Rappahannock Electric Cooperative Details of Ratemaking Adjustments

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2 Rappahannock Electric Cooperative Details of Ratemaking Adjustments Exhibit No. itness: CBL & JDG Schedule 4A Page I of 6 Adjustment Nos Line No. Operating Revenue Description 1 Base Rate 2 Riders 3 PCA 4 Schedule LP-2 5 Growth Adjustment 6 Subtotal 7 Fee Revenues 10 Other Revenue 11 Total Revenue Production & Purchased Power 15 Margin Stabilization 16 Other Operating Expenses 17 Depreciation 18 Tax Expense - Property 19 Tax Expense - Other 20 Total Operating Expenses Operating Margins Less : Interest on Cust Deposits 25 Charitable and Educ Donations 26 Operating Margins - Adjusted Plus :Capital Credits Accrued 29 Other Income 30 Less : Interest on Long Term Debt 31 Other interest Expense 32 Other Expense 33 Total Margin Rate Base 36 Net Utility Plant 37 Allowance For orking Capital 38 Other Rate Base Deductions 39 Total Rate Base Column 2 Reclassify Property Tax-w/ orking Capital Total Pronerty Tax 2 adi~ 29i~!g (Col. 1) (Col. 2) (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)

3 11-A Exhibit No. itness : CBL & JDG Schedule 4A Page 2 of thru 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 $ - $ - $ $ $ $

4 Exhibit No. itness : CBL & JDG Schedule 4A Page 3 of 6 F" w Im %J w a Pension Prepay Pension Cafeteria Major Storm Amortization Expense Plan Rate Case RO 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)

5 Exhibit No. itness: CBL & JDG Schedule 4A Page 4 of 6 w 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

6 Exhibit No. itness : CBL & JDG Schedule 4A Page 5 of 6 I~A w a 141 w Interest orking 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

7 Exhibit No. itness : CBL & JDG Schedule 4A Page 6 of 6 H w 43 %J w Adjustment to Adjustment to Base Rate PCA and Rate Adjustment to orking 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, $ 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

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9 Rappahannock Electric Cooperative Detail of Ratemaking Adjustments For the 12 Months Ending December 31, 2012 H Exhibit No. itness: CBL & JD40 Schedule 40 Page 1 of Adj No. Description Explanation of Operatinp Expense Adoustments Amount H 2-1 Tax Expense - Property Adjustment to Reclassify Property Tax $ (4,282,781) 2-2 Tax Expense - Property 2-3 Allowance for orking Capital Adjustment to Reclassify Property Tax 4,282,781 Adjustment to orking Capital to Reflect Reclassified Taxes (528,014) 6-1 Base Rate Revenue Adjust Base Rate Distribution Revenue for Unbilled Sales and Customer Growth 891,343 6-la Base Rate Revenue Adjust Base Rate ESS Revenue for Unbilled Sales and Customer Growth 2,156, 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 (1,080,903) (2,824,487) 401, Fuel - PCA Revenue Adjust to Annualize VrPCA Revenue Based on Rate Year Sales and the Current REC Fuel Rate (10,755,237) 6-6 Purchased Power To Adjustment Bear Island Schedule LP-2 Revenue (1,428,768) 6-7 Growth Adjust Adjustment to Roll Unbilled Revenue into Rate Year Sales Revenue Calculations (524,573) 6-9 Purchased Power To adjust Purchased Power Expense for ODEC rate change 1,308, Other 0 & M Expense Adjustment to Uncollectible Accounts Expense 780, Other 0 & M Expense Adjustment to Payroll Expense 948, Tax Expense - Other Adjustment to Payroll Taxes Expense 6-12 Other 0 & M Expense Adjustment to 401 K Employer Contribution Expense 67,973 55, Other 0 & M Expense Adjustment to Reflect Pension Prepayment Amortization 789, Other 0 & M Expense Adjustment to Pension Expense (72,958) 6-15 Other 0 & M Expense Adjustment to Cafeteria Plan Expense 125, Other 0 & M Expense Adjustment to Rate Case Expense 74,500

10 Rappahannock Electric Cooperative Detail of Ratemaking Adjustments For the 12 Months Ending December 31, 2012 Exhibit No. itness : CBL & JD43 Schedule 4 Page 2 of~ Adj No. Descrii)tion Explanation of Overatin?, Expense Adoustments Amount ) Other 0 & M Expense Adjustment to Right of ay Clearing Expense (185,914) 6-18 Other 0 & M Expense 6-19 Other 0 & M Expense 6-20 Other 0 & M Expense 6-21 Other 0 & M Expense 6-22 Other 0 & M Expense 6-23 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 orking Capital Adjustment to Normalize Major Storm Damage Adjustment to Information Technology Expenses Adjustment to Property Insurance and orkers' 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 orking Capital to Reflect Adjustments to O&M Expenses and Deferred Fuel Balance as of 5/31/2013 (406,562) 3,947 71, , ,076 23, , , ,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/ ,510

11 Rappahannock Electric Cooperative Detail of Ratemaking Adjustments For the 12 Months Ending December 31, 2012 Exhibit No. itness : CBL & JDG Schedule 4B Page 3 of 3 AdJ No. Description Explanation of Operating Expense Adjustments Amount 8-1 Base Rate Revenue Adjustment to increase base rate revenue to reflect the proposed retail rates 99,705, Roll-in Rider Surcharge & PCA Adjustment to decrease revenue for the roll-in of rider surcharges and the PCA (88,778,269) 8-3 Uncollectible Accounts 8-4 orking Capital 11-1 Schedule TMR Discounts 11-2 Uncollectible Accounts 11-3 orking Capital 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

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14 1~a RAPPAHANNOCK ELECTRIC COOPERATIVE RATE SCHEDULES AND RIDERS CLEAN

15 TRANSITION MIGRATION RIDER - NT SCHEDULE TMR Exhibit No I-A itness: DFK.- & JDG Schedule : 5A 0 Pagel of4l 114 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 Schedule TMR shall expire no later than June 30, 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 Schedule Factor Unit Schedule A Customers formerly served First 1,000 kh $ per kh on Schedule R-NT Over 1,000 kh $ per kh Schedule B-1 Customers with demand Access Charge $-7.80 per customer less than 25 k and Next 700 kh $ per kh formerly served on Over 700 kh $ per kh Schedules C-NT and G-NT Schedule B-3 Customers with demand Access Charge - Single Phase $ per customer greater than 25 k and Access Charge - Three Phase $ per customer formerly served on First 100 k $ per k Schedules C-NT & G-NT Over 100 k $ per k First 100 kh/k $ per kh Next 100 kh/k $ per kh Next 200 kh/k $ per kh Over 400 kh/k $ _ per kh Schedule LP-11 Customers with demand 57.99% per dollar of greater than 200 k and distribution formerly served on revenue Schedule G-NT Effective : Bills issued On and After July 1, 2014 through June 30, 2015.

16 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA Exhibit No. itness : DFK & J Schedule: 5A Page 2 of 41 POER 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 kh 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 kh sales, kh 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 ESS Base khs PCP Revenue produced by the base Energy Supply Service part of each tariff. $ per kh sold reflecting the annual system average base ESS Revenue per kh sold. The total projected kh to be purchased in the applicable rate year times the Loss Factor. 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 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.

17 Rappahannock Electric Cooperative Schedule PCA-11 Page 2 DEFINITIONS (continued) Exhibit No. itness: DIFK & JDG Schedule : 5A Page 3 of 41 )4 0- C5 U EA SEPA Factor Loss Factor Any Under Recovery balance recorded on the Cooperative's balance sheet as of the most recent accounting month available. ODEC's Energy Adjustment rate from time to time, expressed in $ per kh. One minus the ratio of annual SEPA kh purchased to total annual kh purchased based on historical data. One minus the estimated kh loss percentage based on historical data. IV. 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 khs ESS Base + EAr here ; 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 kh sales for the month times $ , Booked revenues and kh sales will be net of any applicable unbilled adjustments. $ represents cost per kh 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 bills rendered on and after July 1, 2014.

18 Rappahannock Electric Cooperative Schedule PCA-1 Page 3 Exhibit No. H itness: DFK & JD&J Schedule: 5A Page 4 of 41 (Over) and Under Recovery Amounts, if any, will be credited or debited to accounts Deferred Credit - PCA or Deferred Debit - PCA, with <0 10A corresponding credits or debits to Purchased Power - PCA. 40 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, khs, 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 Page 3 Filed State Corporation Commission Effective for bills rendered on and after July 1, 2014.

19 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA POER COST ADJUSTMENT RIDER SCHEDULE PCA-11 (IN Exh i bit No.- itness: DFK & JDG Schedule : SA Page 5 of 41 I,& Q 14pa 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. 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 kh 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 kh sales, kh 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 ESS Base khs Revenue produced by the base Energy Supply Service part of each tariff. Not applicable 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 Filed State Corporation Commission Effective for service rendered on and after January 1, 2014.

20 1~.a Rappahannock Electric Cooperative Interim Schedule PCA - I Exhibit No.- <0 itness : DFK & JDG %J Page 2 Schedule : 5A Page 6 of 41 IV. FORMULA PCA = Rider RS Rider RS PCA 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 kh sales for the month times $ Booked revenues and kh sales will be net of any applicable unbilled adjustments. (Over) and Under Recovery Amounts, if any, will be credited or debited to accounts Deferred Credit - PCA or Deferred Debit - PCA, with corresponding credits or debits to 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 NT Applicable to customers of the Cooperative who receive service within the territory acquired by Rappahannock Electric Cooperative as approved in PUE a. A charge of $ per kh, and ; b. A charge of $ per kh be applied through June 30, 2014, in accordance with the conditions prescribed in requirement 2) of the Final Order in Case No. PUE $ represents cost per kh 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.

21 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA FARM, HOME AND CIVIC SERVICE SCHEDULE A Exhibit No. itness : DfK & JDG Schedule: 5A Page 7 of 41 H 0 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. 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. ith the exception of church sanctuaries, the maximum demand to be provided under Schedule A shall be 200 k. 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 Energy Delivery Charges : First 300 kh per month Over 300 kh per month $10.00 per month $12.15 per $ per $ per kh B. Electricity Supply Service Charges : All kh per $ per kh 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

22 Exhibit No. itness : DJFK & JDG Schedule : 5A Rappahannock Electric Cooperative Schedule A Page 8 of 41 Page 2 V. 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. V1. POER 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. Vil 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

23 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA SMALL GENERAL SERVICE SCHEDULE B-1 Exhibit No. itness: Dk & JDG Schedule: 5A Page 9 of 41 0 IVA 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. 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 k. TYPE OF SERVICE 60 hertz, single-phase, at available secondary voltages. IV MONTHLY RATE A. Distribution Delivery Charges : Access Charges : Single-Phase Service Energy Delivery Charges : All kh delivered $28.00 per $ per kh B. Electricity Supply Service Charges : All $ per kh 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 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

24 Exhibit No.- itness: DFK & JDG Rappahannock Electric Cooperative Schedule : 5A Schedule B-1 Page 10 of 41 Page 2 1-h a Vi. POER 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. Vil 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. 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. 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

25 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA SMALL GENERAL SERVICE SCHEDULE B-3 Exhibit No. itness : Dk & JDG Schedule : 5A Page I I of 41 ~A 0 4 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. APPLICABILITY Applicable to multi-phase Customers, and any single-phase Customer whose actual demand exceeds 25 k 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 k TYPE OF SERVICE 60 hertz, multi-phase where available, at available secondary voltages. IV. MONTHLY RATE A. Distribution Delivery Charges : Single-Phase Access Charge Multi-Phase Access Charge $28.00 per $47.50 per month Demand Delivery Charge : First 100 k of billing demand $1.50 per k Over 100 k of billing demand $9.00 per k Energy Delivery Charges : First 100 kh per k delivered Next 100 kh per k delivered Next 200 kh per k delivered Over 400 kh per k $ per $ per $ per $ per kh B. Electricity Supply Service Charges: Energy Charges : First 100 kh per k Next 100 kh per k Next 200 kh per k Over 400 kh per $ per $ per $ per $ per kh Schedule B-3 Effective : On All Bills Issued on and After July 1, 2014

26 Rappahannock Electric Cooperative Schedule B-3 Page 2 Exhibit No.- itness : DFK & JDG Schedule : 5A Page 12 of 41 I~A 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. POER 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. VII. 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. 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 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-3 Effective : On All Bills Issued on and After July 1, 2014

27 Rappahannock Electric Cooperative Schedule LP- I Page I RAPPAHANNOCK ELECTRIC COOPERATIVE. Fredericksburg, VA Exhibit No. itness: DFK & JDG Schedule : 5A Page 13 of 41 I-A 0 LARGE POER SERVICE SCHEDULE LP-1 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. APPLICABILITY Applicable to all Customers along the lines of the Cooperative contracting for a load of 100 k or more. TYPE OF SERVICE Multi-phase, 60 hertz, at available voltage. IV MONTHLY RATE A. Distribution Delivery Charges : Access Charge : Demand Delivery Charges : First 100 k of billing demand delivered Next 400 k of billing demand delivered Next 1,500 k of billing demand delivered Over 2,000 k of billing demand delivered Energy Delivery Charges : First 100 kh per k delivered Next 100 kh per k delivered Next 200 kh per k delivered Over 400 kh per k $ per $1.50 per $1.25 per $ 1.10 per $1.00 per $ per $ per $ per $ per kh Voltage Discount (k) : 2 kilovolt (kv) to 15 kv $0.25 per k Over 15 kv $0.50 per k Schedule LP-1 Effective : On All Bills Issued on and After July 1, 2014

28 Rappahannock Electric Cooperative Schedule LP-1 Page 2 Exhibit N,.- itness: DFK Schedule & JDG : SA Page 14 of 41 I~A a IV. MONTHLY RATE (Continued) B. Electricity Supply Service (ESS) Charges : Demand Charge : All k of ESS Billing $8.15 per k Energy Charges : First 100 kh per k of ESS Billing $ perkh Next 100 kh per k of ESS Billing $ perkh Next 200 kh per k of ESS Billing $ perkh Over 400 kh per k of ESS Billing $ perkh V 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. $ B. $0.50 times the highest average k of demand measured in any 15-minute interval during the current billing month. C. The minimum specified in any contract currently in force. V1. 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. ii. The highest average k of demand measured in any 15-minute interval during the current billing month, or 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 k. b. For Customers whose billing demand as determined under VI. A. 1. above exceeds 1,000 k, 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: Schedule LP-1 Effective: On All Bills Issued on and After July 1, 2014

29 Rappahannock Electric Cooperative Schedule LP-1 Page 3 Exhibit No. itness: D17K & Mr, Schedule : SA Page 15 of %J 0 DETERMINATION OF BILLING DEMANDS (CONT.) i. The highest average k 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. C. The ESS Billing Demand shall be the highest average k of demand measured in any 15-minute interval during the current billing month. 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 POER 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. Vill HOLESALE POER 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. IX. 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. Schedule LP-1 Effective : On All Bills Issued on and After July 1, 2014

30 Rappahannock Electric Cooperative Schedule HD-1 Page I RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA LARGE POER HIGH DIVERSITY SERVICE SCHEDULE HD-1 Exhibit No. itness: DFK & Mr, Schedule: SA Page 16 of 41 i-a 0 SJ 0 ki 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 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 k or more. CONDITIONS OF SERVICE A. B. 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. 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. IV TYPE OF SERVICE Multi-phase, 60 hertz, at available voltage. V. MONTHLY RATE A. Distribution Delivery Charges : Access Charge $ per month Demand Delivery Charge : All k of Maximum Billing Demand $ 1.10perk Energy Delivery Charges : First 100 kh per k delivered Next 100 kh per k delivered Next 200 kh per k delivered Over 400 kh per k $ per $ per $ per $ per kh Schedule HID-1 Effective : On All Bills Issued on and After July 1, 2014

31 Rappahannock Electric Cooperative Schedule HD-1 Page 2 Exhibit No. itness: DFK & JDG Schedule: 5A Page 17 of 41 I-A 0 %J V. MONTHLY RATE (CONT.) B. Electricity Supply Service Charges: holesale Billing Demand : 1. The charges for holesale 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 k of Excess Demand will apply each month. Energy Charges : 1. The Customers kh usage for the month times the prevailing ODEC Transmission Energy Rate adjusted to compensate for the applicable distribution losses. 2. The Customer's kh usage for the month times the corresponding monthly ODEC Energy Cost Adjustment adjusted to compensate for the applicable distribution losses V1 MINIMUM MONTHLY DELIVERY CHARGE 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. VII DETERMINATION OF BILLING DEMANDS The billing demands for each month shall be : A. Distribution Delivery Demand - The greater of : a) the highest average k of demand measured in any 15 minute interval during the current billing month, or b) 500 k. B. holesale Billing Demand - holesale 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 k 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

32 Rappahannock Electric Cooperative Schedule HD-1 Page 3 Exhibit No itness : DFK.- & JDG Schedule : 5A Page 18 of 41 I-A 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 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. ix POER 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. X 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

33 Exhibit No. itness : DFK & JDG Schedule : 5A Page 19 of 41 H RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, Virginia INTERRUPTIBLE SERVICE RIDER SCHEDULE IS-1 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 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 k 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 Multi-phase, 60 hertz, at available voltage. 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 k. 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

34 Exhibit No. itness: DFK - & JDG Schedule : 5A Page 20 of 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 : 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

35 Exh i bit No. itness : DFK & ]DO Schedule : SA Page 21 of 41 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, Virginia 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, TYPE OF SERVICE Multi-phase, 60 hertz at available voltage. MONTHLY CHARGES Monthly charges shall be : A. B. C. D. E. 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 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 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 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 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

36 Rappahannock Electric Cooperative Schedule LP-2 Page 2 Exhibit No. itness: DTK & JDG Schedule: 5A Page 22 of 41 ~'A 40 Note : Only charges B through F apply if the Customer has an Electricity Supplier other than the C ooperative as their energy provider. IV. 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. V 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. V1. 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. Vil 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. Vill. 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 July 1, 2014

37 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA LARGE POER SUBSTATION DIRECT SERVICE SCHEDULE LP-3 Exhibit No._ itness : DFK & JDG Schedule: 5A Page 23 of 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 Applicable to Customers Applicable to Customers with monthly capacity requirements of 5,000 kilowatts (k) 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 Multi-phase, 60 hertz, at available voltage. IV. MONTHLY RATE A. Distribution Delivery Charges : 1. Applicable to qualifying Customers taking service from the Cooperative as of November 1, Access Charge $ per month Demand Delivery Charge $ 1.10 per k Energy Delivery Charge $ per kh 2. Applicable to qualifying Customers taking service from the Cooperative on Schedule PP-NT as of June 30, Access Charge : Demand Delivery Charge : Energy Delivery @ $ per month $1.28 per k $ per kh Schedule LP-3 Effective : On all Bills Issued on and After July 1, 2014

38 Rappahannock Electric Cooperative Schedule LP-3 Page2 Exhibit No.- itness : DFK & JDG Schedule : 5A Page 24 of 41 I-& a %J 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 $ per month $0.18 per k Facilities Charge : A facilities charge equal to the installed costs of dedicated local facilities times the applicable factor as follows : ithout 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% ith 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. B. Electricity Supply Service Charges : holesale Billing Demand : 1. The charges for holesale 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 k of Excess Demand will apply each month. Energy Charges : The Customers kh usage for the month times the prevailing ODEC Transmission Energy Rate adjusted to compensate for the applicable distribution losses. Schedule LP-3 Effective : On all Bills Issued on and After July 1, 2014

39 Exhibit No itness : DFK.- & JDG Rappahannock Electriic Cooperative Schedule : 5A Schedule LP-3 Page 25 of 41 Page3 MONTHLY RATE (continued) B. Electricity Supply Service Charges : (continued) 0 ~A 2. The Customer's kh 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 A. Distribution Delivery Demand - The greater of : a) the highest average k of demand measured in any 15 minute interval during the current billing month, or b) 500 k. B. holesale Billing Demand - holesale 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 k 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 POER 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. Schedule LP-3 Effective : On all Bills Issued on and After July 1, 2014

40 Exhibit No.- itness: DFK & JDG Schedule: 5A Rappahannock Electric Cooperative Page 26-of 41 Schedule LP-3 Page4 H 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. Schedule LP-3 Effective : On all Bills Issued on and After July 1, 2014

41 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA Exhibit No.- itness : DFK & JDG Schedule : 5A Page 27 of 41 1-h 40 %J AVAILABILITY TIME OF USE SERVICE SCHEDULE R-TOU 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. IV MONTHLY RATE A. Distribution Delivery Charges : Access Charges : Single-phase Service Multi-phase Service Energy Delivery Charges : First 300 kh per month Over 300 kh per month $10.00 per month $12.15 per month * $ per kh * $ per kh B. Electricity Supply Service Charges : All On-Peak kh - June - September All On-Peak kh - October - May All Off-Peak $ per $ per per kh V DETERMINATION OF ON-PEAK AND OFF-PEAK KH A. On-Peak kh - Summer includes the months of June through September and is defined as kh 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 kh - Non-Summer includes the months of October through May and is defined as kh used on Schedule R-TOU Effective : On Bills issued On and After July 1, 2014 Page 1

42 Exhibit No. itness : DFK & JDG FA Schedule : 5A Schedule RJOU Page 28 of4l 40 IIJ Page 2 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 kh is defined as all kh 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. POER 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. 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

43 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA PRIVATE OUTDOOR AREA LIGHTING SERVICE - NT (Closed December 13,1985) SCHEDULE AL Exhibit No.- itness: DFK & JDG Schedule : 5A Page 29 of 41 J.A Q *4 AVAILABILITY Available In the territory acquired by the Cooperative in Case No. PUE , 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, 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 att High Pressure Sodium (HPS) $ aft Mercury Vapor (MV) $ att Mercury Vapor (MV) $29.82 Standard ood Poles Length Monthly Charge 35 feet $ feet $3.88 Overhead Circuit $0.013 per foot for each foot of span length B. Electricity Supply Service Charges : Type of Fixture Lumen kh/month Monthly Charge 400 aft HPS 50,000 Lumen 167 kh $ aft MV 21,500 Lumen 162 kh $ aft MV 60,000 Lumen 386 kh $17.38

44 IV Rappahannock Electric Cooperative Schedule AL Page 2 POER COST ADJUSTMENT Exhibit No. itness : DFK & J-DG Schedule: SA Page 30 of a %J All kilowatt-hours under this schedule will be adjusted as per Schedule PCA-1. V. 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. VI 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. hen 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. hen 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. hen 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

45 Vil. Rappahannock Electric Cooperative Schedule AL Page 3 CUSTOMER ONED EQUIPMENT - COMPANY OPERATES AND MAINTAINS Exhibit No.- witness: DFK & JDG Schedule : 5A Page 31 of 41 I-^ a %j 10 henever 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 aft Mercury Vapor (MV) 175 aft Mercury Vapor (MV) Delivery Charge $4.50 $4.77 B. Electricity Supply Service Charges : Type of Fixture 100 aft MV 175 att MV kh/month 45 kh 74 kh 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 hen the Customees equipment is intermediate in size to those listed above the Customer shall pay the monthly charges applicable to the next larger size. Schedule AL Effective : On All Bills Issued on and After July 1, 2014

46 Exhibit No.- itness: DFK & JDG Schedule : 5A Page 32 of 41 1-b RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA STREET AND HIGHAY LIGHTING SERVICE - NT SCHEDULE MSL Closed to new services after June 30, 2014 COOPERATIVE-ONED AND MAINTAINED EQUIPMENT A. Availability Available in the territory acquired by the Cooperative in Case No. PUE , 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 Distribution Delivery Charges: Monthly Distribution : Tvoe of Fixture - Overhead Supoly Delivery Charge High Pressure Sodium (HPS) - ood Pole 70 att HPS $ aft HPS $ aft HPS $ aft HPS $ Mercury Vapor (MV) - ood Pole (restncled to installations as of October 1, 1 993) 175 aft MV $ 8.12 Mercury Vapor (MV) - ood Pole (restricted to installations as of October 3, 1991) 250 aft MV $ att MV $ 13.85

47 Exhibit No. itness: DIFK & JDC; Schedule : 5A Rappahannock Electric Cooperative Page 33 of 41 Schedule MSL Page 2 #-A Distribution Delivery Charge - Monthly Rate (continued) Type of Fixture - Underground Supply High Pressure Sodium (HPS) Delivery Charge Standard Pole - Low Mounting 70 aft HPS $ aft HPS $ Standard Pole - High Mounting 100 aft HPS $ aft HPS $ aft HPS $ Rectangular Enclosed - Standard Pole - High Mounting 200 att HPS $ aft HPS $ Rectangular Enclosed - Multiple units for each additional fixture per pole 200 aft HIPS $ aft HPS $ Mercury Vapor (MV) Standard Pole - Low Mounting (restricted to installations as of October 1, 1993) 175 aft MV $ Standard Pole - High Mounting (restricted to installations as of October 3, 199 1) 400 aft MV $ 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. hen 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.) Schedule MSL Effective : On All Bills Issued on and After July 1, 2014

48 Exhibit No. itness: DfK & JDG Schedule : 5A Rappahannock Electric Cooperative Page 34 of 41 Schedule MSL Rage 3 ~-A Monthly Rate (continued) 2. Electricity Supply Service Charges : Type of Fixture Lumen kh/month Monthly Charge 70 aft HPS 5,800 Lumen 37 kh $ aft HPS 9,500 Lumen 51 kh $ aft HPS 22,000 Lumen 86 kh $ aft HPS 50,000 Lumen 167 kh $ aft MV 8,150 Lumen 74 kh $ aft MV 11,500 Lumen 103 kh $ att MV 21,500 Lumen 162 kh $7.29 D. Power Cost Adjustment All kilowatt-hours under this schedule will be adjusted as per Schedule PCA-1. 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. hen 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. hen 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. hen 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 : Schedule IVISIL Effective : On All Bills Issued on and After July 1, 2014

49 Exhibit No.- itnm: DFK & JDG Rappahannock Electric Cooperative Schedule : 5A Page 35 of 41 Schedule MSL Page 4 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-ONED 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. Schedule MSL Effective : On All Bills Issued on and After July 1, 2014

50 Exhibit No. itness : DfK & JDG Schedule : 5A Rappahannock Electric Cooperative Page 36 of 41 Schedule MSL Page 5 C. Monthly Rate 1. Distribution Delivery Charges : Monthly Distribution : Member Owned Fixture - Hiah Pressure Sodium Deliverv Charae 70 att HPS $ att HPS $ att HPS $ att HIPS $ Electricity Supply Service Charges : Type of Fixture Lumen kh/month Monthly Charge 70 aft HPS 5,800 Lumen 37 kh $ aft HPS 9,500 Lumen 51 kh $ att HPS 22,000 Lumen 86 kh $ att HPS 50,000 Lumen 167 kh $7.52 hen 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 All kilowatt-hours under this schedule will be adjusted as per Schedule PCA-1. 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

51 Rappahannock Electric Cooperative Schedule IVISL Page 6 G. Con nection/disconnection Fee Exhibit No. itness: DFK & JD(; Schedule : 5A Page 37 of 41 a 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. INA 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. Schedule MSL Effective : On All Bills Issued on and After July 1, 2014

52 Exhibit No.- itness: DFK & JDG Schedule : 5A Page 38 of 41 IRA RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA <0 OUTDOOR LIGHTING SERVICE - NT SCHEDULE OLN Closed to new services after June 30,2014 AVAILABILITY Available in the territory acquired by the Cooperative in Case No. PUE , subject to the Terms and Conditions of the Cooperative on file with the Virginia State Corporate Commission. 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 A. Distribution Delivery Charges : Monthly Distribution : Type of Fixture Delivery CharQe 100 att High Pressure Sodium (HPS)' $ att High Pressure Sodium (HpS) 2 $ att Mercury Vapor (MV) 1 $ aft Mercury Vapor (MV) 2 $ B. Electricity Supply Service Charges : TvDe of Fixture Lumen kh/month Monthlv Charae 100 att HPS 9,500 Lumen 51 kh $ att HPS 22,000 Lumen 86 kh $ att MV 8,150 Lumen 74 kh $ att MV 21,500 Lumen 162 kh $ 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.

53 bxhiblt NO.- itness: DFK & JDG Schedule : 5A Rappahannock Electric Cooperative Page 39 of 41 Schedule OLN Page 2 B. Electricity Supply Service Charges (continued) hen facilities, in addition to those specified previously are required to provide 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 : H 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. POER COST ADJUSTMENT All kilowatt-hours under this schedule will be adjusted as per Schedule PCA-1. 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. 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. 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

54 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA OUTDOOR LIGHTING SCHEDULE OL Exhibit No.- itness: DFK & JDG Schedule : 5A Page 40 of 41 F-A -0 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. 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 A. Distribution Delivery Charges : Monthly Distribution : Type of Fixture *175 att Mercury Vapor *250 aft Mercury Vapor *400 aft Mercury Vapor *1,000 aft Mercury Vapor *90 aft High Pressure Sodium 100 aft High Pressure Sodium 150 att High Pressure Sodium 400 att High Pressure Sodium Delivery Charge $ 7.00 $11.17 $12.91 $25.50 $ 7,45 $ 7.57 $ 8.49 $18.22 B. Electricity Supply Service Charges: Type of Fixture kh/month Monthly Charge *175 att Mercury Vapor *250 att Mercury Vapor *400 att Mercury Vapor *1,000 aft Mercury Vapor Schedule OL Effective : On All Bills Issued on and After July 1, $ $ $ $16.21

55 Rappahannock Electric Cooperative Schedule OL Page 2 txnjbjt No.- itness : DFK & JDG Schedule : SA Page 41 of 41 PA 0 1J B. Electricity Supply Service Charges (continued) : Type of Fixture kh/month Monthly Charge *90 att High Pressure Sodium aft High Pressure Sodium aft High Pressure Sodium att High Pressure Sodium 150 $1.62 $1.80 $2.70 $6.75 V TYPE OF FIXTURE 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 POER 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. Vil 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 written notice by either party. Schedule OL Effective: On All Bills Issued on and After July 1, 2014

56 j..a w RAPPAHANNOCK ELECTRIC COOPERATIVE RATE SCHEDULES AND RIDERS BLACKLINE

57 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA FARM, HOME AND CIVIC SERVICE SCHEDULE A Exhibit No. itness : DFK & JD(~A Schedule : 5A Page I of 39 0 %J 4M 10 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. 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. ith the exception of church sanctuaries, the maximum demand to be provided under Schedule A shall be 200 k'. 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 Energy Delivery Charges : First 300 kh per month Over 300 kh per month $10.00 per month $12.15 per per per kh B. Electricity Supply Service Charges : All kh per per kh 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

58 Exhibit No.- itness : DFK & JlPG Rappahannock Electric Q Schedule : 5A &beaule-a Page 2 of 39 EAM22 0 V. 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. 1. HOLESALE-POER 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 PCA-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~

59 Exhibit No.- itness : DFK & J9P Schedule : 5A Page 3 of %J RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA a- SMALL GENERAL SERVICE SCHEDULE B-1 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. 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 k. TYPE OF SERVICE 60 hertz, single-phase and Fnulti phase where available, at available secondary voltages. IV,MONTHLY RATE A. Distribution Delivery Charges : Access Charges : Single-Phase Service Multi phase SeFV*Ge $28.00 per month $47.60 pef menth Energy Delivery Charges : All kh per kh B. Electricity Supply Service Charges : All per kh 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

60 ExhibitNo.- itness : DFK & JDI~ Rappahannock Electric Cooperative Schedule : 5A Schedule B-1 Page 4 of 39 0 Page 2 IQ 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. VVHOLESALE-POER COST ADJUSTMENT CLAUSE 1 The amount of charges calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's helesale Power Cost Adjustment Clause, Schedule PCA-1. VI 1. 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. 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 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 NeyembeF 1,

61 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA Exhibit No. itness : DAK & J Schedule : 5A Page 5 of 39 0 *'J a SMALL GENERAL SERVICE SCHEDULE B-3 1. 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. APPLICABILITY Applicable to multi-phase Customers, and any single-phase Customer whose actual demand exceeds 25 k 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 k. Ill. TYPE OF SERVICE 60 hertz, multi-phase where available, at available secondary voltages. IV. MONTHLY RATE A. Distribution Delivery Charges : Single-Phase Access Charge (a) $28.00 per month Multi-Phase.Access Charge : Demand Delivery Charge : First 100 k of billing demand delivered Over 100 k of billing demand delivered Energy Delivery Charges : First 100 kh per k delivered Next 100 kh per k delivered Next 200 kh per k delivered Over 400 kh per k $47.50 per $1.50 per $9.00 per per per per per kh B. Electricity Supply Service Charges : Energy Charges : First 100 kh per k Next 100 kh per k Next 200 kh per k Over 400 kh per per per per per kh Schedule B-3 Effective : On All Bills Issued on and After July

62 8gppAbA=ck Electric C,9~chedule Q-3 E!9,M 2 2 Exhibit No itness : DFK.- & JDG,') Schedule : 5A Page 6 of 39 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 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. HOLESALE-POER COST ADJUSTMENT CLAUSE The amount of charges calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's helesale Power Cost Adjustment Clause, Schedule PCA-1. VI 1. 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. 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. IX. 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-3 Effective : On All Bills Issued on and After July NeyembeF 1,

63 RaPpAbaimock Electric QQ~~,9chedule LEAeuq_1=2 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA LARGE POER SERVICE SCHEDULE LP-1 Exhibit No.- itness : DFK & JDG Schedule : 5A Page 7 of 39 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 Corporation Commission. APPLICABILITY Applicable to all Customers along the lines of the Cooperative contracting for a load of 100 k or more. TYPE OF SERVICE Multi-phase, 60 hertz, at available voltage. IV.MONTHLY RATE A. Distribution Delivery Charges : Access Charge : Demand Delivery Charges : First 100 k of billing demand delivered Next 400 k of billing demand delivered Next 1,500 k of billing demand delivered Over 2,000 k of billing demand delivered Energy Delivery Charges : First 100 kh per k delivered Next 100 kh per k delivered Next 200 kh per k delivered Over 400 kh per k _$ per per per per per 1778 per 1558 gg_p er 1018 per 0818 per kh Voltage Discount (k) : 2 kilovolt (kv) to 15 kv $0.25 per k Over 15 kv $0.50 per k B. Electricity Supply Service (ESS) Charges : Schedule LP-1 Effective : On All Bills Issued on and After July ANeyembeF 1, 2009

64 ppahannock Electric C _&hedule LP-11 Bqg=e_2-,~ Exhibit No. itness : DFK & JI)d Schedule : 5A Page 8 of 39 C. Demand Charge : All k of ESS Billing per k Energy Charges : First 100 kh per k of ESS Billing kh Next 100 kh per kof ESS Billing Next 200 kh per k of ESS Billing 4857 per kh Over 400 kh per k of ESS Billing per kh V,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. $ B. $0.50 times the highest average k of demand measured in any 15-minute interval during the current billing month. C. The minimum specified in any contract currently in force. V1..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 k of demand measured in any 15-minute interval during the current billing month, or ii. iii. 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 100 k. 2. For Customers whose billing demand as determined under VI. A. 1. above exceeds 1,000 k, 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 NeveFnbeF 1,

65 Rappahannock Electric C Schedule Ll?_-1 Eag-e-3-2 Exhibit No. itness: DFK & JDG Schedule : SA Page 9 of 39 4) 0 demands. The equipment shall remain the property of the Cooperative. The alternate monthly billing demand shall be the higher of: i. ii. The highest average k 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 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.) B. The ESS Billing Demand shall be the highest average k 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 1040 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 V11 POER 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 NeYeFnbeF 1,

66 Vill I Ix. Rappabamock Electric Schedule L - Enp_4a HOLESALE POER COST ADJUSTMENT CLAUSE The amount of charge calculated at the above rate is subject to increase or decrease under provisions of the Cooperative's holesale Power Cost Adjustment Clause, Schedule PCA. TERM OF CONTRACT Exhibit No.- itness : DFK & JDG Schedule : SA Page 10 of 39 I-A 40 IN3 0 1`4 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 LP-1 Effective : On All Bills Issued on and After July NeyembeF 1,

67 Exhibit No. itness : DFK & Joe Rappahannock Electric C Schedule : 5A Schedule HD_-1 Page I I of 39 0 Bur- 1.2 RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, VA C2 LARGE POER 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 k 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 A. Distribution Delivery Charges : Access Charge : Demand Delivery Charge : All k of Maximum Billing Demand delivered Energy Delivery Charges : First 100 kh per k delivered per kh Next 100 kh per k delivered per $ per $ 1.10 per $ $ Schedule HD-1 Effective: On All Bills Issued on and After NeyembeF 1, 20MI&I ~2014

68 Rappahannock Electric Cooperative SC,hedule HD--j Enp=22 Exhibit No. itness : DFK & Schedule : 5A 19-Q Paize 12 of 39 per kh per kh Next 200 kh per k delivered Over 400 kh per k $0.043,36 $ V. MONTHLY RATE (CONT.) B. Electricity Supply Service Charges : GP-holesale Billing Demand : 1 The changes for holesale 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 k of Excess Demand will apply each month. Energy Charges : 1. The Customers kh 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 kh usage for the month times the corresponding month1v ODEC Enerav Cost Adiustment adiusted to COMDensate for the apolicable distribution losses VI MINIMUM MONTHLY DELIVERY CHARGE 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

69 Rappabamock Electric QQQPff3lime Schedule HD--1 B_e 32 B. The minimum specified in any contract currently in force. Exhibit No itness : DFK.- & JDG Schedule : 5A Pap,e 13 of 39 H a Sj 40 NJ Vil,DETERMINATION OF BILLING DEMANDS The billing demands for each month shall be : 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. C. GP-holesale Billing Demand - holesale 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 high Old DeFMA.e.n.. Allenthly DeliveFed Demand deteffnined f8f the "VE AFea- PUFGuan eminuen's helesale Fate, Rate SGhedule GD. The GIR Demand rhall be the Gustemer-!s maximum houfiy inteffated demard GGGUFFiRg in the GIR HGUF. 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,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. IX ROER 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. Schedule HID-1 Effective: On All Bills Issued on and After Neyembw 1, 20M _0 1 4

70 Rappahannock Electric C Schedule HD--1 EN:p=42 ExhibitNo itness: DFK.- & JD~ Schedule: 5A 0 Page 14 of w a The amount Gf GhaFge GaIGUIated at the above Fate is rubjegt tg irgfease OF degfease undef PFGVi6iGnS of the GeepeFative's holesale PeweF Cost AEljustmeRt Clause, Sr.hedule "PGA." 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 NevembeF 1, 20MIg!y~2014~

71 Exhibit No.- itness : DFK & J_DG I-A Schedule : 5A Pam 15 of 39 C RAPPAHANNOCK ELECTRIC COOPERATIVE Fredericksburg, Virginia INTERRUPTIBLE SERVICE RIDER SCHEDULE IS-1 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 k 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 Multi-phase, 60 hertz, at available voltage. IV 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 k of InteFFUptible DeFAaR he interruptible demand credit shall not apply unless the Customer's interruptible demand is at least 50 k. V 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