Supplement No. 611 to P.S.C. Md. E-6: Rider 2 Electric Efficiency Charge, Rider 15 Demand Response Service Charge and Rider 26 Peak Time Rebate Charge

Transcription

1 John C. Frain Director Regulatory Strategy & Revenue Policy P.O. Box 1475 Baltimore, Maryland Telephone Fax November 20, 2017 David J. Collins, Executive Secretary Public Service Commission of Maryland William Donald Schaefer Tower 6 Saint Paul Street, 16 th Floor Baltimore, Maryland Re: Supplement No. 611 to P.S.C. Md. E-6: Rider 2 Electric Efficiency Charge, Rider 15 Demand Response Service Charge and Rider 26 Peak Time Rebate Charge Dear Mr. Collins: Baltimore Gas and Electric Company ( BGE or the Company ) hereby files Supplement No. 611 to P.S.C. Md. E-6. This Supplement revises the EmPOWER Maryland Charge line item on customers electric bills by revising the Electric Efficiency Charge, the Demand Response Service Charge and the Peak Time Rebate Charge contained in Rider 2, Rider 15 and Rider 26, respectively, of BGE s Retail Electric Service Tariff effective with January 2018 billings. The table below provides the proposed $/kwh breakdown of the total EmPOWER Maryland Charge for each rate schedule. Schedule R/RL Schedule G/GS Schedule GL Schedule P/T Rider Rider Rider 26 ( ) ( ) ( ) ( ) Total EmPOWER For a typical residential electric customer using 925 kwh per month, the total increase in the EmPOWER Maryland Charge amounts to approximately $0.76 per month, going from the current charge of $5.81 per month to the new charge of $6.56 per month. Based on a monthly bill of 925 kwh, the Rider 2, Rider 15 and Rider 26 monthly charges amount to $4.01, $2.65 and ($0.10) per month respectively. The filing revises the residential Electric Efficiency Charge for Rate Schedules R and RL from $ per kwh to $ per kwh. The filing increases the Demand Response Service Charge, which is only applicable to residential electric customers, from $ per kwh to $ per kwh. The filing decreases the Peak Time Rebate Charge for Rate Schedules R and RL from ($ ) per kwh to ($ ) per kwh. The Electric Efficiency Charge for Rate Schedules G/GS, GL and P/T changes from $ , $ , and $

2 David J. Collins, Executive Secretary November 20, 2017 Page 2 per kwh to $ , $ , and $ per kwh, respectively. The filing also decreases the Peak Time Rebate Charge for Schedules G/GS, GL and P/T from ($ ), ($ ), and ($ ) per kwh to ($ ), ($ ) and ($ ) per kwh, respectively. The increase reflected in the Rider 2 Electric Efficiency Charge for residential customers is primarily the result of increases in actual and forecasted program expenditures to deliver the 2% energy savings target being applied over decreasing sales, and includes the 2018 forecasted costs associated with BGE s September 1, 2017 proposed EmPower Maryland program filing currently pending. The increase in the Rider 15 Demand Response Service Charge primarily is a result of lower wholesale revenues. The decrease in the Rider 26 Peak Time Rebate charge reflects the decrease in Peak Time Rebate credits paid to residential customers based on their load reductions during the BGE Smart Energy Rewards Energy Savings Days (called Critical Event Days in the Tariff) in BGE respectfully requests consideration of the revised EmPOWER Maryland Charge at the December 13, 2017 Administrative Meeting. If the Commission issues an order on the proposed EmPOWER Maryland program filing plan that impacts the proposed charges herein, BGE will update this filing to incorporate any necessary edits. Respectfully submitted, Attachments cc: Paula Carmody, Office of People s Counsel John C. Frain

3 Supplement No. 611 (Redline)

4 78 Electric Retail Baltimore Gas and Electric Company 2. Electric Efficiency Charge Rates for service under the Company s rate schedules are subject to a Charge to recover Eligible Costs (hereinafter defined) applicable to that rate schedule incurred by the Company for conservation program design and for specific conservation programs approved for inclusion in the Charge by the Commission. The Charge is calculated for a 12-month period beginning January 1 of each year using the procedures described below. Calculation of Efficiency Charge The Charge for the 12-month period beginning January 1 of each year is determined for each rate schedule by dividing Eligible Costs expected to be allocated to the schedule for the 12-month period by the kilowatt sales expected for that rate schedule over the 12-month period. Subject to prior Commission approval, the Charge may be revised at any time to include additional conservation programs or to otherwise adjust for significant changes in Eligible Costs. Details concerning the calculation of the Charge are filed with and approved by the Commission prior to their use in billing. For Charge calculation purposes, the costs and revenues from Schedules R and RL, Schedules G and GS, and Schedules P and T, are aggregated to form the Residential, Small General Service, and Primary/Transmission Voltage Service classes, respectively. The Charge is combined with Rider 15 Demand Response Service, as appropriate, to comprise the EmPOWER Maryland Charge line item on the Customer s monthly electric bill. The Charges effective with service rendered on or after January 1, are as follows: Rate Schedule Rate ($ per kilowatt-hour) Residential (Schedules R and RL) Small General Service (Schedules G and GS) General Service Large (Schedule GL) Primary/Transmission Voltage Service (Schedules P and T) Eligible Costs Total costs eligible for recovery in a 12-month Charge period are program design costs and the implementation costs for programs approved by the Commission, incurred from the following cost categories: (1) Program Costs. These include program design costs, and implementation costs such as customer education, marketing, rebates and buy-downs, capital, measurement and verification (M&V) and evaluation for approved conservation programs. The regulatory asset is amortized over five years and earns a return at the rate of the Company s most recent authorized electric system rate of return. (2) Imbalances. For each rate schedule, Imbalances are the differences between cumulative costs eligible for recovery and revenues collected through the Charge as of December 31 of each year. The estimated Imbalance includes 9 months of actual and 3 months of estimated data. An Imbalance is debited or credited against the costs eligible for recovery during the 12-months beginning January 1. During its disposition, an Imbalance earns interest at the Company s most recent authorized electric system rate of return. Such rate is adjusted for taxes, when the Imbalance represents an under-collection of costs to the Company. (Continued on Next Page) P. S. C. Md. E-6 (Suppl ) Filed 11/20/201711/21/2016 Effective 01/01/201801/01/2017

5 94B Electric Retail Baltimore Gas and Electric Company Rider 15 Demand Response Service continued B. Cost Recovery Rates for service under the Company s residential rate schedules are subject to a Charge to recover eligible costs for the Demand Response Service program. The Charge is calculated for a 12-month period beginning January 1 of each year using the procedures described below. Calculation of Charge The Charge for the 12-month period beginning January 1 of each year is determined for each rate schedule by dividing Eligible Costs (defined below) expected to be allocated to the schedule for the 12- month period by the kilowatt sales expected for that rate schedule over the 12-month period including a true-up (defined below). Subject to prior Commission approval, the Charge may be revised at any time to adjust for significant changes in Eligible Costs. Details concerning the calculation of the Charge are filed with and approved by the Commission prior to their use in billing. The Charge is combined with Rider 2 Electric Efficiency Charge to comprise the EmPOWER Maryland Charge line item on the Customer s monthly electric bill. The Charge effective January 1, through December 31, is as follows: Rate Schedule Rate ($ per kilowatt-hour) Residential (Schedules R, RL) Eligible Costs Total costs eligible for recovery in a 12-month Charge period are the costs approved by the Commission and incurred from the following cost categories: Program Costs. Eligible Costs include all costs associated with administering the program. They include but are not limited to capital costs (procurement and installation of switches and thermostats and other capital expenditures such as hardware and software); and operating costs including labor, advertising, other operation and maintenance, contractor costs, monitoring and evaluation, customer incentives (enrollment incentives and bill credits), return and taxes. a. Capital costs are amortized on a straight line basis over ten years (thermostats) and fifteen years (switches). b. The regulatory asset is amortized over five years for the air conditioning switch and thermostat pilot costs and for certain operating costs (specifically, certain customer acquisition costs, one-time Enrollment Incentive costs and a portion of the customers monthly credits as required). c. Earnings on the net investment in the Demand Response Service are determined by applying the Company s most recent authorized rate of return, adjusted for taxes, to the average investment balance net of deferred taxes. d. The remaining operating costs (customer's monthly credit, ongoing operating costs, property taxes, etc.) will also be recovered. (Continued on Next Page) P. S. C. Md. -- E-6 (Suppl ) Filed 11/20/1711/21/16 Effective 01/01/1801/01/17

6 Baltimore Gas and Electric Company Electric Retail 107b Rider 26 Peak Time Rebate continued The true-up charge/credit applicable to Schedules R, RL, G, GS, GL, P and T is combined with Rider 2 Electric Efficiency Charge and Rider 15 Demand Response Service to comprise the EmPOWER Maryland Charge line item on the Customer s monthly electric bill. The Charges effective with January billings are as follows: Rate Schedule Rate ($ per kilowatt-hour) Residential (Schedules R and RL) ( )( ) General Service Small (Schedules G and GS) ( )( ) General Service Large (Schedules GL) ( )( ) Primary/Trans. Voltage (Schedules P and T) ( )( ) 27. Smart Meter Opt-Out Residential and Small Commercial Customers served under Schedules R and G respectively, who elect to opt-out of receiving a smart meter and choose to retain a non-smart meter, are subject to the Smart Meter Opt-Out fees listed in this Rider. A Customer who is nonresponsive to BGE s attempts to install a smart meter, as detailed in Order No , shall also be subject to this Rider. A Customer receiving service under Schedules RL or GS, who is subject to this Rider, shall be moved to a non-time-of-use schedule, Schedule R and G, respectively, and shall receive a non-time-of-use ERT (encoder receiver transmitter) or AMR (automatic meter reading) meter for no additional costs beyond the Opt-Out fees specified below. Smart Meter Opt-Out Customers are subject to a one-time, up-front fee upon enrollment, payable in three monthly installments, and a recurring monthly fee after enrollment, regardless of the quantity of meters per premise. The applicable fees for enrolling in Smart Meter Opt-Out will be shown as separate line items on the Customer s bill and are as follows: One-time, up-front Fee: Monthly Fee: $75 (payable in three monthly installments) $5.50 (per month) Opt-Out Customers will receive an initial bill that includes the first installment of the one-time, up-front fee and ongoing monthly fee. An Opt-Out Customer can elect to discontinue the application of this Rider at any time by electing to have a smart meter installed. The charges shall be waived and removed from the Customer s bill where the opt-out charges first appear if the customer agrees, before the end of the fifth subsequent billing cycle, to have a smart meter installed, provided the Customer allows reasonable access for installation of the smart meter. For Customers who elect to have a smart meter installed after the waiver period has expired, the charges shall continue to be billed and shall cease upon the earlier of the installation of a smart meter or within 30 days of receiving customer notification, provided the Customer allows reasonable access for installation of the smart meter. An Opt-Out Customer served under both an electric schedule and a gas schedule will receive only one one-time, up-front fee and monthly fee per premise. A Customer with multiple electric premises shall incur fees for each individual premise that is opted-out of receiving a Smart Meter. P. S. C. Md. E-6 (Suppl ) Filed 11/21/201611/20/2017 Effective 01/01/201701/01/2018

7 Supplement No. 611 (Clean)

8 78 Electric Retail Baltimore Gas and Electric Company 2. Electric Efficiency Charge Rates for service under the Company s rate schedules are subject to a Charge to recover Eligible Costs (hereinafter defined) applicable to that rate schedule incurred by the Company for conservation program design and for specific conservation programs approved for inclusion in the Charge by the Commission. The Charge is calculated for a 12-month period beginning January 1 of each year using the procedures described below. Calculation of Efficiency Charge The Charge for the 12-month period beginning January 1 of each year is determined for each rate schedule by dividing Eligible Costs expected to be allocated to the schedule for the 12-month period by the kilowatt sales expected for that rate schedule over the 12-month period. Subject to prior Commission approval, the Charge may be revised at any time to include additional conservation programs or to otherwise adjust for significant changes in Eligible Costs. Details concerning the calculation of the Charge are filed with and approved by the Commission prior to their use in billing. For Charge calculation purposes, the costs and revenues from Schedules R and RL, Schedules G and GS, and Schedules P and T, are aggregated to form the Residential, Small General Service, and Primary/Transmission Voltage Service classes, respectively. The Charge is combined with Rider 15 Demand Response Service, as appropriate, to comprise the EmPOWER Maryland Charge line item on the Customer s monthly electric bill. The Charges effective with service rendered on or after January 1, 2018 are as follows: Rate Schedule Rate ($ per kilowatt-hour) Residential (Schedules R and RL) Small General Service (Schedules G and GS) General Service Large (Schedule GL) Primary/Transmission Voltage Service (Schedules P and T) Eligible Costs Total costs eligible for recovery in a 12-month Charge period are program design costs and the implementation costs for programs approved by the Commission, incurred from the following cost categories: (1) Program Costs. These include program design costs, and implementation costs such as customer education, marketing, rebates and buy-downs, capital, measurement and verification (M&V) and evaluation for approved conservation programs. The regulatory asset is amortized over five years and earns a return at the rate of the Company s most recent authorized electric system rate of return. (2) Imbalances. For each rate schedule, Imbalances are the differences between cumulative costs eligible for recovery and revenues collected through the Charge as of December 31 of each year. The estimated Imbalance includes 9 months of actual and 3 months of estimated data. An Imbalance is debited or credited against the costs eligible for recovery during the 12-months beginning January 1. During its disposition, an Imbalance earns interest at the Company s most recent authorized electric system rate of return. Such rate is adjusted for taxes, when the Imbalance represents an under-collection of costs to the Company. (Continued on Next Page) P. S. C. Md. E-6 (Suppl. 611) Filed 11/20/2017 Effective 01/01/2018

9 94B Electric Retail Baltimore Gas and Electric Company Rider 15 Demand Response Service continued B. Cost Recovery Rates for service under the Company s residential rate schedules are subject to a Charge to recover eligible costs for the Demand Response Service program. The Charge is calculated for a 12-month period beginning January 1 of each year using the procedures described below. Calculation of Charge The Charge for the 12-month period beginning January 1 of each year is determined for each rate schedule by dividing Eligible Costs (defined below) expected to be allocated to the schedule for the 12- month period by the kilowatt sales expected for that rate schedule over the 12-month period including a true-up (defined below). Subject to prior Commission approval, the Charge may be revised at any time to adjust for significant changes in Eligible Costs. Details concerning the calculation of the Charge are filed with and approved by the Commission prior to their use in billing. The Charge is combined with Rider 2 Electric Efficiency Charge to comprise the EmPOWER Maryland Charge line item on the Customer s monthly electric bill. The Charge effective January 1, 2018 through December 31, 2018 is as follows: Rate Schedule Rate ($ per kilowatt-hour) Residential (Schedules R, RL) Eligible Costs Total costs eligible for recovery in a 12-month Charge period are the costs approved by the Commission and incurred from the following cost categories: Program Costs. Eligible Costs include all costs associated with administering the program. They include but are not limited to capital costs (procurement and installation of switches and thermostats and other capital expenditures such as hardware and software); and operating costs including labor, advertising, other operation and maintenance, contractor costs, monitoring and evaluation, customer incentives (enrollment incentives and bill credits), return and taxes. a. Capital costs are amortized on a straight line basis over ten years (thermostats) and fifteen years (switches). b. The regulatory asset is amortized over five years for the air conditioning switch and thermostat pilot costs and for certain operating costs (specifically, certain customer acquisition costs, one-time Enrollment Incentive costs and a portion of the customers monthly credits as required). c. Earnings on the net investment in the Demand Response Service are determined by applying the Company s most recent authorized rate of return, adjusted for taxes, to the average investment balance net of deferred taxes. d. The remaining operating costs (customer's monthly credit, ongoing operating costs, property taxes, etc.) will also be recovered. (Continued on Next Page) P. S. C. Md. -- E-6 (Suppl. 611) Filed 11/20/17 Effective 01/01/18

10 Baltimore Gas and Electric Company Electric Retail 107b Rider 26 Peak Time Rebate continued The true-up charge/credit applicable to Schedules R, RL, G, GS, GL, P and T is combined with Rider 2 Electric Efficiency Charge and Rider 15 Demand Response Service to comprise the EmPOWER Maryland Charge line item on the Customer s monthly electric bill. The Charges effective with January 2018 billings are as follows: Rate Schedule Rate ($ per kilowatt-hour) Residential (Schedules R and RL) ( ) General Service Small (Schedules G and GS) ( ) General Service Large (Schedules GL) ( ) Primary/Trans. Voltage (Schedules P and T) ( ) 27. Smart Meter Opt-Out Residential and Small Commercial Customers served under Schedules R and G respectively, who elect to opt-out of receiving a smart meter and choose to retain a non-smart meter, are subject to the Smart Meter Opt-Out fees listed in this Rider. A Customer who is nonresponsive to BGE s attempts to install a smart meter, as detailed in Order No , shall also be subject to this Rider. A Customer receiving service under Schedules RL or GS, who is subject to this Rider, shall be moved to a non-time-of-use schedule, Schedule R and G, respectively, and shall receive a non-time-of-use ERT (encoder receiver transmitter) or AMR (automatic meter reading) meter for no additional costs beyond the Opt-Out fees specified below. Smart Meter Opt-Out Customers are subject to a one-time, up-front fee upon enrollment, payable in three monthly installments, and a recurring monthly fee after enrollment, regardless of the quantity of meters per premise. The applicable fees for enrolling in Smart Meter Opt-Out will be shown as separate line items on the Customer s bill and are as follows: One-time, up-front Fee: Monthly Fee: $75 (payable in three monthly installments) $5.50 (per month) Opt-Out Customers will receive an initial bill that includes the first installment of the one-time, up-front fee and ongoing monthly fee. An Opt-Out Customer can elect to discontinue the application of this Rider at any time by electing to have a smart meter installed. The charges shall be waived and removed from the Customer s bill where the opt-out charges first appear if the customer agrees, before the end of the fifth subsequent billing cycle, to have a smart meter installed, provided the Customer allows reasonable access for installation of the smart meter. For Customers who elect to have a smart meter installed after the waiver period has expired, the charges shall continue to be billed and shall cease upon the earlier of the installation of a smart meter or within 30 days of receiving customer notification, provided the Customer allows reasonable access for installation of the smart meter. An Opt-Out Customer served under both an electric schedule and a gas schedule will receive only one one-time, up-front fee and monthly fee per premise. A Customer with multiple electric premises shall incur fees for each individual premise that is opted-out of receiving a Smart Meter. P. S. C. Md. E-6 (Suppl. 611) Filed 11/20/2017 Effective 01/01/2018

11 Supplement No. 611 ATTACHMENT Rider 2

12 EXH.1 ATT.1 BALTIMORE GAS AND ELECTRIC COMPANY COMPUTATION OF 2017 ELECTRIC AMORTIZED PROGRAM EXPENDITURES EXPENDITURES TOTAL RATE EXPENDITURES EXPENDITURES EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURES PROGRAM SCHEDULE (2012) (2013) (2014) (2015) (2016) (2017) (1) (2) (3) (4) (5) (6) (7) SOURCE: (1)+(2)+(3)+(4)+(5)+(6) RESIDENTIAL R,RL $ 34,214,655 $ 41,942,090 $ 49,119,641 $ 38,565,661 $ 46,753,068 $ 44,865,615 $ 255,460,728 GENERAL SERVICE SMALL G,GS $ 10,966,706 $ 14,497,062 $ 14,744,964 $ 23,854,420 $ 18,469,200 $ 14,844,488 $ 97,376,840 GENERAL SERVICE LARGE GLS,GLP $ 19,744,205 $ 16,759,631 $ 18,370,418 $ 24,097,506 $ 21,786,934 $ 18,484,527 $ 119,243,221 PRIMARY/TRANS. VOLTAGE P,T $ 9,641,525 $ 15,734,318 $ 10,434,821 $ 10,476,475 $ 11,579,987 $ 10,847,590 $ 68,714,716 TOTAL ALL PROGRAMS $ 74,567,091 $ 88,933,100 $ 92,669,843 $ 96,994,062 $ 98,589,190 $ 89,042,219 $ 540,795,506 AMORTIZED EXPENDITURES 5TH YR AMORT. 4TH YR AMORT. 3RD YR AMORT. 2ND YR AMORT. 1ST YR AMORT. TOTAL AMORTIZED UNAMORTIZED REMAINING FOR 2013 FOR 2014 FOR 2015 FOR 2016 FOR 2017 AMORTIZED COSTS ADJ. BALANCE AMORTIZATION EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURES FOR TAXES (12/31/17) (8) (9) (10) (11) (12) (13) (14) (15) (16) (8) +(9)+(10)+(11)+ (14) / ( ) (7) - (14) (12)+(13) - Prior yr(s) Amort. RESIDENTIAL R,RL $ 3,555,650 $ 8,388,418 $ 9,823,928 $ 7,713,132 $ 9,350,614 $ 4,630,959 $ 43,462,701 $ 44,434,801 $ 111,711,410 GENERAL SERVICE SMALL G,GS $ 1,160,842 $ 2,899,412 $ 2,948,993 $ 4,770,884 $ 3,693,840 $ 1,521,293 $ 16,995,264 $ 17,375,385 $ 43,480,754 GENERAL SERVICE LARGE GLS,GLP $ 2,002,982 $ 3,351,926 $ 3,674,084 $ 4,819,501 $ 4,357,387 $ 1,863,123 $ 20,069,003 $ 20,517,872 $ 50,698,671 PRIMARY/TRANS. VOLTAGE P,T $ 937,697 $ 3,146,864 $ 2,086,964 $ 2,095,295 $ 2,315,997 $ 1,083,205 $ 11,666,023 $ 11,926,948 $ 27,754,977 TOTAL ALL PROGRAMS $ 7,657,171 $ 17,786,620 $ 18,533,969 $ 19,398,812 $ 19,717,838 $ 9,098,580 $ 92,192,990 $ 94,255,006 $ 233,645,812

13 EXH.1 ATT.2 BALTIMORE GAS AND ELECTRIC COMPANY COMPUTATION OF 2017 ELECTRIC PROGRAM EARNINGS BEGINNING ENDING AVG BAL NET RATE BALANCE BALANCE AVERAGE OF DEFERRED PROGRAM SCHEDULE (1/1/17) (12/31/17) BALANCE TAXES RETURN (1) (2) (3) (4) (5) SOURCE: Exh.1-Att.1, Col. 16 [(1)+(2)] / 2 (3) x (4) x RESIDENTIAL R,RL $ 110,308,496 $ 111,711,410 $ 111,009,953 $ 66,203,561 $ 7,368,456 GENERAL SERVICE SMALL G,GS $ 45,631,530 $ 43,480,754 $ 44,556,142 $ 26,572,169 $ 2,957,482 GENERAL SERVICE LARGE GLS,GLP $ 52,283,147 $ 50,698,671 $ 51,490,909 $ 30,707,891 $ 3,417,788 PRIMARY/TRANS. VOLTAGE P,T $ 28,573,409 $ 27,754,977 $ 28,164,193 $ 16,796,421 $ 1,869,442 TOTAL ALL PROGRAMS $ 236,796,583 $ 233,645,812 $ 235,221,197 $ 140,280,042 $ 15,613,168

14 EXH. 1 ATT.3 BALTIMORE GAS AND ELECTRIC COMPANY COMPUTATION OF 2017 ELECTRIC PROGRAM IMBALANCES 2017 AMORTIZED WHOLESALE TOTAL RATE CALENDAR PROGRAM LOST CAPACITY TRUE UP PRIOR YEAR RECOVERABLE GROSS CARRYING NET PROGRAM SCHEDULE REVENUES COSTS REVENUES REVENUES RETURN 2016 IMBALANCE EXPENSES IMBALANCE COSTS IMBALANCE (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) SOURCE: Exh.1-Att.1, Col. 15 Exh.1-Att.2, Col. 5 Prior Year Filing (2) + (3) + (4) + (8) - (1) (9) + (10) Exh.2-Att.3, Col. 5 (5) + (6) + (7) RESIDENTIAL R,RL $ 46,344,790 $ 44,434,801 $ - $ (3,213,635) $ 7,368,456 $ 433,915 $ (835,414) $ 48,188,124 $ 1,843,334 $ 102,582 $ 1,945,916 GENERAL SERVICE SMALL G,GS $ 20,132,947 $ 17,375,385 $ - $ (1,257,883) $ 2,957,482 $ (150,450) $ (310,485) $ 18,614,049 $ (1,518,898) $ (49,288) $ (1,568,186) GENERAL SERVICE LARGE GLS,GLP $ 22,975,162 $ 20,517,872 $ - $ (1,191,180) $ 3,417,788 $ 115,802 $ 160,717 $ 23,020,998 $ 45,836 $ 2,551 $ 48,387 PRIMARY/TRANS. VOLTAGE P,T $ 14,863,480 $ 11,926,948 $ 999,118 $ (585,266) $ 1,869,442 $ (104,137) $ 396,434 $ 14,502,539 $ (360,940) $ (11,713) $ (372,653) TOTAL ALL PROGRAMS $ 104,316,378 $ 94,255,006 $ 999,118 $ (6,247,964) $ 15,613,168 $ 295,130 $ (588,747) $ 104,325,710 $ 9,332 $ 44,132 $ 53,464

15 EXH.2 ATT.1 BALTIMORE GAS AND ELECTRIC COMPANY COMPUTATION OF 2018 ELECTRIC AMORTIZED PROGRAM EXPENDITURES EXPENDITURES TOTAL RATE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURES PROGRAM SCHEDULE (2013) (2014) (2015) (2016) (2017) (2018) (1) (2) (3) (4) (5) (6) (7) SOURCE: Exh.1-Att.1, Col.2 Exh.1-Att.1, Col.3 Exh.1-Att.1, Col.4 Exh.1-Att.1, Col.5 Exh.1-Att.1, Col.6 (1)+(2)+(3)+(4)+(5)+(6) RESIDENTIAL R,RL $ 41,942,090 $ 49,119,641 $ 38,565,661 $ 46,753,068 $ 44,865,615 $ 51,843,533 $ 273,089,607 GENERAL SERVICE SMALL G,GS $ 14,497,062 $ 14,744,964 $ 23,854,420 $ 18,469,200 $ 14,844,488 $ 23,687,492 $ 110,097,626 GENERAL SERVICE LARGE GLS,GLP $ 16,759,631 $ 18,370,418 $ 24,097,506 $ 21,786,934 $ 18,484,527 $ 21,522,686 $ 121,021,702 PRIMARY/TRANS. VOLTAGE P,T $ 15,734,318 $ 10,434,821 $ 10,476,475 $ 11,579,987 $ 10,847,590 $ 12,825,362 $ 71,898,553 TOTAL ALL PROGRAMS $ 88,933,100 $ 92,669,843 $ 96,994,062 $ 98,589,190 $ 89,042,219 $ 109,879,073 $ 576,107,487 AMORTIZED EXPENDITURES 5TH YR AMORT. 4RD YR AMORT. 3ND YR AMORT. 2ND YR AMORT. 1ST YR AMORT. TOTAL AMORTIZED UNAMORTIZED REMAINING FOR 2014 FOR 2015 FOR 2016 FOR 2017 FOR 2018 AMORTIZED COSTS ADJ. BALANCE RATE AMORTIZATION EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURE EXPENDITURES FOR TAXES (12/31/18) PROGRAM SCHEDULE (8) (9) (10) (11) (12) (13) (14) (15) (16) (8)+(9)+(10)+(11)+(12)+(13) (14) / ( ) (7) - (14) - (prior yrs. amort) RESIDENTIAL R,RL $ 4,146,373 $ 9,823,928 $ 7,713,132 $ 9,350,614 $ 8,973,123 $ 5,615,849 $ 45,623,019 $ 46,643,438 $ 117,931,924 GENERAL SERVICE SMALL G,GS $ 1,348,130 $ 2,948,993 $ 4,770,884 $ 3,693,840 $ 2,968,898 $ 2,566,047 $ 18,296,791 $ 18,706,023 $ 48,871,455 GENERAL SERVICE LARGE GLS,GLP $ 1,545,754 $ 3,674,084 $ 4,819,501 $ 4,357,387 $ 3,696,905 $ 2,331,390 $ 20,425,020 $ 20,881,853 $ 51,796,337 PRIMARY/TRANS. VOLTAGE P,T $ 1,447,744 $ 2,086,964 $ 2,095,295 $ 2,315,997 $ 2,169,518 $ 1,389,277 $ 11,504,796 $ 11,762,116 $ 29,075,542 \ TOTAL ALL PROGRAMS $ 8,488,000 $ 18,533,969 $ 19,398,812 $ 19,717,838 $ 17,808,444 $ 11,902,564 $ 95,849,627 $ 97,993,430 $ 247,675,258

16 EXH.2 ATT.2 BALTIMORE GAS AND ELECTRIC COMPANY COMPUTATION OF 2018 ELECTRIC PROGRAM EARNINGS BEGINNING ENDING AVG BAL NET RATE BALANCE BALANCE AVERAGE OF DEFERRED PROGRAM SCHEDULE (1/1/18) (12/31/18) BALANCE TAXES RETURN (1) (2) (3) (4) (5) SOURCE: Exh.1-Att.2, Col. 2 Exh.2-Att.1, Col. 16 [(1)+(2)] / 2 (3) x (4) x RESIDENTIAL R,RL $ 111,711,410 $ 117,931,924 $ 114,821,667 $ 68,476,772 $ 7,621,465 GENERAL SERVICE SMALL G,GS $ 43,480,754 $ 48,871,455 $ 46,176,105 $ 27,538,274 $ 3,065,010 GENERAL SERVICE LARGE GLS,GLP $ 50,698,671 $ 51,796,337 $ 51,247,504 $ 30,562,730 $ 3,401,632 PRIMARY/TRANS. VOLTAGE P,T $ 27,754,977 $ 29,075,542 $ 28,415,259 $ 16,946,150 $ 1,886,107 TOTAL ALL PROGRAMS $ 233,645,812 $ 247,675,258 $ 240,660,535 $ 143,523,927 $ 15,974,213

17 EXH. 2, ATT. 3 BALTIMORE GAS AND ELECTRIC COMPANY 2018 ELECTRIC EFFICIENCY ELIGIBLE COSTS TOTAL RATE LOST CAPACITY RECOVERABLE PROGRAM SCHEDULE AMORTIZATION RETURN REVENUES REVENUES IMBALANCE DOLLARS (1) (2) (3) (4) (5) (6) SOURCE: Exh.2-Att.1, Col.15 Exh.2-Att.2, Col. 5 Exh.1-Att.3, Col. 11 (1) + (2) + (3) + (4) + (5) RESIDENTIAL R,RL $ 46,643,438 $ 7,621,465 $ - $ (3,028,919) $ 1,945,916 $ 53,181,900 GENERAL SERVICE SMALL G,GS $ 18,706,023 $ 3,065,010 $ - $ (1,205,510) $ (1,568,186) $ 18,997,337 GENERAL SERVICE LARGE GLS,GLP $ 20,881,853 $ 3,401,632 $ - $ (1,241,857) $ 48,387 $ 23,090,015 PRIMARY/TRANS. VOLTAGE P,T $ 11,762,116 $ 1,886,107 $ 1,264,808 $ (581,552) $ (372,653) $ 13,958,825 TOTAL ALL PROGRAMS $ 97,993,430 $ 15,974,213 $ 1,264,808 $ (6,057,838) $ 53,464 $ 109,228,077

18 BALTIMORE GAS AND ELECTRIC COMPANY COMPUTATION OF 2018 ELECTRIC EFFICIENCY CHARGE EXH ANNUAL TOTAL BILLING EFFICIENCY RATE RATE RECOVERABLE DETERMINANTS RATE SCHEDULE SCHEDULE COSTS (MWH) ($/KWH) (1) (2) (3) SOURCE: SOURCE: Exh.2-Att.3, Col. 6 (1) / [(2) x 1000] RESIDENTIAL R,RL $ 53,181,900 12,255, GENERAL SERVICE SMALL G,GS $ 18,997,337 2,852, GENERAL SERVICE LARGE GLS,GLP $ 23,090,015 8,041, PRIMARY/TRANS. VOLTAGE P,T $ 13,958,825 5,610,

19 Supplement No. 611 ATTACHMENT Rider 15

20 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider 15 CONTENTS WORKSHEET NAME Per kwh Summary of Revenue Requirement Revenue Requirement Amortized Program Costs Return Operating Costs Company Incentive Support DESCRIPTION COMPUTATION OF PEAKREWARDS REVENUE REQUIREMENT PER KWH SUMMARY OF PEAKREWARDS REVENUE REQUIREMENT COMPUTATION OF PEAKREWARDS REVENUE REQUIREMENT PEAKREWARDS PROGRAM EXPENDITURES COMPUTATION OF PEAKREWARDS RETURN COMPUTATION OF PEAKREWARDS OPERATING COSTS COMPANY INCENTIVE SUPPORT

21 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider COMPUTATION OF PEAKREWARDS REVENUE REQUIREMENT PER KWH" A Total Revenue Requirement $ 35,133,912 B Forecasted MWH Residential Sales 12,255,035 C=A/B PeakRewards Program $'s Per kwh Rate $

22 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider 15 SUMMARY OF PEAKREWARDS REVENUE REQUIREMENT TOTAL OPERATING WHOLESALE COMPANY REVENUE YEAR AMORTIZATION RETURN COSTS REVENUES INCENTIVE TRUE-UP REQUIREMENT ,348,220 5,836,072 27,844,072 (16,748,266) 739,442 4,185,214 32,204, ,886,449 5,510,834 25,580,574 (14,625,331) 391,672 6,486,816 33,231, ,420,639 5,502,502 26,076,521 (10,243,124) 0 3,377,374 35,133,912

23 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider 15 COMPUTATION OF PEAKREWARDS REVENUE REQUIREMENT TOTAL OPERATING WHOLESALE COMPANY REVENUE YEAR AMORTIZATION RETURN COSTS REVENUES TRUE-UP INCENTIVE REQUIREMENT 2016 Switches $ 3,134,440 $ 1,966,565 $ 27,844,072 $ (16,748,266) $ 4,185,214 $ 739,442 $ 21,121,468 Thermostats $ 2,804,129 $ 2,793, ,597,213 IT Infrastructure $ 1,352,456 $ 705, ,057,735 Regulatory Asset $ 3,057,194 $ 371, ,428,338 $ 10,348,220 $ 5,836,072 $ 27,844,072 $ (16,748,266) $ 4,185,214 $ 739,442 $ 32,204,754 TOTAL OPERATING WHOLESALE COMPANY REVENUE YEAR AMORTIZATION RETURN COSTS REVENUES TRUE-UP INCENTIVE REQUIREMENT 2017 Switches $ 2,798,193 $ 1,660,786 $ 25,580,574 $ (14,625,331) $ 6,486,816 $ 391,672 $ 22,292,709 Thermostats $ 3,766,908 $ 2,891, ,658,474 IT Infrastructure $ 1,289,650 $ 649, ,938,834 Regulatory Asset $ 2,031,699 $ 309, ,340,997 $ 9,886,449 $ 5,510,834 $ 25,580,574 $ (14,625,331) $ 6,486,816 $ 391,672 $ 33,231,014 TOTAL OPERATING WHOLESALE COMPANY REVENUE YEAR AMORTIZATION RETURN COSTS REVENUES TRUE-UP INCENTIVE REQUIREMENT 2018 Switches $ 1,678,604 $ 1,654,333 $ 26,076,521 $ (10,243,124) $ 3,377,374 $ - $ 22,543,708 Thermostats $ 5,652,490 $ 2,890, ,542,681 IT Infrastructure $ 1,150,647 $ 641, ,791,650 Regulatory Asset $ 1,938,898 $ 316, ,255,873 $ 10,420,639 $ 5,502,502 $ 26,076,521 $ (10,243,124) $ 3,377,374 $ - $ 35,133,912

24 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider 15 PEAKREWARDS PROGRAM EXPENDITURES PROGRAM CAPITAL EXPENDITURES Switches $ 8,700,774 $ 10,682,511 $ 6,699,880 $ 3,696,683 $ 4,003,109 $ 3,741,165 $ 2,133,762 $ 2,118,862 $ (900,248) $ 455,650 $ 3,899,994 Thermostats 2,199,798 17,690,799 8,586,176 10,592,594 3,294,869 3,196,225 4,385,143 5,177,944 7,051,563 4,765,251 3,898,435 IT Infrastructure 3,970,972 4,325, ,381 1,270,440 1,002,005 1,550,037 (4,749) 1,956, , ,962 1,615,599 Regulatory Asset - Pilot 1,055, Regulatory Asset - Signing Bonus 414,538 6,651,720 (788,598) 4,898, , , , , , , ,050 Regulatory Asset - Marketing 6,011,103 7,108,499 9,348,388 6,547,083 2,237,765 1,670,842 1,870,237 1,493,488 1,045,683 1,548,759 1,550,004 TOTAL CAPITAL EXPENDITURES $ 22,352,211 $ 46,459,291 $ 24,678,226 $ 27,004,942 $ 11,461,689 $ 10,457,108 $ 8,895,505 $ 11,281,862 $ 7,918,038 $ 7,740,725 $ 11,741,082 PROGRAM AMORTIZATION Switches 182, ,875 1,600,209 1,927,287 2,129,226 2,464,305 2,499,906 3,751,923 3,134,440 2,798,193 1,678,604 Thermostats 42,230 1,143,573 2,591,714 3,694,054 4,162,067 4,502,822 4,524,313 2,399,627 2,804,129 3,766,908 5,652,490 IT Infrastructure 22, , , , , , ,480 1,174,328 1,352,456 1,289,650 1,150,647 Regulatory Asset 718,260 3,529,622 4,991,195 7,085,484 8,418,251 8,208,062 6,554,783 4,836,675 3,057,194 2,031,699 1,938,898 TOTAL AMORTIZATION $ 965,344 $ 6,071,007 $ 9,569,954 $ 13,054,499 $ 15,533,542 $ 16,077,132 $ 14,456,482 $ 12,162,553 $ 10,348,220 $ 9,886,449 $ 10,420,639 ENDING UNAMORTIZED BALANCE Switches 8,517,981 18,267,617 23,367,288 25,136,684 27,010,567 28,287,426 27,921,283 26,288,222 22,253,534 19,910,991 22,132,381 Thermostats 2,157,568 18,704,795 24,699,256 31,597,795 30,730,597 29,424,000 29,284,831 32,063,148 36,310,582 37,308,925 35,554,870 IT Infrastructure 3,948,911 7,809,735 8,255,280 9,178,048 9,356,054 10,004,149 9,121,919 9,904,121 8,967,849 8,323,161 8,788,113 Regulatory Asset 6,762,407 16,993,004 20,561,598 24,921,339 19,664,794 13,426,412 9,252,978 6,444,828 4,738,173 4,581,335 4,969,491 ENDING UNAMORTIZED BALANCE $ 21,386,867 $ 61,775,151 $ 76,883,423 $ 90,833,866 $ 86,762,012 $ 81,141,988 $ 75,581,010 $ 74,700,319 $ 72,270,137 $ 70,124,413 $ 71,444,856

25 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider 15 COMPUTATION OF PEAKREWARDS RETURN UNAMORTIZED UNAMORTIZED AVERAGE AVG BAL NET RATE OF YEAR BEGINNING ENDING BALANCES OF DEF. TAX RETURN RETURN (1) (2) (3) (4) (5) (6) [(1)+(2)]/2 (4) x (5) 2016 Switches $ 26,288,222 $ 22,253,534 $ 24,270,878 $ 17,669, % $ 1,966,565 Thermostats 32,063,148 $ 36,310,582 34,186,865 25,095, % 2,793,084 IT Infrastructure 9,904,121 $ 8,967,849 9,435,985 6,336, % 705,279 Regulatory Assets 6,444,828 $ 4,738,173 5,591,500 3,334, % 371,144 $ 74,700,319 $ 72,270,137 $ 73,485,228 $ 52,435,516 $ 5,836, Switches $ 22,253,534 $ 19,910,991 $ 21,082,262 $ 14,921, % $ 1,660,786 Thermostats 36,310,582 $ 37,308,925 36,809,754 $ 25,979, % 2,891,566 IT Infrastructure 8,967,849 $ 8,323,161 8,645,505 $ 5,832, % 649,184 Regulatory Assets 4,738,173 $ 4,581,335 4,659,754 2,778, % 309,298 $ 72,270,137 $ 70,124,413 $ 71,197,275 $ 49,513,345 $ 5,510, Switches $ 19,910,991 $ 22,132,381 $ 21,021,686 $ 14,863, % $ 1,654,333 Thermostats 37,308,925 $ 35,554,870 36,431,898 $ 25,967, % 2,890,191 IT Infrastructure 8,323,161 $ 8,788,113 8,555,637 $ 5,759, % 641,003 Regulatory Assets 4,581,335 $ 4,969,491 4,775,413 2,847, % 316,975 $ 70,124,413 $ 71,444,856 $ 70,784,634 $ 49,438,476 $ 5,502,502

26 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider 15 COMPUTATION OF PEAKREWARDS OPERATING COSTS ANNUAL TOTAL PROPERTY RETAIL Gross Receipts & OPERATING YEAR O&M TAX CONTRA REVENUE PSC Assessment EXPENSES 2016 Program (All Rider 15) $ 3,162,510 $ 1,502,490 $ 23,075,869 $ 103,202 $ 27,844, Program (All Rider 15) $ 2,748,712 $ 1,603,757 $ 20,993,825 $ 234,279 $ 25,580, Program (All Rider 15) $ 3,048,900 $ 1,717,302 $ 21,035,798 $ 274,521 $ 26,076,521

27 BALTIMORE GAS AND ELECTRIC COMPANY PeakRewards sm Program Electric - Rider 15 COMPANY INCENTIVE SUPPORT Calendar Year Incentive Threshold Determination Total Revenue Requirement (Customer Surcharge) $ 10,479,183 $ 12,445,917 $ 11,111,020 $ 11,689,272 $ 14,071,392 $ 25,198,448 $ 32,204,754 33,231,014 35,133,912 Avoided Costs Applicable to Offset Surcharge: Capacity Price Mitigation $ 3,722,954 $ 13,561,833 $ 32,441,713 $ 39,192,304 $ 40,731,734 $ 33,941,024 $ 25,555,885 $ 17,956,541 $ 9,155,120 Energy Price Mitigation note (1) note (1) note (1) note (1) note (1) note (1) note (1) note (2) note (1) Avoided Transmission Infrastructure note (1) note (1) note (1) note (1) note (1) note (1) $ 11,862,175 $ 11,626,484 $ 11,390,793 Avoided Distribution Infrastructure note (1) note (1) note (1) note (1) note (1) note (1) note (1) $ 8,452,458 $ 8,281,032 Non-Participant Net Benefit $ (6,756,229) $ 1,115,916 $ 21,330,693 $ 27,503,032 $ 26,660,342 $ 8,742,576 $ 5,213,305 $ 4,804,469 $ (6,306,967) Pass or Fail Incentive Threshold Fail Pass Pass Pass Pass Pass Pass Pass Fail Note (1): The determination of the energy price mitigation, transmission and distribution avoided costs were not necessary to achieve the non-participant net benefit threshold. Note (2): The determination of the energy price mitigation was not necessary to achieve the non-participant net benefit threshold. Supporting Information Delivery Year (Jun-May) Capacity Price Mitigation RPM VRR Curve RTO RTO MAAC MAAC MAAC MAAC MAAC RTO RTO UCAP Price, $/MWDay - Point A $ UCAP Price, $/MWDay - Point B $ $ $ $ $ UCAP Price, $/MWDay - Point C $ $ $ $ Unforced Capacity Level, MW - Point A 150, ,329.8 Unforced Capacity Level, MW - Point B 155, , , , , , , , ,633.0 Unforced Capacity Level, MW - Point C 134, , , , , , , ,823.0 A-B Slope, UCAP Price/Unforced Capacity Level (0.016) B-C Slope, UCAP Price/Unforced Capacity Level (0.030) (0.057) (0.072) (0.077) (0.086) (0.089) (0.049) (0.028) Delivery Year (Jun-May) BGE UCAP Obligation 8,469 8,557 7,937 7,926 7,911 7, , , ,948.5 Residential Percentage of BGE UCAP Obligation 49% 55% 52% 52% 53.6% 53.6% 53.1% 52.4% 52.4% Residential Portion of BGE UCAP Obligation 4, ,707 4,127 4,121 4,240 4,221 4,020 4,062 4,165 RPM Price Mitigation, $/MWDay/MW (0.016) (0.030) (0.057) (0.072) (0.077) (0.086) (0.089) (0.049) (0.028) 2008 Legacy A/C Devices 233, , , , , , , , ,082 Legacy A/C Capacity per Device, kw ICAP Legacy A/C Capability, MW ICAP Legacy W/H Devices 73,747 73,747 73,747 73,747 73,747 73,747 73,747 73,747 73,747 Legacy W/H Capacity per Device, kw ICAP Legacy Wtr Htr Capability, MW ICAP Legacy Capability, MW ICAP Legacy Capability, MW UCAP Growth in Cleared Resources, MW UCAP Capacity Price Mitigation Value to Residential Customers $ 6,349,899 $ 18,701,726 $ 42,085,653 $ 37,150,736 $ 43,258,513 $ 27,441,511 $ 24,150,396 $ 13,586,111 $ 6,028,580 Calendar Year (Jan-Dec) Calendar Year Capacity Price Mitigation Value to Residential Customers $ 3,722,954 $ 13,561,833 $ 32,441,713 $ 39,192,304 $ 40,731,734 $ 33,941,024 $ 25,555,885 $ 17,956,541 $ 9,155,120 Delivery Year (Jun-May) Capacity Revenue BRA Capacity Price, $/MWDay (UCAP) $ $ $ $ $ $ $ $ $ BRA Cleared DLC ICAP, MW Cleared Commercial DLC ICAP, MW Residential BRA Cleared ICAP, MW Residential BRA Cleared UCAP, MW ILR Capacity Price, $/MWDay (UCAP) $ $ Residential ILR DLC ICAP, MW Residential ILR DLC UCAP, MW Forecast Pool Requirement Demand Resource Factor Residential BRA + ILR Cleared ICAP, MW Residential BRA + ILR Cleared UCAP, MW st IA Purchases, MW UCAP 2nd IA Purchases, MW UCAP rd IA Purchases, MW UCAP st IA Price, $/MWDay 2nd IA Price, $/MWDay $ $ rd IA Price, $/MWDay $ 2.51 IA Purchase Cost $ (325,215) $ (1,404,938) Capacity Revenue $ 26,838,897 $ 21,368,956 $ 30,713,747 $ 40,539, $ 21,914,666 $ 19,372,066 $ 14,492,321 $ 14,602,780 $ 6,508,086 Calendar Year (Jan-Dec) Calendar Year Capacity Revenue $ 24,292,235 $ 23,629,202 $ 27,108,040 $ 36,934,293 $ 30,854, $ 20,384, $ 16,531,628 $ 14,547,473 $ 9,856,850 Calendar Year (Jan-Dec) Energy Revenue Number of System A/C Events Average Duration, Hours Average LMP During Events, $/MWh $ 398 $ 77 $ 51 $ 52 Annual Load Reduction, MWh 11,716 9,455 3,645 7,425 Estimated Energy Revenue $ 574,312 $ 4,725,766 $ 2,329,949 $ 3,150,412 $ 2,285,600 $ 268,048 $ 216,638 $ 77,858 $ 386,274

28 Supplement No. 611 ATTACHMENT Rider 26

29 BALTIMORE GAS AND ELECTRIC COMPANY Smart Energy Rewards Program Electric - Rider COMPUTATION OF SMART ENERGY REWARDS REVENUE REQUIREMENT PER KWH 2018 TOTAL ANNUAL BILLING RATE RATE 2017 CAPACITY PLC REVENUE DETERMINANTS RIDER 26 RATE SCHEDULE SCHEDULE PLCs - MW REQUIREMENT (MWH) ($/KWH) (1) (2) (3) RESIDENTIAL R,RL 3,491 $ (1,356,854) 12,255, GENERAL SERVICE SMALL G,GS 647 $ (251,421) 2,852, GENERAL SERVICE LARGE GLS,GLP 1,581 $ (614,619) 8,041, PRIMARY/TRANS. VOLTAGE P,T 918 $ (356,918) 5,610,

30 BALTIMORE GAS AND ELECTRIC COMPANY Smart Energy Rewards Program Electric - Rider COMPUTATION OF SMART ENERGY REWARDS REVENUE REQUIREMENT TOTAL WHOLESALE OPERATING REVENUE YEAR REVENUES COSTS TRUE-UP REQUIREMENT 2016 $ (12,314,655) $ 10,943,410 $ 1,302,174 $ (69,072) 2017 $ (9,356,918) $ 6,803,351 $ (26,246) $ (2,579,812)

31 BALTIMORE GAS AND ELECTRIC COMPANY Smart Energy Rewards Program Electric - Rider COMPUTATION OF SMART ENERGY REWARDS OPERATING COSTS BILL GROSS PSC OPERATING YEAR CREDITS RECEIPTS TAX ASSESSMENT COSTS 2016 $ 11,063,791 $ (131,436) $ 11,055 $ 10,943, $ 6,962,875 $ (162,496) $ 2,972 $ 6,803,351

32 BALTIMORE GAS AND ELECTRIC COMPANY Smart Energy Rewards Program Electric - Rider COMPUTATION OF SMART ENERGY REWARDS TRUE-UP PRIOR YEAR TOTAL REVENUE RIDER 26 RIDER 26 CARRYING (OVER)/UNDER REQUIREMENT REVENUES IMBALANCE COSTS COLLECTION 2016 $ 5,724,285 $ 4,492,040 $ 1,232,244 $ 69,930 $ 1,302, $ (1,187,055) $ (1,161,635) $ (25,421) $ (825) $ (26,246)