above, the Customer shall pay the monthly rate applicable to the next larger size .

I-A

W Q SJ

W

Schedule MSL Effective : On All Bills Issued on and After July 1 . L014Janvapt+41M



Rappahannock Electric Cooperative Schedule IVISL Page 6

E-D . wholesale Power Cost Adjustment

All kilowatt-hours under this schedule will be adjusted as per Schedule WPCA-1 -NT beginning july 1, 201 1 .

FL.E . Term of Contract

Service is sold under this schedule for a minimum period of thirty (30) days for Distribution Delivery Charges .

G-F. Responsibilities

The Customer is responsible for furnishing and installing all street lighting equipment, which includes posts, foundations, brackets, and luminaires complete with ballasts, light sensitive switches, and lamps using equipment approved and installed in a manner acceptable to the Company. All Customer-owned lighting equipment is to be installed prior to connection to the Cooperative's service circuits . All maintenance of the Customer's lighting equipment shall be the responsibility of the Customer. The Cooperative will furnish, install, connect, own, and maintain the electric service circuits required to connect the Customers lighting equipment to the Cooperative's Distribution System. If the Customer requests and the Cooperative agrees, the Cooperative may install all Customer-owned lighting equipment at the Customer's expense.

If the Cooperative is called to do maintenance on Customer-owned lighting equipment, a charge will be made for time and materials required to do said maintenance. Also, the Customer is responsible for providing non-standard material.

H-G. Con nection/Disconnection Fee

The fee for connecting or disconnecting a street light shall be $15.00 per light with a $40.00 minimum per trip . Any work required in addition to that of connecting or disconnecting a light will be charged to the Customer based on the estimated cost to do the work .

4-H. Removal Charge

Cooperative-owned facilities, which are no longer needed to provide service to the Customer's lighting system, will be removed by the Cooperative. If the removal involves more than disconnecting the Customer's equipment as covered under 11 . G., the Customer will be charged the estimated cost to remove the Cooperative's equipment. Removal of the Customer-owned equipment shall be at the Customer's

Schedule MSL Effective : On All Bills Issued on and After July 1 . L014JanuaPt4-,,1M

expense.

Exhibit No.- Witness: DFK & JDG Schedule : 5A IHA Page 34 of 39

Schedule MSL Effective : On All Bills issued on and After July 1 . Z014Januafy-*-,24I-G


OUTDOOR LIGHTING SERVICE - NT SCHEDULE OLN


AVAILABILITY




APPLICABILITY

Applicable for lighting service sold for outdoor lighting supplied from the existing overhead secondary and contracted for by a private Customer. The rating of lamps in lumens is for identification and shall approximate the manufacturer's standard rating .

MONTHLY RATE



Type of Fixture

100 Waft High Pressure Sodium (HPS) 200 Waft High Pressure Sodium (HPS) 175 Waft Mercury Vapor (MV) 400 Waft Mercury Vapor (MV)


Type of Fixture Lumen kWh/Month

100 Waft HPS 9,500 Lumen' 51 kWh 200 Waitt HPS 22,000 Lumen 2 86 kWh 175 Waft MV 8,150 Lumen' 74 kWh 400 Waft MV 21,500 Lumen 2 162 kWh

Delivery Charge

$8 .594-2 $14.8907 $8.884-6 $165.5704

Monthly Charge

$24.306 $24.874 $2-1-.3W $Z3.2942

'Cooperative will provide lamp, photo-electric relay control equipment, fixture, and upsweep arm not over four (4) feet in length, and will mount same on an existing pole carrying secondary circuits .

2COoperative will provide lamp, photo-electric relay control equipment, fixture, and upsweep arm not over six (6) feet in length, and will mount same on an existing pole carrying secondary circuits .

)-A W

W 0 NJ

Schedule OLN Effective : On All Bills Issued on and After July 1 . 2 )14ne4-, QM

Exhibit No.- Witness : DFK & JDG


When facilities, in addition to those specified previously are required to provide W outdoor lighting service, the Customer will pay in advance the cost of installing all 0

Rappahannock Electric Cooperative Schedule OLN Page 2

B. Electricity Supply Service Charges (continued)

additional facilities . For the Cooperative's facilities installed prior to December 13, 1985, the monthly rental charges will continue as follows:

1 . $2 .74 for each standard distribution wood pole required, 2 . $0.013 per foot for each foot of span length of wires required, and 3. $2 .74 of each kilovolt-ampere of transformer capacity installed .

The Customer may elect to own and maintain poles and secondary circuits on his property to accommodate the installation of the outdoor lighting fixture . Such poles and circuits shall meet Cooperative specifications .

All kilowatt-hours under this schedule will be adjusted as per Schedule %WCA-1-NT beginning july 1, 2014 .

Service is sold under contract to take continuous service under this rate schedule for a minimum period of three (3) years or longer for Distribution Delivery Charges.


V-WJI . GENERAL I

All Cooperative-owned facilities necessary for service under this schedule shall be maintained by the Cooperative and all such service and maintenance will be performed only during the Cooperative's regular scheduled working hours. The Cooperative shall be allowed two working days after notification by the Customer to replace all burned-out lamps.

All lamps are lighted from dusk to dawn every night, or for approximately 4,200 hours perannum.

The Customer shall obtain written approval from public authorities for lights to be

Schedule OLN Effective : On All Bills Issued on and After July 1 . M14pa-l-,2440

located on public thoroughfares.

Rappahannock Electric Cooperative Schedule OLN Page 3

V11 GENERAL (CONT)

Exhibit No . Witness : DFK & JDG Schedule : SA Page 37 of 39

The Customer shall select the location of all poles installed on the Customer's property under the provisions of this schedule . Pole relocation or removal will be at the Customer's expense. All pole locations shall conform to all safety standards, and state and municipal regulations. The Customer shall be responsible for all damages to, or loss of, the Cooperative's property located on the Customer's premises, unless resulting from causes beyond the Customer's control.

Schedule OLN Effective : On All Bills Issued on and After July 1 . 2 )14Ae4-,,'M

I-A

W

0 44

W

0


OUTDOOR LIGHTING SCHEDULE OL

Exhibit No.- Witness : DFK & JD0 Schedule : 5A Page 38 of 39

AVAILABILITY


APPLICABILITY

Applicable upon request to Customers along the lines of the Cooperative for street, highway, and ground lighting .

INSTALLATION CHARGE

The complete installation is to be furnished, maintained, and operated by the Cooperative and will remain the property of the Cooperative. All installation charges shall be in accordance with Article V1, Section H of the Cooperative's Terms and Conditions .

IV MONTHLY RATE



Type of Fixture Delivery Change

*175 Waft Mercury Vapor $7.006-60 *250 Watt Mercury Vapor $11 .1 *400 Watt Mercury Vapor $12.9106 *1,000 Waft Mercury Vapor $25.503-.47-

*90 Watt High Pressure Sodium $7.452-5 100 Waft High Pressure Sodium $7.5734 150 Waft High Pressure Sodium $8.494-5 400 Watt High Pressure Sodium $187-.2237


Type of Fixture kWh/Month Monthly Change

175 Waft Mercury Vapor 70 $il-i~iw *250 Waft Mercury Vapor 100 $42.~~W *400 Watt Mercury Vapor 150 $§4.ZP6 *1,000 Waft Mercury Vapor 360 $160.213

Schedule OL Effective : On All Bills Issued on and After July 1 . 2014

I`-b

W 0

Rappahannock Electric Cooperative Schedule OL Page 2

B. Electricity Supply Service Charges (continued) :


*90 Waft High Pressure Sodium 36 100 Waft High Pressure Sodium 40 150 Waft High Pressure Sodium 60 400 Waft High Pressure Sodium 150

V.

VII

TYPE OF FIXTURE

Exhibit No. Witness: DlTK & JDG Schedule: 5A Page 39 of 39

Monthly Charge

$1 .602 $1 .8044 $24.70

$§4.Z52-6

The type of fixture and method of installation shall be in accordance with the Cooperative standards .

*Replacement or new installations of fixtures marked by asterisk are not available under this rate .

Service for all units marked by an asterisk as listed in Section III will continue to be supplied at those locations being serviced at the rates set forth . In the event such an existing unit is discontinued at the Customer's option, it shall no longer be available at that location . No additional such units will be supplied, and in the event any such unit shall fail, and cannot be made operative in the field by either a bulb or electric eye replacement, at the Customer's option the Cooperative will, at the Cooperative's cost, after reasonable notification to the Customer, either (a) remove and not replace the defective fixture or (b) replace the same with a Cooperative high pressure sodium vapor fixture of the Customer's choice which will, thereafter, be billed at the appropriate rate .

WHQI=F!SAL-&P0WER COST ADJUSTMENT CLAUSE .


TERM OF CONTRACT

The term of contract for service under this schedule shall be such as may be mutually agreed upon, but not less than one (1) year, and to continue thereafter until terminated by a thirty (30) day wriften notice by either party.

Schedule OL Effective . On All Bills Issued on and After NevembeF 1, 2901kiply 1 ~2014

I~A

W 0 114

W 4a)

oil

6

I-A Rappahannock EC Exhibit No . - w Class Revenue Allocation Witness: JOG Jurisdictional Classes Schedule 58

Page 1 of 8 w Dollars In Thousands

Rate Yea Present Proposed Rate Year Present Proposed Revenue Revenue Revenue Plus Revenue Less Rate to Rate

Rate Class Customers MWh Revenue Revenue Difference Percent Deferred Ch . Mitigation Cr. Percent [Col . 1) lCol. 2) JCol. 3) (Col. 4) ICOI. S) (Col . 6) (Col . 7) (Col . 8) (Col . 9) (Col. 10)

Jurisdictional System:

I Schedule A 95,597 1,407,835 163,4125 $ 163,412.S 0.00% 2 Schedule R-NT 43,312 661,385 $ 65,760.2 $ 72,873.7 $ 7,113.S 10.82% $ 67,009 $ 71,068 6.06% 3 Schedule R-TOU 46 581 $ 63 .4 $ 67.3 $ 3.9 6.14% 4 Schedule B-1 3,303 56,529 $ 6,680.2 $ 6,680.2 $ - 0.00% S Schedule B-1 to B-3 1,077 67,182 $ 7,594.7 $ 7,713.5 $ 128.8 1.70% 6 Schedule B-3 is 1,267 $ 138.9 $ 138.9 $ - 0.00% 7 Schedule C-NT to B-1 2,022 18,056 $ 1,918.7 $ 2,227.1 $ 308.4 16.07% $ 1,953 $ 2,178 11.S2% 8 Schedule C-NT to B-3 301 22,371 $ 2,iZ3.0 $ 2,293.8 $ 170.8 8.0s% $ 2,16S $ 2,233 3.12% 9 Schedule G-NT to B-1 3,671 31,882 $ 3,400.3 $ 3,940.3 $ 540.0 is.&B% $ 3,460 $ 3,853 11.3S% 10 Schedule G-NT to B-3 78S S6,521 S,328.S $ S,6SO.2 $ 321.7 6.04% $ 5,43S $ S,496 1.12% 11 Schedule G-NT to LP-1 is 11,083 1,084.9 $ 1,191.3 $ 106.S 9.81% $ 1,106 $ 1,161 S.00% 12 Schedule LP-1 230 310,746 $ 28,019 .1 $ 28,019 .1 $ - 0.00% 13 Schedule PH-NT to B-3 7 1,387 $ 126.1 $ 13S.0 $ 8.9 7.07% $ 129 $ 131 1.9s% 14 Schedule PH-NT to LP-1 238 456,819 $ 3S.098 .6 $ 37,S71 .3 $ 2,482.6 7.08% $ 3S,9SI $ 36,324 1.0.4% 15 Schedule PP-NT to LP-3 2 127,109 $ 8,766.S $ 8,S07.7 $ (20.8) .2 .95% $ 9,006 $ 8,508 -S .S4% 16 Schedule HD-1 2 7,646 $ S99.2 $ S99.2 $ MOD% 17 Schedule LP-3 2 28,632 $ 1,697.8 $ 1,697.8 $ 0.00% 28 Schedule ALP-NT 66 $ 9.8 $ 9.8 $ (0 .0) 0.00% 19 Schedule MSL-NT 664 $ 201.8 $ 201.8 $ (0.0) 0.00% 20 Schedule CIL 13,181 $ 2,118.8 $ 2,119.3 $ 0.s 0.02% 21 Schedule OLN-NT 1,872 $ 355.1 $ 355.1 $ (0.0) -0.01% Z2 Schedule OLNT - Contract 1 $ 101.6 $ 101.6 $ 0.00%

23 24 Subtotal Jurisdictional 150,628 3,282,816 $ 334,S79.7 $ 345,506.S $ 10,926.8 3.27% 25 Schedule LP-2 1 641,119 $ 28,349 .9 $ 28,349 .9 R-2-0% 26 Total Jurisdictional ISO,6Z9 3,923,934 $ 362,929.6 $ 373,856.4 10,926.8 3.01% 27 otherRevenue $ 3,146.0 $ 3,146.0 - 28 Total Jurisdictional $ 366,07S.6 $ 377,002.4 10,926.8 2.98% 29 30 31 Consolidated Classes 32 33 Schedule A 138,909 2,069,220 $ 229,172.8 $ Z36,286.3 $ 7,113.5 3.10% 34 Schedule R-TOU 46 S81 $ 63.4 $ 67.3 $ 3.9 6.14% 3S Schedule B-1 8,996 106,467 $ 11,999.2 $ 12,847.6 $ 848.4 7.07% 36 Schedule 9-3 2,188 148,728 $ 1S,301 .2 $ 15,931 .5 $ 630.3 4.12% 37 Schedule LP-1 483 778,648 $ 64,19Z.6 $ 66,781 .7 S 2,S89.1 4.03% 38 Schedule HD-1 2 7,646 $ S99.2 $ S99.2 $ - 0.00% 39 Schedule LP-3 4 155,741 $ 10,464.3 i0o20S .5 $ (2S8.8) -2.47% 40 Lights - 1So78S $ 2,787.2 2,787.6 $ 0.4 0.02%

41 42 Total 150,628 3,282,816 $ 334,S79.7 $ 345,S06.5 $ 10,926 .8 3.27% 43 Schedule LP-2 1 641,119 $ 28,349 .9 $ 28,349 .9 $ 122% 44 45 Total 150,629 3,923,934 $ 362,9Z9.6 $ 373,856.4 $ 10,926 .8 3.01%

1350730201

z 'Z 'm

CL

m a Q.

ci 19 888 c5 cl I 8 8 a 8 2 - 9 8 8 8 888

kcL

o

It ul P% Ict gw

wL Ci ai . . . . a a

. . . .

ct ai P st R IR

L L ux li

vt

pt

'i

!Q cli

M

a a a ai

o N dl I

CR IR li -t c p 8 m N , . R t t

,% R IL A

le m r. cc w

at ci mw NO

om, co

ul

- It

co a ca tj 4r

4=1 wN 4=1 =6 w

cc

I

c o ig c c o c v .4 E

1

12 12 - 9 : 9 :2 :2 :2 2 2 M 2 2 ar R 3: c c cc cc 2 M w. a: le cc a: cc ~: Q w 19

Mm Q ~ " m v m A o 29 " m a In -a w I t, w m R w w rl

130730201 ~-.v 1

c; S

c 3:

-0

0

60',99 9 988 vt

999 co g 99

A 9 It ~~ 4~ I'ZZ Z 10

9

9

w s 0 to 8 v Si

I It ai

00 8 Q

C ;

to I I I I m rlt Ict a; I I et 0 Ul ro

rz cc

co "i mwmm I k-L

c, N

mw ul q -t -L

o

;z ',Z

i

z. a P a, I ~ a; rz t It t It t lo In .

-

Ln

do o wi M

co o m m .

l P, a; o a; It

P m LA m Ll; ch

c2l UL

C6 ~l R

4

m at N I

0 m

0 4

I

I

I

10

N

c cc c c c s g It W c 0 0 c 4. c c .2 A CZ c I cc ~l m ~'2 I i % i A m 12 v i"2 i-2 t w & I I i i ~ t 1'2

c w rj t r, L3 01 . . . t cc w 3: 1 -

5 :e -0 i 5 v In 2 lic al etc 22" 3: cr 99 iz rx iz 3: 2S ;i 3 -0

130730201

Z Z z "gill Z91 9 11 z z 6 ca 0 4 9 9 9 o g i i 6 c;

m A ct ;i

Io co P: c; r: Le ck ul LQ

In mN

m N cr. ;z 12 m L" co cL 19, Imo IT. -~,i . . . . sa

c-m d d ew. A N

2 ~ "t Q v . . . tR 4 99 . . . . at 'L Itt ax o

8 cm 4

alt

cm Ict is

ca c,

I

cr

aL mv cr

sw c cc cc

;"2 12 2 12 w

cc ol T3

o cc cc :c9c w cc

w. A A cc N

Rappahannock Electric Cooperative Class Revenue Allocation All Classes

Per Books Adjusted

Exhibit No. VAtness: JDG Schedule 5 : Paso 5 of

Consumer Equivalent Equivalent Per Books Adjusted Per Books Adjusted Proposed w

Classification Bills Bills kft kWh Revenve Revenue Revenue Difference Percent (Col . 1) (Col. 2) (Col. 3) (Col. 4) jcol. 5) (Col. 6) (Col . 7) (Col. 8) (Col . 9) (Ccd. 10)

219 Jurisdictional System - Adfust W 220 Matching fuel revenue to fuel cost - Legacy S 3S8,972 5 $ 0 0 221 Matching fuel revenue to fuel cost - NT $ (332,046) $ 0 0 222 2Z3 Total Jurisdictional Syst 224 Distrfbtution Revenue 149,925 150,629 3,870,733,5&2 3,923,934,417 $ 94.609,142 S 9SSW,485 10S,165,029 $ 9,664,S44 10 .12% US ESS Revenue S 177 .923,094 S 178,6SO,962 $ Z68,691,417 $ 90,040,55S 50 .40% 226 Rider P-1-12 $ (1 .938,376) S 13,019,279) $ S 3,019,279 -100 .00% 227 Rider P-1-13 $ - $ 12,824,487) $ $ 2,824,487 -100 .00% 228 Rider RSU-1-NT S IS.26SX3 $ LS,670,338 S 5 (IS,670,338) -100 .00% 229 WPCA Revenue $ 89,706,934 S 78,951,697 $ $ (78,9S1,697 -IGO-00% 230 Total $ 375 .S69,617 S 36Z,929,617 S 373,956,446 $ 10,926,829 3 .01% 231 232 Other Revenue $ 3.1",004 S 3,146,004 $ 3,146,004 $ 0.00% 233 234 Grand Total Jurisdictional System 149,925 150,629 3,870,733,S82 3,923,934,417 S 378.71S,621 $ 366,075,621 $ 377,002,450 S 10,926,829 2.99% 23S

130730201

lu

- r a q P,

'a ~ 3 v

t % t ~

In

N Ul Cli m

12 12 5 1,2 we it cr CC 13

0 0 w cr. a: w

cc cr a: :c2c w w cc w

06 A N N -ft N m

cl

1307302VI a

Ila

q M r% IcL -1 Ci K Ct cR e L't et

mw L N lo * co 4 c .

Ut Ct x u

c

rz v w

z ON cc cc ON c 0 .4 1

CT 12 52 1-2 '2 Cc cc

~O -Om mcc 12 mo .0 :c2c 'R 3: 3: .2

CL -a w N cc m 0

1307302UI 1~ -~ ~ 0

13

a C C ' P a a a w m r; 0 0 t

9

t a

t M

% L i i

co 14 8 0- 5

all

2 2 N So 5 I c

62 zo oN v :3 M4 3

12 c r- cc 12 - S 9 cc cc I .2 12 cc w w

I cc cc ir

0 0 0

a 4 9 2 S 5t gt In a F, cc mm A om om, m A A ~ m m A

Rappahannock Electric Cooperative€¦ · Rappahannock Electric Cooperative Details of Ratemaking...

Documents

Transcript of Rappahannock Electric Cooperative€¦ · Rappahannock Electric Cooperative Details of Ratemaking...