1150 Pepco District of Columbia Application for Rate … P.S.C - - December, 2017 Introduced as:...

December 19, 2017

BEFORE THE PUBLIC SERVICE COMMISSION

OF THE DISTRICT OF COLUMBIA IN THE MATTER OF ) ) THE APPLICATION OF ) POTOMAC ELECTRIC POWER ) FORMAL CASE NO. 1150 COMPANY FOR AUTHORITY TO ) INCREASE EXISTING RETAIL ) RATES AND CHARGES FOR ) ELECTRIC DISTRIBUTION SERVICE ) )

VOLUME IV OF VII DIRECT TESTIMONY AND EXHIBITS OF:

PEPCO (E) ....................................................................................................................... Janocha

J.F. Janocha Direct Testimony DC P.S.C - - December, 2017 Introduced as: PEPCO _______ (E)

PEPCO (E) POTOMAC ELECTRIC POWER COMPANY

BEFORE THE PUBLIC SERVICE COMMISSION OF THE DISTRICT OF COLUMBIA

DIRECT TESTIMONY OF JOSEPH F. JANOCHA FORMAL CASE NO. 1150

Q1. Please state your name, position, and business address. 1

A1. My name is Joseph F. Janocha. I am the Manager of Retail Pricing for Pepco 2

Holdings, LLC (PHI). I am testifying on behalf of Potomac Electric Power Company 3

(Pepco or the Company). 4

Q2. Please state your educational background and professional qualifications. 5

A2. I have a Bachelor of Engineering degree with a concentration in Mechanical 6

Engineering from Stevens Institute of Technology. I am a Registered Professional 7

Engineer in the State of New Jersey and the Commonwealth of Pennsylvania. I 8

began my career with Philadelphia Electric Company (PECO) in 1982 as an engineer 9

in the Mechanical Engineering Division. From 1982 through 1992, I held various 10

positions in PECO’s Mechanical Engineering, Nuclear Quality Assurance, and 11

Nuclear Engineering Divisions. I joined Atlantic City Electric Company (ACE) in 12

1992 as a Senior Engineer in the Joint Generation Department. In 1998, I joined the 13

Regulatory Affairs group as a Coordinator, responsible for the design and 14

administration of electric rates for the ACE subsidiary. In March 2005, I was 15

promoted to Regulatory Affairs Manager for Pepco Holdings, responsible for rate 16

design and administration for Delmarva Power & Light Company (Delmarva Power) 17

and ACE subsidiaries. I assumed my current position in January 2011. In this 18

capacity, I am responsible for the development and administration of electric and gas 19

delivery rates, as well as tariff surcharges, for all of Pepco Holdings utilities. 20

Witness Janocha

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Q3. What is the purpose of your Direct Testimony? 1

A3. The purpose of my Direct Testimony is to: 2

Provide a distribution rate design supporting the Company's proposed increase 3

in distribution revenue in the amount of $66.209 million as set forth in the 4

Direct Testimony of Company Witness Ziminsky. The proposed rate design 5

incorporates the results from the Class Cost of Service Study (CCOSS), as 6

provided in the Direct Testimony of Company Witness Murphy; 7

Provide a summary of the status of the Customer Base Rate Credit (CBRC); 8

Provide a proposed rate design for Residential customers that includes a 9

demand rate component, in response to the Commission’s directive in 10

Paragraph 487 of Order No. 18846 in Formal Case No. 1139 to make more 11

extensive use of Advanced Metering Infrastructure (AMI) data and to improve 12

the rate design for the Residential Class; 13

Provide two-part and three-part rate designs for service to Master Metered 14

Apartment buildings (MMAs), as directed by the Commission in Paragraph 15

511 in Order No. 18846; 16

Provide proposed new rates for service to Light Emitting Diode (LED) Street 17

Lighting, Outdoor Lighting and Traffic Signals, as directed by the 18

Commission in Paragraphs 465, 487, 488, 526, 531 and 539 in Order No. 19

18846; 20

Provide proposed adjustments to the rate design for the commercial rate 21

classes; 22

Witness Janocha

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Provide the results of the weather-normalization study of test year sales and an 1

explanation of the weather-normalization process, excluding Residential Aid 2

Discount (RAD), customers as directed in Order No. 18846 in Paragraph 168; 3

Provide an update to the Appliance Saturation Study/Conditional Demand 4

Analysis, as directed by the Commission in Paragraphs 487 and 536 in Order 5

No. 18846; 6

Provide tariff changes proposed by the Company; and 7

Provide the results of the Distribution Marginal Cost Study. 8

This testimony and the accompanying exhibits were prepared by me or under 9

my direct supervision and control. The sources for my testimony are Company 10

records, public documents, and my personal knowledge and experience. 11

I. Allocation of Distribution Revenue Requirement 12

Q4. Please describe the objectives of the allocation of the proposed revenue 13

requirement among the Company’s rate classes. 14

A4. In Order Nos. 18846, 17424, 16930, and 15710 in Formal Case Nos. 1139, 15

1103 1087 and 1076, respectively, the Commission recognized the need to address 16

disparities in rate class-specific Rates of Return (RORs) as part of an approach to 17

allocate revenue requirements. In addition, the orders recognize the need to address 18

the negative rates of return associated with the Residential rate class. The Company’s 19

approach takes these goals into consideration. 20

The proposed revenue allocation procedure is intended to achieve the 21

following objectives: 22

1. Limit the maximum percentage increase to any rate class to 1.5 times 23

the overall average percentage increase. 24

Witness Janocha

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2. Ensure that the final proposed Unitized Rate of Return (UROR) for a 1

rate class with an existing UROR above 1.0 does not increase nor 2

move to a level below 1.0.1 3

3. Ensure that the final proposed UROR for a rate class with an existing 4

UROR below 1.0 does not decrease nor move to a level above 1.0. 5

Taken together, the objectives above balance the Commission’s goal of 6

moving the revenue recovered from a rate class to a level reflective of cost causation 7

with the concept of gradualism. These objectives also recognize the Commission’s 8

policy that uniformity of rates of return among rate classes is not required.2 9

Q5. Please describe Pepco’s recommended procedure for distributing the proposed 10

rate increase. 11

A5. As a starting point for the development of the revenue allocation, the 12

Company summarized the rate class-specific distribution revenue, net operating 13

income, net rate base, rate of return and UROR results from the CCOSS. The results 14

of this analysis are provided in Table 1 on page 1 of PEPCO (E)-1. 15

The CCOSS results summarized in Table 1 show that the current earned 16

returns vary widely by class. At the low end of the range are Schedules R, SL-E, SL-17

S, TS and SL-LED, which all show negative rates of return. At the high end of the 18

range are the Time Metered General Service – High Voltage (Schedule GT 3B), 19

Telecommunications Network (TN), and the proposed class for LED Traffic Signals, 20

all of which have UROR’s greater than 3.5. 21

1 The UROR is the ratio of the ROR for the rate class to that of the overall ROR. 2 In the Matter of the Application of the Potomac Electric Power Company for Authority to Increase Existing Retail Rates and Charges for Electric Distribution Service, Formal Case No. 1139, Order No. 18846 (Order No 18846) at P 453, n.754 (Jul. 25, 2017).

Witness Janocha

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Next, Pepco used the class UROR results from the CCOSS as a benchmark to 1

determine appropriate class UROR in the final rate design. Based on this analysis, 2

the Company recommends allocating to the Residential rate class a percentage 3

increase equal to 1.5 times the overall percentage increase. This results in an 4

allocation of $18.634 million, or 28%, of the total $66.209 million revenue 5

requirement to the Residential class. 6

Then, Pepco addressed the traffic signal and street lighting classes as well as 7

rate classes GT-3B, TN, and the proposed LED Traffic Signal class. To address the 8

negative rates of return for the TS, SL-E, SL-S classes and the proposed LED street 9

lighting class, the Company recommends allocating to these rate classes a percentage 10

increase equal to 1.5 times the overall percentage increase, the same as for the 11

Residential rate class. Based on URORs exceeding 3.5 for rate classes GT-3B, TN 12

and the proposed LED traffic signal class, the Company is not proposing any increase 13

for these classes. 14

For the MMA class, the Company proposes a revenue increase equal to the 15

overall percentage increase. 16

Finally, the revenue allocation for each remaining commercial class was 17

adjusted by a constant factor until the Company reached the overall revenue increase 18

target. The results of the revenue allocation are shown on page 1 of PEPCO (E)-1 19

and in Table 1. 20

This procedure achieved the desired result of moving all rate class URORs 21

closer to unity, as shown by comparing the results of Tables 1 and 2 on page 1 of 22

PEPCO (E)-1. A summary of that comparison is provided in Table 1: 23

Witness Janocha

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Table 1 1

2

Q6. What does the Company propose regarding the use of the CBRC? 3

A6. In accordance with the Commission directives in Order No. 18846, the CBRC 4

is being used to offset the current customer charge levels for the classes to which it 5

has been applied. No portion of the CBRC is being used to offset the proposed rate 6

increases. Under this approach, the CBRC funding can be expected to continue until 7

August 2019. This is detailed in the table below, which provides the status of the 8

CBRC funding: 9

Initial CBRC Level $ 17,282,000 CBRC Provided through September 2017 $ 685,029 Balance Available $ 16,596,971 Projected Monthly CBRC $ 754,497

Projected CBRC Expiration 8/1/2019

Rate Schedule

Current ROR Proposed ROR

Current UROR

Proposed UROR

UROR Movement

UROR Movement

(%)

UROR Movement Needed to

Acheive Unity

Percentage Movement

to Unity

Distribution Revenue Increase

(millions)

Distribution Revenue

Increase (%)R -5.1% -3.5% -0.9 -0.5 0.5 50.3% 1.9 24.0% 18.6$ 23.6%MMA 7.9% 10.0% 1.4 1.3 -0.1 8.0% -0.4 27.9% 1.9$ 15.8%GS-LV 8.9% 11.2% 1.6 1.4 -0.1 8.9% -0.6 24.0% 6.9$ 13.9%GS-HV 9.3% 11.7% 1.7 1.5 -0.2 9.6% -0.7 24.0% 0.0$ 8.4%GT-LV 13.1% 15.6% 2.3 2.0 -0.3 13.8% -1.3 24.0% 29.7$ 13.8%GT-3B 21.6% 21.6% 3.9 2.8 -1.1 27.5% -2.9 37.2% -$ 0.0%GT-3A 13.1% 15.6% 2.3 2.0 -0.3 13.7% -1.3 24.0% 7.8$ 14.0%METRO 12.3% 14.8% 2.2 1.9 -0.3 13.1% -1.2 24.0% 1.0$ 14.4%SL-E -4.8% -4.1% -0.9 -0.5 0.3 38.0% 1.9 17.6% 0.2$ 23.6%SL -LED -0.8% 0.7% -0.1 0.1 0.2 169.2% 1.1 20.5% 0.0$ 23.6%TS -2.9% -1.8% -0.5 -0.2 0.3 55.7% 1.5 18.8% 0.0$ 23.6%TS - LED 28.5% 28.5% 5.1 3.7 -1.4 27.5% -4.1 34.3% -$ 0.0%SL-S -5.7% -4.4% -1.0 -0.6 0.4 43.8% 2.0 22.1% 0.1$ 23.6%TN 37.2% 37.2% 6.6 4.8 -1.8 27.5% -5.6 32.4% -$ 0.0%Total 5.6% 0.0% 1.0 1.0 66.2$ 15.7%

Witness Janocha

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II. Use of AMI Data 1

Q7. How has the Company expanded the use of AMI data in the development of 2

proposed rate designs? 3

A7. The Company has used AMI data extensively in the development of proposed 4

rate designs for the Residential class and for MMA customers. The increased AMI 5

utilization involves: 6

Use of three years of AMI data to develop Residential and MMA annual hourly 7

load profiles, which are later matched against hourly substation peak information 8

to be used in the development of a time-based demand charge; 9

Use of hourly data to develop demand billing determinants for residential and 10

MMA customers; and 11

Use of three years of customer-specific hourly data to develop frequency 12

distributions of bill impacts of the proposed demand rate structures on the 13

Residential class and MMA accounts. 14

III. Residential Rate Design 15

Q8. What is the Company’s recommended rate design for Residential service 16

(Schedule R)? 17

A8. The Company recommends a Residential rate structure that includes a demand 18

component in the distribution rate. Including a demand rate for the Residential class 19

more closely aligns the rate design with the nature of the underlying distribution 20

service costs and complies with the Commission directive in Order No. 18846 (P. 21

487) to make improved use of AMI data in rate design. Moreover, use of a demand 22

rate replaces the existing blocked volumetric rate structure and provides a more cost-23

Witness Janocha

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based price signal to recover peak-related costs than was achieved with the legacy 1

blocked rates. 2

Q9. Please explain the basis for the recommended demand rate component included 3

in Schedule R (Residential Service). 4

A9. The electric distribution system is designed to be able to provide the level of 5

electric service customers require at all times. To do so, the Company must ensure 6

that there is sufficient capacity to meet the expected peak demands placed on the 7

system. As Company Witness Hall testifies, the local area loads are a major factor in 8

sizing distribution facilities because they reflect the fact that customer-specific peak 9

loads do not occur at the same time. 10

The basic construct of the Company’s demand charge proposal is a demand 11

rate that corresponds to the time period associated with the hours that most peaks 12

occur across the distribution system. When planning the distribution system, the 13

Company evaluates the peak of each individual component: substation, feeders, and 14

transformers. The closer the component is to the customer, the more directly the 15

distribution facilities relate to the site-specific requirements of the customer, and the 16

individual customer’s absolute or non-coincident peak demand (the NCP) becomes 17

more of a factor in allocating costs.3 Thus, to establish the time period that most 18

peaks occur across the distribution system, the Company evaluated SCADA data 19

from the distribution substation transformers. Substation transformer loading is 20

considered to be representative of peak loads across the system. 21

3 NARUC Electric Utility Cost Allocation Manual, p. 97.

Witness Janocha

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Q10. What were the results of the evaluation of peaks on the distribution substation 1

transformers? 2

A10. Based on the analysis of substation load data, the Company determined that 3

the time period of 1 pm to 9 pm. represented the period during which the highest 4

frequency of distribution substation transformer peaking occurs. The results are 5

presented in PEPCO (E)-4. This “peak period” is robust enough to capture a 6

significant portion of the transformer peaks and not so narrow that it could result in 7

simply shifting the same peak demand level to a different time. 8

Q11. How does this time period compare to the load profile of the Residential class? 9

A11. The Company summarized the hourly AMI data for the Residential class for 10

all hours of the year, as well as by summer and winter seasons, to develop a load 11

profile for the Residential class.4 The results of the analysis are presented in PEPCO 12

(E)-4. The load profile shows that the timing of the daily Residential class peak 13

corresponds closely with the substation peak window of 1 p.m. to 9 p.m. 14

Q12. Please describe alternative rate structures evaluated. 15

A12. Four demand measure scenarios were analyzed for comparison purposes. 16

Each of the scenarios involves the use of different demand measures during the peak 17

time period of 1 pm to 9 pm. The scenarios represented a range of billing demand 18

calculations based on demands collected through AMI metering. On one end of the 19

range is a demand measure based on a single maximum customer peak. The other 20

end of the range is an average demand using every hour in the peak period each 21

month. The scenarios were developed and then evaluated using the following 22

criteria: 23

4 Order No. 18846 at P 494 and 500 (AE is P. 494 and RTM is P. 500) required that the Company merge the Residential AE class and the appropriate members of the R-TM class into the Residential class.

Witness Janocha

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revenue neutrality; 1

visibility/cost-based pricing; 2

initial minimal customer impacts; and 3

understandability 4

The scenarios are outlined below: 5

Scenario 1: Average of a customer’s hourly weekday demands during peak 6

hours. This yields over 100 data points (demands) per billing month per 7

customer. The 100 demands would be averaged to create a single billing 8

demand per customer. 9

Scenario 2: Average of the customer’s individual five highest weekday peaks 10

in one month during the established peak hours. This yields five data points 11

(demands) per billing month per customer. The five demands would be 12

averaged to create a single billing demand per customer. 5 13

Scenario 3: Average of a customer’s single daily peak demand measured 14

during the established peak hours. This yields approximately 30 data points 15

(demands) per billing month per customer. The 30 demands would be 16

averaged to create a single billing demand per customer. 17

Scenario 4: Maximum monthly or monthly CP demand yields one data point 18

(demand) per billing month per customer which would become the billing 19

demand per customer. 20

5 This is similar to PJM which uses the five highest demands for transmission pricing.

Witness Janocha

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Q13. Did the Company evaluate the level of costs that should be recovered through 1

the demand charge? 2

A13. Yes. As part of the evaluation of alternative demand rate structures, the 3

Company analyzed the impact of recovering the following level of costs through the 4

demand charge: 5

50% of non-customer-related costs; and 6

10% of non-customer related costs 7

By including these demand cost level sensitivities in the analysis, a total of 8 8

alternative rate designs were evaluated. 9

Q14. What were the results of the evaluation of alternative rate structures? 10

A14. The results of the evaluation of the rate design scenarios against the 11

previously identified criteria are summarized in PEPCO (E)-4. As a result of the 12

evaluation of alternatives, the Company proposes a Residential rate structure based on 13

Scenario 3—the average daily peaks rate demand measure. This demand measure 14

allows for a price signal that can be clearly understood and can be communicated 15

easily. Because it averages daily demands, it allows for smoothing of all demands 16

that, measured alone, might create a single peak that is inordinately high. 17

The period being measured is consistent every day for each month, which 18

enables the customer to respond to the price signal and reduce load on a consistent 19

and easy-to-understand basis. Further, the use of an average reduces the likelihood 20

that a customer will be charged a higher demand rate simply because they have one 21

abnormally high hourly demand in a given month. Both of these factors will help 22

Residential customers adjust to the concept of a demand charge without the new rate 23

component being overly burdensome or complicated. 24

Witness Janocha

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Q15. What level of costs does the Company propose to recover through the initial 1

demand charge? 2

A15. The Company recommends implementing the demand rate on a phased-in 3

basis in order to allow Residential customers to become familiar with and better 4

understand the new rate design. The first step in the implementation of the demand 5

charge should be to recover 10% of the Residential non-customer-related distribution 6

costs through a demand charge. The long-term goal should be to recover 50% of non-7

customer charge distribution costs through a demand charge.6 The implementation of 8

this rate design will provide for just, reasonable, and non-discriminatory rates and 9

will institute a paradigm in the District of Columbia that is flexible and adaptable to 10

the innovations of the future. 11

Q16. How would the remaining non-customer-related revenue be recovered? 12

A16. With the introduction of a demand charge to recover peak-related costs, the 13

Company recommends that the remaining non-customer-related revenue be recovered 14

through a uniform volumetric charge. 15

Q17. Have you evaluated the bill impacts on Residential customers for the alternative 16

scenarios considered? 17

A17. Yes. The Company evaluated the bill impact for all Residential customers 18

using three years of AMI data. Annual bill impacts were calculated for each 19

customer under the existing volumetric rate structure and each of the proposed 20

demand rate scenarios for the period of 2014 through 2016. The Company developed 21

6 Based on the results of the CCOSS supported by Company Witness Murphy, 50% of the non-customer charge distribution costs is approximately equal to the percentage of distribution demand costs associated with primary infrastructure and substations.

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a frequency distribution of annual bill impacts for each year for each scenario. The 1

results are presented in PEPCO (E)-4. 2

In addition PEPCO (E)-3 provides the bill impact of the proposed rates with 3

the proposed rate design delineated in Scenario 3 including a demand charge designed 4

to recover 10% of proposed non-customer-related revenue. Under this proposal, the 5

impact to an average Residential customer using 648 kWhs per month with a billing 6

demand of 1.07 kW, the monthly bill would increase by $7.54 or 9.24%. 7

IV. Master Metered Apartments 8

Q18. Please provide the background behind the three-part rate design for the MMA 9

class that the Company has included in this application. 10

A18. In Paragraphs 488 and 511 of Order No. 18846, the Commission directed the 11

Company to provide two amended rate structures for the MMA rate class in the 12

Company’s next base rate case: a two-part rate and a three-part rate. The Company 13

used three years of AMI data to evaluate the load patterns for all customer accounts in 14

the MMA class, the results of which are presented in PEPCO (E)-5. As directed by 15

the Commission, the Company is providing both a two-part rate and a three-part rate. 16

However, as discussed below, the Company recommends keeping in place the current 17

two-part rate and does not recommend moving to a three-part rate for MMA 18

customers at this time. The rate design proposed in PEPCO (E)-1 provides the 19

existing two-part rate structure. The three-part rate design, showing the mitigation 20

measures discussed below, is provided in PEPCO (E)-5. 21

Page 1 of PEPCO (E)-5 provides the average hourly annual summer and 22

winter loads on a per-dwelling-unit basis. The results show that the peak hourly 23

usage occurs between the hours of 6 pm to 9 pm, which aligns with the peak period of 24

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substation transformers. The profile is also similar to that of the Residential class, 1

supporting that the MMA class is Residential in nature. 2

Q19. Please describe the results of the Company’s evaluation of the alternative three-3

part rate design for the MMA class. 4

A19. Based on the similarity between the load profiles of the Residential class and 5

the MMA class, the Company evaluated the same alternative demand rate structures 6

for the MMA class as recommended for the Residential class. As with the 7

Residential class, the Company developed bill impact analyses using three years of 8

AMI data, including a frequency distribution for each scenario using a revenue 9

neutral rate structure. Due to the large number of MMA accounts served by third-10

party suppliers, the Company performed the bill impact analysis for the MMA class 11

using only the distribution portion of the bill. While the results for the MMA class 12

show that the 30-day-average peak demand scenario (Scenario 3) results in an adverse 13

bill impact to the fewest customers, the bill impacts for the MMA class show a much 14

wider spread. Of particular concern is that over 50% of MMA customers would see 15

distribution increases of 3% or greater. 16

Q20. What is the reason for the bill impact disparity between the Residential and 17

MMA classes, given that both classes involve Residential customers? 18

A20. The three-part rate design for the MMA class is designed with a flat 19

volumetric rate, similar to the Residential rate design. As previously explained with 20

respect to the Residential class, this approach provides a more cost-based structure 21

than the blocked rates, which are a legacy of the bundled rate structure. While this 22

approach has minimal impact on the Residential class, the flat volumetric rate 23

adversely impacts MMA customers with usage less than 640 kWhs per month. The 24

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evaluation of the MMA individual customer usage data over the past three years 1

presented in PEPCO (E)-5 indicates that over 90% of MMA accounts have average 2

usage per dwelling unit of less than 640 kWhs per month. By comparison, 59% of 3

Residential accounts have average usage of 640 kWhs or less. This usage variation is 4

the reason for the adverse impacts to the MMA class. 5

Q21. Is the usage pattern related to the number of dwelling units in an MMA 6

account? 7

A21. No. The Company has evaluated the average usage per dwelling unit versus 8

the number of dwelling units per account. The results presented in PEPCO (E)-5 9

show that there is no correlation between usage per unit and the number of dwelling 10

units in a building. 11

Q22. Did the Company evaluate ways to mitigate the adverse impacts of the three-12

part rate design on MMA customers? 13

A22. Yes, the Company evaluated mitigation measures. By retaining the block 14

structure for MMA customers on a three-part rate, the Company was able to mitigate 15

the adverse effects of the three-part rate design. PEPCO (E)-5 shows the results when 16

the existing rate block relationship is maintained combined with a demand charge 17

designed to recover 10% of demand-related costs with a 30-day-average demand 18

billing determinant.7 19

As another mitigation measure, the Company looked at retaining the rate 20

block structure and increasing the initial block to the point where an inclining block 21

structure is maintained. This results in a wider range of impacts but could be 22

considered as an initial step toward flattening the volumetric rate. While the 23

7 As PEPCO (E)-5 shows, the net revenue differences for this rate design is $66,068.

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Company proposes to use a two-part MMA rate, if the Commission were to adopt a 1

three-part rate design for the MMA class, the Company would recommend using the 2

modified rate block structure, with the higher initial block, in the interest of balancing 3

the introduction of a more cost-based rate with gradualism. 4

Q23. Has the Company complied with Paragraph 511 of Order No. 18846, which 5

directs Pepco “to work cooperatively with AOBA and the SEU to propose an 6

amended MMA rate structure for the next rate case”? 7

A23. Yes, the Company has been in discussions with both AOBA and the SEU on 8

various issues, including MMA rate design. The discussions with AOBA have been 9

fruitful but have not yet produced an agreement. However, the Company continues to 10

engage in discussions work with AOBA. Additionally, AOBA and Pepco 11

participated in a Technical Conference on MMA rate design on November 3, 2017. 12

The SEU informed the Company that it does not have the expertise in MMA rate 13

design to comment substantively. 14

V. Commercial Rate Design 15

Q24. Please explain the recommended rate design for General Service – Non-Demand 16

(Schedule “GS ND”). 17

A24. Schedule GS ND is a two-part rate comprised of a customer charge and 18

seasonally differentiated volumetric rates. As has been approved in previous cases, 19

the Company presents a customer charge for Schedule GS ND that moves one quarter 20

of the way toward a charge that is fully reflective of customer-related costs, as 21

detailed in the CCOSS. In addition, the Company presents an alternative customer 22

charge in which the existing customer charge is increased by 1.5 times the overall 23

class percentage increase. As shown in PEPCO (E)-1, the customer charge that is 24

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based on moving 25% of the way to full cost results in a rate design that provides a 1

more even distribution of the proposed increase between the customer and volumetric 2

charges. The remaining distribution revenue requirement is recovered through an 3

equal percentage increase in the summer and winter volumetric rates. Through this 4

approach, the Company continues to move toward fully cost-based rates, as approved 5

in Order Nos. 16930, 17424 and 18846, while providing gradualism in intra-class bill 6

impacts. 7

Under the proposed rates, the results of PEPCO (E)-3 show that the total bill 8

impact for GS ND customers ranges from 10.7% to 24% based on customer usage 9

levels. 10

An additional factor considered in the customer impact evaluation was the 11

dollar impact associated with the highest percentage impact. For Schedule GS ND, 12

the highest percentage bill impacts of between approximately 22% and 25% involve 13

those customers with the lowest usage levels of between 0 and 50 kWhs per month. 14

However, the dollar impact for these customers is between $6.57 and $7.16 per 15

month, which is approximately equal to the change in the customer charge. Based on 16

the minimal dollar impact of the proposed customer charge change on the population 17

of customers that would see a large percentage increase, the proposed rate design 18

comports with the concept of gradualism and is reasonable. 19

Q25. Please explain the recommended rate design for General Service – Low Voltage 20

(Schedule “GS LV”). 21

A25. Schedule GS LV has a three-part rate structure consisting of a customer 22

charge, a demand charge and a seasonally differentiated volumetric charge. As has 23

been approved in previous cases, the Company presents a customer charge that moves 24

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one half of the way toward a charge that is fully reflective of customer-related costs, 1

as detailed in the CCOSS. In addition, the Company evaluated an alternative 2

customer charge in which the existing customer charge is increased by 1.5 times the 3

overall class percentage increase. As shown in PEPCO (E)-1, the customer charge 4

that is based on moving 50% of the way to full cost results in a rate design that 5

provides a more even distribution of the proposed increase between the customer and 6

volumetric charges. 7

The Company used a similar methodology for the design of the demand 8

charge. The Company evaluated two alternative demand rate designs. The first 9

approach increases the demand charge such that it recovers 50% of the non-customer-10

related revenue requirement. The alternative approach increases the demand charge 11

by 1.5 time the overall class percentage increase. In the interest of gradualism, the 12

Company proposes the alternative demand charge in which the increase is equal to 13

1.5 times the percentage increase of the class. 14

The remaining distribution revenue requirement is recovered through an equal 15

percentage increase in the summer and winter volumetric rates. Through this 16



impacts. 19

Q26. Please explain the recommended rate design for General Service – Primary 20

Service (Schedule “GS 3A”). 21

A26. Schedule GS 3A has a three-part rate structure consisting of a customer 22

charge, a demand charge and a seasonally differentiated volumetric charge. The 23

Company evaluated a customer charge that moves one half of the way toward a 24

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19

charge that is fully reflective of customer-related costs, as has been approved in 1

previous cases. In addition, the Company evaluated two alternative customer charge 2

rate designs. The first involved increasing the existing customer charge by 1.5 times 3

the overall class percentage increase. The second involved a customer charge that is 4

moved to full cost. As shown in PEPCO (E)-1, moving the customer charge to full 5

cost provides a rate design that results in a more even distribution of the proposed 6

increase between the customer and volumetric charges. 7

The Company used a similar methodology for the design of the demand 8

charge. The Company evaluated two alternative demand rate designs. The first 9

approach increases the demand charge such that it recovers 50% of the non-customer-10

related revenue requirement. The alternative approach increases the demand charge 11

by 1.5 times the overall class percentage increase. In the interest of gradualism, the 12

Company proposes the alternative demand charge in which the increase is equal to 13

1.5 times the percentage increase of the class. 14





impacts. 19

Witness Janocha

20

Q27. How has the Company addressed the issue of intra-class differences for 1

customers served under Time Metered General Service – Low Voltage (Schedule 2

“GT LV”) and Time Metered General Service – Primary Service (Schedule “GT 3

3A”)?8 4

A27. The Company’s approach in Formal Case Nos. 1087, 1103 and 1139 to 5

address intra-class differences for customers served under Schedules GT LV and GT 6

3A has been to propose movement of the customer charge toward the full cost 7

dictated by the CCOSS and to increase the demand charge closer to a full-cost basis. 8

The Company is proposing the same approach in this case. 9

As in previous cases, the Company proposes a customer charge for the GT LV 10

and GT 3A classes that reflect the full unit costs dictated by the CCOSS. In the 11

treatment of the demand and volumetric components, consideration needs to be given 12

to customer load factors in order to balance the rate impact within the rate class 13

(intra-class impact) , as discussed below. 14

Q28. What is the importance of the customer’s load factor in the design of 15

distribution rates that include demand and volumetric components? 16

A28. A customer’s load factor is an important consideration in the design of a rate 17

structure that includes both demand and volumetric rate components. The load factor 18

is defined as the ratio of the peak demand to the average demand. For an individual 19

customer, the average demand in a given period is derived by dividing the usage by 20

the hours in the period. For example, the monthly average demand is equal to the 21

8 In Paragraph 98 of Order No. 19130 in Formal Case No. 1139, the Commission directed that an examination of the development of customer, demand and volumetric charges for Schedules GT LV and GT 3A be designated as an issue in the Company’s next rate case.

Witness Janocha

21

usage divided by 720 hours (assuming a 30-day month). A customer with a high load 1

factor has a relatively consistent level of demand for all hours in a month. 2

The consistency in the level of demand determines the impact that a demand 3

charge has on a customer. Demand charges for the GT LV and GT 3A classes are 4

based on the customer’s individual monthly maximum demand. This demand may or 5

may not coincide with periods of distribution system peaks. However, customers 6

with high load factors and a consistent level of demand are likely to experience 7

similar levels of demand during their individual maximum demand as well as during 8

the system peaks. Therefore, to account for customers with lower load factors, a 9

volumetric component has been retained in the rate design. This provides a rate 10

structure that stabilizes the impact of rate changes across all customers in the rate 11

class. 12

Q29. Has the Company evaluated the load factors of the GT LV and GT 3A rate 13

classes? 14

A29. Yes, the Company has analyzed the load factors of each customer in the GT 15

LV and GT 3A classes and has developed a frequency distribution of load factors for 16

each class. The results are provided in PEPCO (E)–6. The results show that 70% of 17

GT LV customers and 40% of GT 3A customers have load factors lower than 50%. 18

These results indicate that most customers would still benefit from the three-part rate 19

structure and that a complete elimination would result in a significant bill impact for a 20

large majority of customers. 21

Based on this approach, the Company’s prior approach to designing the 22

demand and volumetric components continues to be reasonable. As such, the rate 23

design for these classes in this proceeding follows a similar methodology. 24

Witness Janocha

22

Q30. Please explain the proposed rate design for Time Metered General Service – 1

Low Voltage (Schedule “GT LV”). 2

A30. The current rate design for Schedule GT LV is a three-part rate consisting of a 3

customer charge, demand charge and volumetric charge. Based on the analysis of the 4

GT LV customer load factors, the Company evaluated two alternative demand rate 5

designs. The first approach increases the demand charge such that it recovers 50% of 6

the non-customer-related revenue requirement. The alternative approach increases 7

the demand charge by 1.5 times the overall class percentage increase. In the interest 8

of gradualism, the Company proposes the alternative demand charge in which the 9

increase is equal to 1.5 times the percentage increase of the class. 10





impacts. 15


Primary Service (Schedule “GT 3A”). 17

A31. The current rate design for Schedule GT 3A is a three-part rate consisting of a 18

customer charge, demand charge and volumetric charge. Based on the analysis of the 19

GT 3A customer load factors, the Company evaluated two alternative demand rate 20

designs. The first approach increases the demand charge such that it recovers 50% of 21

the non-customer-related revenue requirement. The alternative approach increases 22

the demand charge by 1.5 times the overall class percentage increase. In the interest 23

Witness Janocha

23

of gradualism, the Company proposes the alternative demand charge in which the 1

increase is equal to 1.5 times the percentage increase of the class. 2





impacts. 7


High Voltage (Schedule “GT 3B”). 9

A32. The current rate design for Schedule GT 3B is a two-part rate consisting of a 10

customer charge and a demand charge. The Company proposes to modify the rates 11

for this schedule using the same approach the Company proposed and the 12

Commission approved in Order Nos. 18846 and 17424. The proposed customer 13

charge is designed to reflect fully the customer-related costs, as developed in the 14

CCOSS. The balance of the allocated revenue requirement is recovered through the 15

demand charge. 16

Q33. Please explain the proposed rate design for Rapid Transit Service (Schedule 17

“RT”). 18

A33. The distribution charge for Schedule RT consists of a single, monthly 19

customer charge. The proposed customer charge is designed to recover the entire 20

revenue requirement allocated to the class. 21

Witness Janocha

24

VI. Street Lighting and Traffic Signal Rate Design 1

Q34. Please explain the current rate design for Street Lighting Service (Schedule 2

“SL”) and Traffic Signal Service (Schedule “TS”). 3

A34. Schedules SL and TS apply to street light and traffic signal installations and 4

are intended to recover costs related to the distribution system infrastructure required 5

to provide delivery service to these facilities. The rate design is currently comprised 6

of a customer charge and a per-lamp charge. The current rate design provides distinct 7

per lamp charges for Schedules SL and TS, in order to better reflect the underlying 8

cost. 9

Q35. Please explain the proposed changes to the Company’s tariff rate schedules for 10

street lighting Service (Schedule “SL”) and Traffic Signal Service (Schedule 11

“TS”). 12

A35. In Paragraph 539 of Order No. 18846, the Commission directed the Company 13

to develop new rates for outdoor and street lights and traffic signal installations that 14

use LED lights. In response to that directive, the Company has modified its CCOSS 15

to include two new rate classes OL/SL-LED and TS-LED. The modifications to the 16

CCOSS involve using demand allocations that are specific to the lower energy 17

consumption associated with LED applications. The details of the CCOSS 18

modifications are discussed in the Direct Testimony of Company Witness Murphy. 19

Based on the CCOSS results, the Company recommends two new rate schedules for 20

LED street light and traffic signal installations. 21

Witness Janocha

25

Q36. Please explain the proposed rate design for Outdoor/Street Lighting LED 1

Service and Traffic Signal LED Service. 2

A36. The Company is proposing that the rates for the new LED lighting and traffic 3

signal rate classes be reflected as separate items on the existing Schedules SL and TS, 4

respectively. This approach allows the array of lights and devices included in the 5

existing accounts to be maintained, while providing the full benefit of the new LED 6

cost allocations to be reflected in rates. Currently, the street light accounts include 7

both conventional and LED light offerings. Similarly, the traffic signal accounts 8

include both conventional and LED signals. The new LED rates are based on the 9

results from the updated CCOSS, which separated the LED street lights and traffic 10

signals into separate classes. 11

The rates for the LED Street/Outdoor light and LED Traffic Signal offerings 12

are based on the CCOSS results for those classes. The distribution rates for both of 13

these offerings are designed on a volumetric basis to better reflect the different usage 14

levels of LED installations. For purposes of consistency, the Company also proposes 15

that the distribution rates for Schedule SL and Schedule TS be designed as volumetric 16

rates. In addition to putting the rates for conventional and LED lighting on the same 17

basis, the modification is intended to encourage the transition to more energy efficient 18

LED lights, as customers would see an immediate reduction in their distribution bills. 19

The rates are reflective of the difference in the distribution system-related costs 20

associated with serving LED fixtures, while maintaining the existing customer 21

account composition of lights and signals for billing purposes. 22

Witness Janocha

26

The details of the proposed rate design are provided on page 16 of PEPCO 1

(E)-1. PEPCO (E)-2 provides the updated tariff sheets associated with these new 2

rates for LED lights and traffic signals. 3

Q37. Please explain the proposed rate design for Street Lights Served from Overhead 4

Lines (Schedule “SSL-OH”) and Street Lights Served from Underground Lines 5

(schedule “SSL-UG”). 6

A37. The rate components for Schedules SSL-OH and SSL-UG have been adjusted 7

by the same percentage as the proposed distribution rate increase for the respective 8

class. 9

Q38. Please explain the proposed rate design for Temporary Service (Schedule “T”). 10

A38. Schedule T is a two-part rate comprised of a customer charge and seasonally 11

differentiated volumetric rates. For Schedule T, the customer charge has been 12

modified in the same manner as Schedule GS ND. Specifically, it has been designed 13

so that it moves one quarter of the way toward a charge that is fully reflective of 14

customer-related costs, as detailed in the CCOSS. Historically, the customer charges 15

for Schedules GS ND and T have been set at the same level, and this approach is 16

continued in this rate design. The volumetric rates have been designed to recover the 17

residual revenue increase allocated to Schedule T. 18

Q39. Have you prepared bill comparisons using the recommended rates that result 19

from the rate designs discussed above? 20

A39. Yes. Bill comparisons for all the major classes are attached as PEPCO (E)-3. 21

Witness Janocha

27

VII. Weather-Normalization Study 1

Q40. Has the Company included a weather-normalization study with this filing? 2

A40. Yes, as directed by the Commission in Paragraph 172 of Order No. 17424 in 3

Formal Case No. 1103, the Company has designed volumetric rates using weather-4

normalized billing determinants. The weather-normalization study is attached as 5

PEPCO (E)-7. PEPCO (E)-7 includes an explanation of the process for the weather-6

normalization of sales. The Company continues to use the same weather-7

normalization methodology approved by the Commission in Order Nos. 17424, 8

16930, and 15710. In addition, as directed by the Commission in Order No. 18846, 9

the RAD customers have been excluded from the weather normalization calculation. 10

VIII. Appliance Saturation Study 11

Q41. Has the Company updated its appliance saturation study with this filing? 12

A41. Yes, as directed by the Commission in Paragraph 536 of Order No. 18846, the 13

Company has prepared a new Conditional Demand Analysis (CDA) based on the 14

results of the most recent appliance saturation study. The updated CDA is provided 15

as PEPCO (E)–8. 16

Q42. How has the Company used the updated CDA? 17

A42. The Company plans to incorporate the results of the CDA as part of its sales 18

forecasting efforts. The Company’s proposed rate design replaces the blocked 19

volumetric rates with a three-part rate that is comprised of a customer charge, demand 20

charge and flat volumetric charge. However, the results of the CDA continue to 21

confirm that 400 kWhs remains a reasonable approximation of electric usage for basic 22

needs. 23

Witness Janocha

28

IX. Tariff Changes 1

Q43. Are you sponsoring revised tariff pages that contain the proposed rates? 2

A43. Yes. The proposed tariff pages and the present tariff pages showing additions 3

underlined and deletions struck through are attached as PEPCO (E)-2. The proposed 4

percentage changes are shown on the rate design workpapers in PEPCO (E)-1. In 5

addition, the Company proposes to eliminate three riders that are no longer applicable 6

to customers: the Generation Procurement Credit (Rider “GPC”), the Divestiture 7

Sharing Credit (Rider “DS-R” and Rider “DS-NR”), and Rider “PCDC” 8

(POWERCENTS DC Project). 9

X. Distribution Marginal Cost Study 10

Q44. Why is the Company including a Distribution Marginal Cost Study with this 11

filing? 12

A44. The Distribution Marginal Cost Study attached as PEPCO (E)-9 is included in 13

this filing to comply with various Commission directives in Formal Case No. 939 and 14

earlier rate proceedings. Because this is a distribution-only rate request, the Company 15

has not produced generation or transmission marginal cost studies. 16

In past proceedings, the Marginal Cost Study was used to design rates that 17

primarily recovered generation-related costs. Those marginal cost-based rates were 18

intended to reflect the prices that would obtain in a competitive market. Since that 19

time the Company has sold its generation plants. Distribution services are clearly not 20

competitive. Therefore, the Company has not used the results of the attached 21

Marginal Cost Study in any way, but the Company is providing it to comply with the 22

previous Commission directive, most recently in Order No. 15710 in Formal Case 23

No. 1076. 24

Witness Janocha

29

While the Company has included this study in this filing out of an abundance 1

of caution, the Company requests that the Commission no longer require that the 2

Company file this study with its rate cases since it is no longer relevant. 3

Q45. Does this conclude your Direct Testimony? 4

A45. Yes, it does. 5

J.F. Janocha Direct Exhibit DC P.S.C - - December, 2017 Introduced as: PEPCO _______ (E) – 1

Pepco (E)‐1Page 1 of 20

Pepco - District of Columbia

Development of Proposed Distribution RateRate Class Allocation of Distribution Revenue Requirements

TOTAL District of Columbia

TABLE 1 Allocation of Operating Income Based on Per Books Cost of Service Study Results RETAIL RESIDENTIAL MMA

Cost of Service Study Results PEPCO (F)-1Operating Income 103,863,755$ (35,127,729)$ 4,063,794$ Distribution Rate Base 1,852,058,328$ 686,672,371$ 51,702,515$ ROR 5.61% -5.12% 7.86%Unitized ROR 1.00 -0.91 1.40

TABLE 2 Rate Schedule Specific Revenue Increase Allocation

Revenue Requirement 66,209,000$ Operating Income Deficiency PEPCO (C)-1 39,486,000$ ROR PEPCO (C)-1 7.74%

Proposed Revenue Allocation RESIDENTIAL MMAOperating Income at Fully Equalized (8.00%) 143,349,315$ 53,148,442$ 4,001,775$ Operating Income Increase at UROR 39,485,559$ 88,276,170$ (62,019)$ Movement toward EROR -23.99% 27.85%Target UROR -0.45 1.29Target ROR -3.51% 9.98%Operating Income at Target ROR 143,026,379$ (24,105,476)$ 5,161,175$ ROR 7.72% -3.51% 9.98%Incremental Income 39,162,624$ 11,022,252$ 1,097,381$ Revenue Conversion Factor 1.6906 1.6906 1.6906Revenue Requirement 66,209,000$ 18,634,408$ 1,855,251$ Final Unitized ROR 1.00 -0.45 1.29

Commercial UROR Movement (applied to GS-LV, GS-HV, GT-LV, GT-3A, METRO) 24.03%


Cost of Service ClassificationRate Schedule Total RESIDENTIAL MMA

Annualized Current Distribution Revenue 420,647,830$ 78,927,067$ 11,753,776$ Revenue Change ($) 66,209,000$ 18,634,408$ 1,855,251$ Proposed Revenue 486,856,830$ 97,561,475$ 13,609,027$

Revenue Change based on Annualized Current Revenue (%) 15.74% 23.61% 15.78%Service Classification Rate Change as a Percentage of Overall Distribution Change 1.50 1.00




TABLE 1 Allocation of Operating Income Based on Per Books Cost of Service Study Results

Cost of Service Study Results PEPCO (F)-1Operating IncomeDistribution Rate BaseRORUnitized ROR


Revenue RequirementOperating Income Deficiency PEPCO (C)-1ROR PEPCO (C)-1

Proposed Revenue AllocationOperating Income at Fully Equalized (8.00%)Operating Income Increase at URORMovement toward ERORTarget URORTarget ROROperating Income at Target RORRORIncremental IncomeRevenue Conversion FactorRevenue RequirementFinal Unitized ROR

Commercial UROR Movement (applied to GS-LV, GS-HV, GT-LV, GT-3A, METRO)


Cost of Service ClassificationRate Schedule

Annualized Current Distribution Revenue Revenue Change ($)Proposed Revenue

Revenue Change based on Annualized Current Revenue (%)Service Classification Rate Change as a Percentage of Overall Distribution Change

GS-LV GS-HV GT-LV GT-3B

15,754,837$ 14,674$ 92,409,686$ 348,674$ 177,422,578$ 157,065$ 703,047,061$ 1,612,884$

8.88% 9.34% 13.14% 21.62%1.58 1.67 2.34 3.85

GS-LV GS-HV GT-LV GT-3B13,732,508$ 12,157$ 54,415,843$ 124,837$ (2,022,330)$ (2,517)$ (37,993,843)$ (223,837)$

24.03% 24.03% 24.03% 37.19%1.44 1.51 2.02 2.79

11.17% 11.66% 15.64% 21.62%19,818,765$ 18,307$ 109,966,078$ 348,674$

11.17% 11.66% 15.64% 21.62%4,063,927$ 3,633$ 17,556,392$ -$

1.6906 1.6906 1.6906 1.69066,870,545$ 6,142$ 29,681,137$ -$

1.44 1.51 2.02 2.79

GS-LV GS-HV GT-LV GT-3B

49,461,833$ 73,175$ 215,260,055$ 633,622$ 6,870,545$ 6,142$ 29,681,137$ -$

56,332,378$ 79,317$ 244,941,192$ 633,622$

13.89% 8.39% 13.79% 0.00%0.88 0.53 0.88 -














GT-3A METRO SL SL-LED

24,245,217$ 3,047,979$ (637,231)$ (1,932)$ 185,263,289$ 24,760,624$ 13,193,750$ 250,564$

13.09% 12.31% -4.83% -0.77%2.33 2.20 -0.86 -0.14

GT-3A METRO SL SL-LED14,339,379$ 1,916,472$ 1,021,196$ 19,394$ (9,905,839)$ (1,131,506)$ 1,658,427$ 21,326$

24.03% 24.03% -17.58% -20.45%2.01 1.91 -0.53 0.10

15.58% 14.77% -4.13% 0.74%28,866,444$ 3,656,286$ (545,387)$ 1,844$

15.58% 14.77% -4.13% 0.74%4,621,227$ 608,307$ 91,844$ 3,777$

1.6906 1.6906 1.6906 1.69067,812,726$ 1,028,414$ 155,272$ 6,385$

2.01 1.91 -0.53 0.10

GT-3A METRO SL SL-LED

55,813,335$ 7,161,382$ 657,664$ 27,045$ 7,812,726$ 1,028,414$ 155,272$ 6,385$

63,626,060$ 8,189,796$ 812,936$ 33,430$

14.00% 14.36% 23.61% 23.61%0.89 0.91 1.50 1.50














TS TS - LED ST LGHT-S TN

(58,513)$ 41,582$ (316,877)$ 79,595$ 2,044,469$ 145,966$ 5,571,216$ 213,976$

-2.86% 28.49% -5.69% 37.20%-0.51 5.08 -1.01 6.63

TS TS - LED ST LGHT-S TN158,242$ 11,298$ 431,212$ 16,562$ 216,755$ (30,284)$ 748,089$ (63,034)$ -18.82% 34.30% -22.06% 32.43%

-0.23 3.68 -0.57 4.81-1.75% 28.49% -4.41% 37.20%

(35,780)$ 41,582$ (245,727)$ 79,595$ -1.75% 28.49% -4.41% 37.20%22,733$ -$ 71,150$ -$ 1.6906 1.6906 1.6906 1.690638,433$ -$ 120,288$ -$

-0.23 3.68 -0.57 4.81

TS TS - LED ST LGHT-S TN

162,785$ 74,821$ 509,485$ 131,785$ 38,433$ -$ 120,288$ -$

201,218$ 74,821$ 629,772$ 131,785$

23.61% 0.00% 23.61% 0.00%1.50 - 1.50 -

PEPCO (E)‐1Page 5 of 20

Pepco - District of ColumbiaDevelopment of Distribution RatesBilling Data for 12 Months Actual Ending September 2017

Schedule Residential ("R")

Distribution Functional Revenue Requirements Total 97,561,475$ Proposed Customer Charge Recovery 48,172,607$ Proposed Demand/Energy Charge Recovery 49,388,869$ Demand Charge Recovery (10% of Non Customer Revenue) 4,938,887$ Volumetric Charge Recovery 44,449,982$

Billing Weather Determinant Normailzed

Billing Current Present Adjustment Weather Billing Proposed Proposed ProposedDelivery Service Determinants Rate Revenue No. Normalization Determinants Increase Rate Revenue

Residential Monthly Customer Charge 3,192,353 15.09$ 48,172,607$ - 3,192,353 -$ 15.09$ 48,172,607$

Distribution Demand 3,413,893 1 - 3,413,893 N/A 1.44670$ 4,938,887$

Kilowatt-hour charge First 400 kWh `

Summer 457,088,934 0.00759$ 3,469,305$ 2 (1,861,794) 455,227,140 0.02076$ 9,450,515$ Winter 602,920,266 0.00759$ 4,576,165$ 3 41,644,760 644,565,026 0.02076$ 13,381,170$

Over 400 kWhSummer 502,736,065 0.02166$ 10,889,263$ 4 (2,757,179) 499,978,886 0.02076$ 10,379,562$ Winter 504,143,891 0.01512$ 7,622,656$ 5 37,087,546 541,231,437 0.02076$ 11,235,965$

Total kWh Charge 2,066,889,156 26,557,389$ 74,113,333 2,141,002,489 N/A 44,447,212$

Total Distribution 74,729,996$

BSA/Revenue Annualization 4,197,071$

Total Annualized Authorized Revenue 78,927,067$

Proposed Distribution Revenue Increase/Decrease 18,634,408$ 18,631,638$

Proposed Distribution Revenue 97,561,475$ 97,558,705$

Percent Change 23.61% 23.61%


Pepco - District of ColumbiaDevelopment of Distribution RatesBilling Data for 12 Months Actual Ending August 2017

Schedule Master Metered Apartments ("MMA")

Distribution Functional Revenue Requirements Total 13,609,027$ Proposed Customer Charge Recovery 9,020,705$ Volumetric Charge Recovery 4,588,322$


Billing Current Present Adjustment Weather Billing Normalized Proposed Proposed ProposedDelivery Service Determinants Rate Revenue No. Normalization Determinants Revenue Increase Rate Revenue

Residential Monthly Customer Charge 658,020 11.84$ 7,790,957$ - 658,020 7,790,957$ 1.87$ 13.71$ 9,021,454$

Distribution Demand -

Kilowatt-hour charge First 400 kWh `

Summer 95,615,510 0.00759$ 725,722$ 6 (659,834) 94,955,675 720,714$ $0.00268 0.01027$ 974,993$ Winter 113,388,672 0.00759$ 860,620$ 7 1,587,396 114,976,069 872,668$ $0.00268 0.01027$ 1,180,560$

Over 400 kWhSummer 61,195,693 0.02166$ 1,325,499$ 8 (312,650) 60,883,044 1,318,727$ $0.00764 0.02930$ 1,783,995$ Winter 31,283,133 0.01512$ 473,001$ 9 434,597 31,717,729 479,572$ $0.00533 0.02045$ 648,773$

Total kWh Charge 301,483,008 3,384,842$ 1,049,509 302,532,517 3,391,681$ 4,588,322$


BSA/Revenue Annualization 577,977$






Pepco - District of ColumbiaDevelopment of Distribution RatesBilling Data for 12 Months Actual Ending August 2017

Schedule Master Metered Apartments ("MMA") -Alternative Rate Design with Demand charge and Blocked Rates

Distribution Functional Revenue Requirements Total 13,609,027$ Proposed Customer Charge Recovery 7,790,957$ Proposed Demand/Energy Charge Recovery 5,818,070$ Demand Charge Recovery (10% of Non Customer Revenue) 10% 581,807$ Volumetric Charge Recovery 5,236,263$ Proposed First Block Increase 1.35(Per Revenue Neutral Rate Design in PEPCO(E)-5)

BillingDeterminant

Billing Current Present Adjustment Weather Billing Normalized Proposed ProposedDelivery Service Determinants Rate Revenue No. Normalization Determinants Revenue Rate Revenue

Residential Monthly Customer Charge Total Customer 658,020 11.84$ 7,790,957$ 658,020 7,790,957$ 11.84$ 7,790,957$

Distribution Demand - -$ -$ 419,324 -$ 1.38749$ 581,807$

Kilowatt-hour charge First 400 kWh

Summer 95,615,510 0.00759$ 725,722$ 6 (659,834) 94,955,675 720,714$ 0.01582$ 1,502,114$ Winter 113,388,672 0.00759$ 860,620$ 7 1,587,396 114,976,069 872,668$ 0.01582$ 1,818,819$

Over 400 kWhSummer 61,195,693 0.02166$ 1,325,499$ 8 (312,650) 60,883,044 1,318,727$ 0.02319$ 1,411,603$ Winter 31,283,133 0.01512$ 473,001$ 9 434,597 31,717,729 479,572$ 0.01588$ 503,727$

Total kWh Charge 301,483,008 3,384,842$ 1,049,509 302,532,517 3,391,681$ 5,236,263$

Total Distribution 11,175,799$ 13,609,027$








Schedule General Service Non Demand ("GS-ND")

Distribution Functional Revenue Requirements Total $16,204,520Proposed Customer Charge Recovery 7,001,294$

Billing Weather NormalizedDeterminant Normailzed Revenue

Billing Current Present Adjustment Weather Billing at Current Proposed Proposed Proposed PercentDelivery Service Determinants Rate Revenue No. Normalization Determinants Rates Increase Rate Revenue Change

Monthly Customer Charge 205,981 27.42$ 5,647,999$ - 205,981 5,647,999$ 6.57$ 33.99$ 7,001,294$ 23.96%

DistributionKilowatt-hour Charge

Summer 98,302,646 0.03125$ 3,071,958$ 10 (96,899) 98,205,747 3,068,930$ 0.01342 0.04467$ 4,387,318$ 42.94%Winter 132,047,792 0.02446$ 3,229,889$ 11 5,676,187 137,723,979 3,368,729$ 0.01051 0.03497$ 4,815,908$ 42.97%Total kWh Charge 230,350,438 6,301,847$ 5,579,288 235,929,726 6,437,658$ 9,203,226$




Proposed Distribution Revenue Increase/Decrease $1,976,375 1,976,375$

Proposed Distribution Revenue $16,204,520 16,204,520$


Customer Charge Rate DesignFull Customer Cost from Cost Study 53.70$ Present Customer Charge 27.42$ Present Increased 25% Toward Full Cost 33.99$ Present Increased at 1.5 times Overall Class Increase 41.13$ Proposed Customer Charge 33.99$ (Minimum of 25% to full cost vs. 1.5 times overall increase)



Schedule Temporary Service ("T")

Distribution Functional Revenue Requirements Total 1,526,088$ Proposed Customer Charge Recovery 114,299$

Billing Weather NormalizedDeterminant Normailzed Revenue

Billing Current Present Adjustment Weather Billing at Current Proposed Proposed Proposed PercentDelivery Service Determinants Rate Revenue No. Normalization Determinants Rates Increase Rate Revenue Change

Monthly Customer Charge 3,450 27.42$ 94,599$ - 3,450 94,599$ 5.71$ 33.13$ 114,299$ 20.82%

DistributionSummer Energy Rate 8,601,534 0.06362$ 547,230$ 12 (8,630) 8,592,904 546,681$ 0.00684$ 0.07046$ 605,490$ 10.75%Winter Energy Rate 14,354,941 0.04961$ 712,149$ 13 319,214 14,674,155 727,985$ 0.00534$ 0.05495$ 806,299$ 10.76%Total kWh Charge 22,956,475 1,259,379$ 310,584 23,267,059 1,274,665$ 1,411,789$


BSA/Revenue Annualization (14,019)$


Proposed Distribution Revenue Increase/Decrease 186,128$ 186,128$



Customer Charge Rate DesignFull Customer Cost from Cost Study 53.70$ Present Customer Charge 27.42$ Present Increased 25% Toward Full Cost 6.57$ Present Increased at 1.5 times Overall Class Increase 5.71$ Proposed Customer Charge 33.13$ (Minimum of 25% to full cost vs. 1.5 times overall increase)



Schedule General Service Low Voltage ("GSD-LV")

Distribution Functional Revenue Requirements Total 38,601,770$

Proposed Customer Charge Recovery 2,719,338.15$

Proposed Demand/Energy Charge Recovery 35,882,431$

Billing Weather Normalized

Determinant Normailzed Revenue

Billing Current Present Adjustment Weather Billing at Current Proposed Proposed Proposed Percent

Delivery Service Determinants Rate Revenue No. Normalization Determinants Rates Increase Rate Revenue Change


Distribution

Kilowatt-hour Charge

Summer 282,841,856 0.03009$ 8,510,711$ 14 (954,155) 281,887,701 8,482,001$ (0.00329)$ 0.02680$ 7,554,178$ -10.93%

Winter 349,487,410 0.02280$ 7,968,313$ 15 6,826,960 356,314,370 8,123,968$ (0.00249)$ 0.02031$ 7,235,309$ -10.92%

Total kWh Charge 632,329,266 16,479,024$ 5,872,805 638,202,071 16,605,969$ 14,789,487$ -21.85%

Demand Charge (Total kW)

Summer 917,178 8.64$ 7,924,418$ - 917,178.0 7,924,418$ 1.80$ 10.44$ 9,575,338$ 20.83%

Winter 1,103,219 8.64$ 9,531,812$ - 1,103,219.0 9,531,812$ 1.80$ 10.44$ 11,517,606$ 20.83%

Total KW Charge 2,020,397 17,456,230$ - 2,020,397.0 17,456,230$ 21,092,945$


BSA/Revenue Annualization (2,194,106)$





Customer Charge Rate Design

Full Customer Cost from Cost Study 53.70$

Present Customer Charge 35.17$

Present Increased 50% Toward Full Cost 44.43$

Present Increased at 1.5 times Overall Class Increase 60.08$

Proposed Customer Charge 44.43$

(Minimum of 50% to full cost vs. 1.5 times overall increase)

Proposed Demand Charge Rate Design

Demand Revenue at Full Recovery 35,882,431$

Unitized over Max KW 17.76$

Average Annual Demand 8.64$

Halfway to Full Demand/Energy Recovery Rate 13.20$

Present Increased at 1.5 times Overall Class Increase 10.44$ Proposed Demand Charge 10.44$

(Minimum of Half of Demand/Energy Recovery and Present times 1.5 Overall Increase)



Schedule General Service Primary Service - General Service ("GSD 3A")

Distribution Functional Revenue Requirements Total 79,317$

Proposed Customer Charge Recovery 7,762$

Proposed Demand/Energy Charge Recovery 71,555$





Monthly Customer Charge 80 89.41$ 7,153$ - 80 7,153$ 7.61$ 97.02$ 7,762$ 8.51%

Distribution


Summer 663,154 0.02015$ 13,363$ 16 (1,982) 661,172 13,323$ 0.00143$ 0.02158$ 14,268$ 7.10%

Winter 905,230 0.01448$ 13,108$ 17 17,840 923,070 13,366$ 0.00103$ 0.01551$ 14,315$ 7.11%

Total kWh Charge 1,568,384 26,471$ 15,858 1,584,242 26,689$ 28,583$


Summer 1,501 10.61$ 15,926$ - 1,501 15,926$ 1.34$ 11.95$ 17,937$ 12.63%

Winter 2,095 10.61$ 22,228$ - 2,095 22,228$ 1.34$ 11.95$ 25,035$ 12.63%

Total KW Charge 3,596 38,154$ - 3,596 38,154$ 42,972$

Total Distribution 71,778$ 79,317$


Total Annualized Authorized Revenue 73,175$

Proposed Distribution Revenue Increase/Decrease 6,142$ 6,142$

Proposed Distribution Revenue 79,317$ 79,317$








(Move to Full cost)


Demand Revenue at Full Recovery 71,555$








Schedule General Service Low Voltage - General Service ("GT-LV")


Proposed Customer Charge Recovery 20,647,759$







Distribution


Summer 2,053,648,248 0.00925$ 18,996,246$ 18 (4,595,436) 2,049,052,812 18,953,739$ $0.003880 0.01313$ 26,895,031$ 41.95%

Winter 2,592,036,154 0.00925$ 23,976,334$ 19 44,767,484 2,636,803,638 24,390,434$ $0.003880 0.01313$ 34,609,609$ 41.95%

Total kWh Charge 4,645,684,402 42,972,580$ 40,172,048 4,685,856,450 43,344,172$ 61,504,640$


Summer 5,095,673 11.47$ 58,447,369$ - 5,095,673 58,447,369$ 2.37$ 13.84$ 70,524,114$ 20.66%

Winter 6,666,523 11.47$ 76,465,019$ - 6,666,523 76,465,019$ 2.37$ 13.84$ 92,264,678$ 20.66%

Total KW Charge 11,762,196 134,912,388$ - 11,762,196 134,912,388$ 162,788,793$




Proposed Distribution Revenue Increase/Decrease 29,681,137$ 29,681,136.73$









(Full Cost from CCOSS)






Present Increased at 1.5 times Overall Class Increase 13.84$ Proposed Customer Charge 13.84$




Schedule General Service - Primary Service ("GT 3A")








Monthly Customer Charge 1,876 187.64$ 352,013$ - 1,876 352,013$ 16.17$ 203.81$ 382,348$ 8.62%

Distribution


Summer 1,076,664,892 0.00428$ 4,608,126$ 20 (4,184,240) 1,072,480,652 4,590,217$ $0.000830 0.00511$ 5,477,544$ 19.39%

Winter 1,338,647,611 0.00427$ 5,716,025$ 21 (2,614,482) 1,336,033,129 5,704,861$ $0.000830 0.00510$ 6,807,658$ 19.44%

Total kWh Charge 2,415,312,503 10,324,151$ (6,798,722) 2,408,513,781 10,295,079$ 12,285,202$


Summer 2,184,804 8.36$ 18,264,961$ - 2,184,804 18,264,961$ 1.76$ 10.12$ 22,110,216$ 21.05%

Winter 2,850,622 8.36$ 23,831,200$ - 2,850,622 23,831,200$ 1.76$ 10.12$ 28,848,295$ 21.05%

Total KW Charge 5,035,426 42,096,161$ - 5,035,426 42,096,161$ 50,958,511$




Proposed Distribution Revenue Increase/Decrease 7,812,726$ 7,812,725.55$



















Schedule General Service - High Voltage ("GT-3B")

Distribution Functional Revenue Requirements Total 633,622$


Proposed Demand/Energy Charge Recovery 630,815$

Weather

Weather Normailzed

Billing Current Present Normalization Billing Proposed Proposed Proposed Percent

Delivery Service Determinants Rate Revenue Adjustment Determinants Increase Rate Revenue Change

Monthly Customer Charge 12 423.38$ 5,081$ - 12 (100.55)$ 322.83$ 3,874$ -23.75%


Summer 141,717 1.40$ 198,404$ - 141,717 0.46$ 1.86$ 263,594$ 32.86%

Winter 197,431 1.50$ 296,147$ - 197,431 0.36$ 1.86$ 367,222$ 24.00%

Total KW Charge 339,148 494,551$ - 339,148 630,815$

Total Distribution 499,632$ 634,689$



Proposed Distribution Revenue Increase/Decrease -$ 1,067$






Present Moved 50% Toward Full Cost 373.11$





Demand Revenue 629,748$

Proposed Demand Rate 1.86$



Schedule- Rapid Transit Service ("RT")

DistributionAnnualized Rate Annualized

Billing Current Present Authorized Annualization Distribution Proposed Proposed Proposed PercentDelivery Service Determinants Rate Revenue Revenue Adjustment Rate Increase Rate Revenue Change

Monthly Customer Charge 1,164 6,208.78$ 7,227,020$ 7,227,020$ -$ 6,208.78$ 883.51$ 7,092.29$ 8,255,426$ 14.23%

Total 7,227,020$ 7,227,020$ 8,255,426$






Schedule-Street Lighting Service Energy ("SL")

BillingDeterminant

Billing Current Present Adjustment Billing Proposed Proposed PercentDeterminants Rate Revenue No. Determinants Rate Revenue Change

Delivery Service Delivery Service

Monthly Customer Charge Monthly Customer Charge SL SL

Metered Accounts 264 17.19$ 4,538$ Metered Accounts 264 22.57$ 5,958$ 31.30%Unmetered Accounts 72 14.70$ 1,058$ Unmetered Accounts 72 19.30$ 1,390$ 31.29%

5,596$ Total 7,348$

No. of Lights Kilowatt-hour ChargeSL 835,356 0.55497$ 463,598$ 22 SL 78,485,688 # 0.01026$ 805,588$ SL-LED 48,732 0.55497$ 27,045$ 23 SL-LED 1,306,679 0.02558$ 33,430$

Total 496,239$

Proposed Distribution Revenue Increase/Decrease 155,272$


Percent Change 31.29%



Schedule-Traffic Signal Service ("TS")

BillingDeterminant

Billing Current Present Adjustment Billing Proposed Proposed PercentDeterminants Rate Revenue No. Determinants Rate Revenue Change

Delivery Service Delivery Service

Monthly Customer Charge 36 8.03$ 289$ Monthly Customer Charge 36 9.37$ 337$ 16.69%

No. of Signals 514,680 0.30291$ 155,902$ 24 Kilowatt-hour Charge - non-LED 9,859,111 0.01971$ 194,287$ LED Signals 247,008 0.30291$ 74,821$ 25 Kilowatt-hour Charge - LED 635,830 0.11767$ 74,821$

Total 231,012$

Proposed Distribution Revenue Increase/Decrease 38,433$


Percent Change 16.64%


POTOMAC ELECTRIC POWER COMPANY

DISTRICT OF COLUMBIA

SERVICING STREET LIGHTS - SCHEDULES "SSL-OH" & SSL-UG"

RATE DESIGN

Billing Data for 12 Months Actual Ending September 2017

ANNUALIZED ANNUALIZED

Billing Determinants REVENUE REVENUE

OVERHEAD FIXED O & M FIXED O & M

INCANDESCENT

Without GLOBE 144 2.478$ 0.039$ 362$ 1.980$ 0.031$ 290$

With GLOBE 12 3.625$ 0.860$ 54$ 2.896$ 0.687$ 43$

TOTAL INCANDESCENT 156 416$ 333$

MERCURY VAPOR

175 WATT 0 7.742$ 0.767$ -$ 6.185$ 0.612$ -$

250 WATT 0 8.846$ 0.777$ -$ 7.067$ 0.621$ -$

TOTAL MERCURY VAPOR 0 -$ -$

METAL HALIDE

400 WATT 12 29.975$ 1.253$ 375$ 23.947$ 1.001$ 299$

TOTAL METAL HALIDE 12 375$ 299$

TOTAL OVERHEAD 168 791$ 632$

UNDERGROUND

INCANDESCENT

With GLOBE 3,948 34.855$ 1.576$ 143,829$ 27.846$ 1.259$ 114,906$

TOTAL INCANDESCENT 3,948 143,829$ 114,906$

MERCURY VAPOR

250 WATT 3,000 35.156$ 1.416$ 109,718$ 28.087$ 1.131$ 87,654$

400 WATT 540 41.227$ 1.759$ 23,212$ 32.937$ 1.405$ 18,544$

TOTAL MERCURY VAPOR 3,540 132,930$ 106,198$

HIGH PRESSURE SODIUM

150 WATT 372 30.828$ 1.155$ 11,898$ 24.629$ 0.923$ 9,505$

TOTAL HIGH PRESURE SODIUM 372 11,898$ 9,505$

METAL HALIDE

100 WATT 2,772 26.563$ 1.039$ 76,514$ 21.221$ 0.830$ 61,127$

175 WATT 13,056 29.975$ 1.253$ 407,716$ 23.947$ 1.001$ 325,727$

400 WATT 468 29.975$ 1.253$ 14,615$ 23.947$ 1.001$ 11,676$

TOTAL METAL HALIDE 16,296 498,845$ 398,530$

TOTAL UNDERGROUND 24,156 787,502$ 629,139$

TOTAL OH & UG 24,324 788,293$ 629,771$

629,772$

PRESENT RATES PROPOSED RATES



Schedule-Telecommunications Network Service ("TN")

Distribution Functional Revenue Requirements Total 131,785$ Proposed Customer Charge Recovery 55,758$

76,027$


Billing Current Present Adjustment Weather Billing Proposed Proposed Proposed PercentDelivery Service Determinants Rate Revenue No. Normalization Determinants Increase Rate Revenue Change

Monthly Customer Charge 6,372 15.31$ 97,555$ - 6,372 (6.56)$ 8.75$ 55,758$ -42.85%

DistributionSummer Energy 1,111,219 0.01427$ 15,857$ 26 (3,386) 1,107,833 0.01410$ 0.02837$ 31,433$ 98.83%

Winter Energy 1,539,729 0.01427$ 21,972$ 27 31,932 1,571,661 0.01410$ 0.02837$ 44,594$ 98.83%

Total kWh Charge 2,650,948 37,829$ 28,545 2,679,493 76,027$

Total Distribution 135,384$ 28,545 131,785$

BSA/Revenue Annualization (3,599)$


Proposed Distribution Revenue Increase/Decrease -$ -$



Customer Charge Rate DesignFull Customer Cost from Cost Study 8.75$ Present Customer Charge 15.31$ Present Moved 100% Toward Full Cost (6.56)$ Proposed Customer Charge 8.75$

Change To Customer Charge from Present 100.00%


BillingDeterminantAdjustmentNo. Description Source File/Tab/Cell

1 Schedule R Demand kW PEPCO (E)‐4 Rate Design

2 Schedule R weather normalization ‐ Summer first 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q24 + [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q44+ [Pepco DC Billing Determinants Final.xlsx]Billi3 Schedule R weather normalization ‐ Winter first 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S24 + [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S44+ [Pepco DC Billing Determinants Final.xlsx]Billin4 Schedule R weather normalization ‐ Summer excess 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q25 + [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q45+ [Pepco DC Billing Determinants Final.xlsx]Billi5 Schedule R weather normalization ‐ Winter excess 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S25 + [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S45 + [Pepco DC Billing Determinants Final.xlsx]Billin

6 Schedule MMA weather normalization ‐ Summer first 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q70 + [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q717 Schedule MMA weather normalization ‐ Winter first 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S70 + [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S718 Schedule MMA weather normalization ‐ Summer excess 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q729 Schedule MMA weather normalization ‐ Winter excess 400 kWh [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S72

10 Schedule GS‐ND Summer weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q8311 Schedule GS‐ND Winter weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S83

12 Schedule T Summer weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q8813 Schedule T Winter weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S88

14 Schedule GSD‐LV Summer weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q9315 Schedule GSD‐LV Winter weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S93

16 Schedule GSD‐3A Summer weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q9917 Schedule GSD‐3A Winter weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S99

18 Schedule GT‐LV Summer weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q10419 Schedule GT‐LV Winter weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S104

20 Schedule GT‐3A Summer weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q10921 Schedule GT‐3A Winter weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S109

22 Include kWhs as billing determinant for SL [Pepco MD UB Revs and kWh 9-2016 to10-2017.xlsx]Summary - street lighting'!$E$30

23 Include kWhs as billing determinant for SL‐LED [Pepco MD UB Revs and kWh 9-2016 to10-2017.xlsx]Summary - street lighting'!$E$29

24 Include kWhs as billing determinant for TS [Pepco MD UB Revs and kWh 9-2016 to10-2017.xlsx]Summary - traffic signal'!$L$29

25 Include kWhs as billing determinant for TS‐LED [Pepco MD UB Revs and kWh 9-2016 to10-2017.xlsx]Summary - traffic signal'!$K$29

26 Schedule TN Summer weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $Q13227 Schedule TN Winter weather normalization [Pepco DC Billing Determinants Final.xlsx]Billing Det WC $S132

CLEAN

PEPCO (E)-2 Page 1 of 88

Electricity--P.S.C. of D.C. No. 1 DC Ninety-Second Revised Page No. R-1

Date of Issue: December 19, 2017 Date Effective: Usage on and after

RATE SCHEDULES

FOR

ELECTRIC SERVICE

IN THE


RATES AND REGULATORY PRACTICES GROUP


Electricity--P.S.C. of D.C. No. 1 DC Ninety-Second Revised Page No. R-2


TABLE OF CONTENTS

RATE SCHEDULES

RESIDENTIAL SERVICE - SCHEDULE "R" ...................................................................... Page R-3 - 3.1 RESIDENTIAL ALL-ELECTRIC SERVICE - SCHEDULE "AE" ......................................... Page R-4 - 4.1 TIME METERED RESIDENTIAL SERVICE - SCHEDULE "R-TM" ................................... Page R-5 - 5.1 TIME METERED RESIDENTIAL SERVICE - EXPERIMENTAL PROGRAM -

SCHEDULE "R-TM-EX" (THIS SCHEDULE HAS BEEN DELETED) ......................... Page R-5.2 -5.3 MASTER METERED APARTMENT – SCHEDULE “MMA” ………………………………... Page R-5.4 – 5.5 GENERAL SERVICE – NON DEMAND - SCHEDULE "GS ND" ...................................... Page R-6 - 6.1

GENERAL SERVICE - LOW VOLTAGE - SCHEDULE "GS LV" ...................................... Page R-6.2 - 6.3 GENERAL SERVICE - PRIMARY SERVICE - SCHEDULE "GS 3A" ............................... Page R-6.4- 6.5 TEMPORARY OR SUPPLEMENTARY SERVICE - SCHEDULE "T" ............................... Page R-7 - 7.1 TIME METERED GENERAL SERVICE - LOW VOLTAGE -

SCHEDULE "GT LV" ................................................................................................... Page R-8 - 8.1

TIME METERED GENERAL SERVICE - PRIMARY SERVICE - SCHEDULE "GT 3A" ................................................................................................... Page R-8.2- 8.3

TIME METERED GENERAL SERVICE - HIGH VOLTAGE - SCHEDULE "GT 3B" ................................................................................................... Page R-8.4- 8.5

RAPID TRANSIT SERVICE - SCHEDULE "RT" ................................................................ Page R-9 - 9.1 STREET LIGHTING SERVICE - SCHEDULE "SL" ........................................................... Page R-10 - 10.1 TRAFFIC SIGNAL SERVICE - SCHEDULE "TS" .............................................................. Page R-11 - 11.1 SERVICING STREET LIGHTS SERVED FROM OVERHEAD LINES -

SCHEDULE "SSL-OH" ................................................................................................ Page R-12 - 12.1

SERVICING STREET LIGHTS SERVED FROM UNDERGROUND LINES - SCHEDULE "SSL-UG" .................................................................................. Page R-13 - 13.1

TELECOMMUNICATIONS NETWORK SERVICE - SCHEDULE "TN" ............................. Page R-14 – 14.1

COGENERATION AND SMALL POWER PRODUCTION INTERCONNECTION SERVICE -

SCHEDULE "CG-SPP" ................................................................................................ Page R-15 - 15.4


Electricity--P.S.C. of D.C. No. 1 DC Sixty-First Revised Page No. 2.2


TABLE OF CONTENTS (CONTINUED)

STANDBY SERVICE - SCHEDULE "S" ............................................................................ Page R-16 - 16.1 COMMUNITY RENEWABLE ENERGY FACILITY - SCHEDULE "CREF"........................ Page R-17 – 17.2 RESERVED FOR FUTURE USE ....................................................................................... Page R-18 - 24 RIDERS MARKET PRICE SERVICE - RIDER "MPS" ..................................................................... Page R-25 (THIS RIDER HAS BEEN DELETED) RELIABLE ENERGY TRUST FUND- RIDER "RETF" ....................................................... Page R-26 (THIS RIDER HAS BEEN DELETED) EXPERIMENTAL RESIDENTIAL ELECTRIC VEHICLE SERVICE - RIDER "R-EV"(THIS RIDER HAS BEEN DELETED) ................................................. Page R-27 EXPERIMENTAL RESIDENTIAL TIME-OF-USE ELECTRIC VEHICLE SERVICE - RIDER "R-TM-EV" (THIS RIDER HAS BEEN DELETED) ....................... Page R-28 RESIDENTIAL AID DISCOUNT - RIDER "RAD" ............................................................... Page R-29 POWER FACTOR - RIDER "PF" ....................................................................................... Page R-30 TELECOMMUNICATION NETWORK CHARGE - RIDER "SL-TN" .................................. Page R-31 DELIVERY TAX - RIDER "DT" ........................................................................................... Page R-32

PUBLIC SPACE OCCUPANCY SURCHARGE - RIDER "PSOS" ..................................... Page R-33 GENERATION PROCUREMENT CREDIT - RIDER "GPC" .............................................. Page R-34 - 34.1 (THIS RIDER HAS BEEN DELETED)

FUEL ADJUSTMENT CHARGE - RIDER "FA" (THIS RIDER HAS BEEN DELETED) ..... Page R-35 - 35.1 ENVIRONMENTAL COST RECOVERY RIDER - RIDER "ECRR" ................................... Page R-36 - 36.3 (THIS RIDER HAS BEEN DELETED) EXCESS FACILITIES - RIDER "EF" .................................................................................. Page R-37

OPTIONAL METER EQUIPMENT RELATED SERVICES - RIDER "OMRS" ................... Page R-38 - 38.1 DIVESTITURE SHARING CREDIT - RESIDENTIAL - RIDER "DS-R" .............................. Page R-39 (THIS RIDER HAS BEEN DELETED) DIVESTITURE SHARING CREDIT- NON-RESIDENTIAL - RIDER "DS-NR” ................... Page R-40 - 40.1 (THIS RIDER HAS BEEN DELETED) STANDARD OFFER SERVICE - RIDER “SOS” ................................................................ Page R-41 - 41.8 ADMINISTRATIVE CREDIT - RIDER “AC” ........................................................................ Page R-42


Electricity--P.S.C. of D.C. No. 1 DC Sixty-First Revised Page No. 2.2



RESERVED DELIVERY CAPACITY SERVICE – RIDER "RDCS"……………………… Page R-43 – 43.1 RIDER “PCDC” – POWERCENTSDC™ PROJECT

(THIS RIDER HAS BEEN DELETED) …………..………………………………. Page R-44 – 44.6 NET ENERGY METERING RIDER – RIDER “NEM”……………………………………… Page R-45 – 45.1 RESIDENTIAL AID DISCOUNT SURCHARGE RIDER – RIDER “RADS” ……..…… Page R-46 SUSTAINABLE ENERGY TRUST FUND – RIDER “SETF”..……………………………. Page R-47 ENERGY ASSISTANCE TRUST FUND – RIDER “EATF” ………………………………. Page R-48 BILL STABILIZATION ADJUSTMENT – RIDER “BSA” ………………………………. Page R-49 RESIDENTIAL DIRECT LOAD CONTROL – RIDER “R-DLC” …………………………. Page R-50 UNDERGROUND PROJECT CHARGE – RIDER “UPC” ……………………………….. Page R-51 COMMUNITY NET METERING – RIDER “CNM” ………………………………………… Page R-52 – 52.1 CUSTOMER BASE RATE CREDIT – RIDER “CBRC”……………………………..…….. Page R-53 UNDERGROUND RIDER……………………………………………………………………. Page R-54


Electricity--P.S.C. of D.C. No. 1 DC - R Eighteenth Revised Page No. R-3


RESIDENTIAL SERVICE

SCHEDULE "R" AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service where the use is primarily for residential purposes and for farm operations where the electricity for both farm and residential purposes is delivered through the same meter. Available only in individual residences and in individually metered dwelling units in multi-family buildings. Not available for residential premises in which five (5) or more rooms are for hire. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE Distribution Service Charge

Summer Winter

Customer Charge – Residential $15.09 per month $ 15.09 per month


First 400 kilowatt-hours $ 0.02076 per kwhr $ 0.02076 per kwhr In excess of 400 kilowatt hours $ 0.02076 per kwhr $ 0.02076 per kwhr

Demand Charge $ 1.44670 per kw $ 1.44670 per kw

Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Service from the Company under the provisions of Rider “SOS” – Standard Offer Service. Billing Credit - A monthly billing credit in the amount of $0.62 will be applied to the bill of each customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.

BILLING MONTHS Summer – Billing months of June through October. Winter – Billing months of November through May.


Electricity--P.S.C. of D.C. No. 1 DC - R Eighteenth Revised Page No. R-3.1


METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. BILLING DEMAND The billing demand shall be the average of the maximum hourly demands recorded for each day of the billing month between the hours of 1p.m. and 9 p.m. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations."

APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Optional Meter Equipment Related Services Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - AE Eighteenth Revised Page No. R-4


RESIDENTIAL ALL-ELECTRIC SERVICE

SCHEDULE "AE" AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service where electricity is the sole source of energy for space heating or the primary source with the application of an add-on heat pump or solar space heating system supplemented by electric space heating servicing the entire conditioned space. Available only in individual residences and in individually metered dwelling units in multi-family buildings. Not available for residential premises in which five (5) or more rooms are for hire. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. This schedule will be eliminated as of June 1, 2018. Customers taking service on this schedule will be moved to Schedule “R”. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE Distribution Service Charge

Summer Winter

Customer Charge – Residential $15.09 per month $15.09 per month Kilowatt-hour Charge First 400 kilowatt-hours $ 0.02076 per kwhr $ 0.02076 per kwhr In excess of 400 kilowatt-hours $ 0.02076 per kwhr $ 0.02076 per kwhr Demand Charge $ 1.44670 per kw $ 1.44670 per kw


BILLING MONTHS

Summer – Billing months of June through October. Winter – Billing months of November through May.


Electricity--P.S.C. of D.C. No. 1 DC - AE Seventeenth Revised Page No. R-4.1



APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Optional Meter Equipment Related Services Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Rider Community Net Metering Rider

Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - R - TM Sixteenth Revised Page No. R-5.1


TIME METERED RESIDENTIAL SERVICE

SCHEDULE "R-TM" AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area to approximately the eight hundred (800) largest residential customers who have participated in the residential time-of-use rates program and who are served under Schedule "R-TM". Any customer presently on Schedule "R-TM" whose energy consumption is less than 2,500 kilowatt-hours for each of the five (5) summer billing months in a calendar year may at the customer's option elect to continue service under this schedule or be served under any other applicable schedule. If the customer elects to stay on Schedule "R-TM", the customer will remain on Schedule "R-TM" for at least twelve (12) billing months. Rate schedule changes will be made annually and become effective with the billing month of June.

Available only for low voltage electric service where the use is primarily for residential purposes and for farm operations where the electricity for both farm and residential purposes is delivered through the same meter.

Available only in individual residences and in individually metered dwelling units in multi-family buildings. Not available for multiple application to master-metered apartment buildings where the use is predominantly residential. Not available for residential premises in which five (5) or more rooms are for hire. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. Not available for customers certified as eligible to be billed under Rider "RAD". This schedule will be eliminated as of June 1, 2018. Customers taking service on this schedule will be moved to the schedule with the appropriate character of service prior to June 1, 2018.

CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE Distribution Service Charge

Summer Winter

Customer Charge $ 15.09 per month $ 15.09 per month Kilowatt-hour Charge First 400 kilowatt-hours $ 0.02076 per kwhr $ 0.02076 per kwhr In excess of 400 kilowatt-hours $ 0.02076 per kwhr $ 0.02076 per kwhr Demand Charge $ 1.44670 per kw $ 1.44670 per kw

Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Services from the Company under the provisions of Rider “SOS” – Standard Offer Service.


Electricity--P.S.C. of D.C. No. 1 DC - R - TM Sixteenth Revised Page No. R-5.1


Billing Credit - A monthly billing credit in the amount of $0.62 will be applied to the bill of each customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.

BILLING MONTHS Summer – Billing months of June through October.

Winter – Billing months of November through May. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. BILLING DEMAND The billing demand shall be the average of the maximum hourly demands recorded for each day of the billing month between the hours of 1p.m. and 9 p.m. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations." APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Delivery Tax Public Space Occupancy Surcharge Optional Meter Equipment Related Services Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - MMA Second Revised Page No. R-5.4


MASTER METERED APARTMENT SERVICE SCHEDULE "MMA"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service for multiple application to master-metered apartment buildings where the use is predominantly residential and not for retail business establishments. Not available for separately metered service billed on Schedule “GS ND” that did not qualify for multiple application of the residential rate as of December 31, 1982. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $13.71 per month $13.71 per month

Kilowatt-hour Charge First 400 kilowatt-hours $ 0.01027 per kwhr $ 0.01027 per kwhr

In excess of 400 kilowatt-hours $ 0.02930 per kwhr $ 0.02045 per kwhr Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Service from the Company under the provisions of Rider “SOS” – Standard Offer Service. Billing Credit - A monthly billing credit in the amount of $0.62 will be applied to the bill of each customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.



Electricity--P.S.C. of D.C. No. 1 DC - MMA Second Revised Page No. R-5.5


METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations."

APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Delivery Tax Public Space Occupancy Surcharge Optional Meter Equipment Related Services Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GS ND Fifteenth Revised Page No. R-6


GENERAL SERVICE – NON DEMAND

SCHEDULE "GS ND"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for “GS LV” customers whose maximum monthly demand is less than 25 kW. Customers whose maximum demand is between 25 kW and 99 kW will be served on Schedule GS LV or GS 3A subject to the provisions stated therein. Customers whose maximum demand is equal to or in excess of one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months will be transferred to Schedule "GT LV", "GT 3A", or "GT 3B" in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June.

Available for low voltage electric service at sixty hertz and for primary service furnished directly from the Company’s electric system at voltages of 4.16 kV, 13.2 kV, or 33 kV, when the customer provides at the customer’s own expense, all necessary transformers, converting apparatus, switches, disconnects, regulators and protective equipment.

Not available for railway propulsion service.

Not available for secondary temporary service or supplementary loads metered separately from lighting and other usage in the same occupancy.

CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, either (i) single phase, three wire, 120/240 volts or 120/208 volts, or (ii) three phase, four wire, 120/208 volts or 265/460 volts for GS Low Voltage Non Demand customers. For GS 3A Non Demand customers, the service under this schedule, normally will be alternating current, sixty hertz, three phase, three wire, at 4.16kV, 13.2kV or 33 kV. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served. MONTHLY RATE Summer Winter GS LOW VOLTAGE NON DEMAND

Distribution Service Charge Customer Charge $ 33.99 per month $ 33.99 per month


All kilowatt-hours $ 0.04467 per kwhr $ 0.03497 per kwhr




Electricity--P.S.C. of D.C. No. 1 DC - GS ND Fifteenth Revised Page No. R-6.1


BILLING MONTHS Summer – Billing months of June through October. Winter – Billing months of November through May. Demand metering equipment will be installed and charges subsequent to the installation of this equipment will be computed under the billing demand provision when the customer's load is of such a magnitude and of such a nature as to indicate any of the following: 1. Monthly energy consumption in excess of 6,000 kilowatt-hours in two (2) consecutive winter

billing months (November through May, inclusive). 2. Monthly energy consumption in excess of 7,500 kilowatt-hours for a single summer billing month

(June through October, inclusive).

3. A monthly demand greater than or equal to twenty-five (25) kilowatts in a single month.

Demand accounts are reviewed annually. The account will be billed under non-demand billing provision when the consumption for each of the previous twelve (12) months is below 6,000 kilowatt-hours and the demand is less than twenty-five (25) kilowatts.

BILLING DEMAND The billing demand shall be the maximum thirty (30) minute demand recorded during the month. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations."

APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GS LV Fourteenth Revised Page No. R-6.2


GENERAL SERVICE - LOW VOLTAGE

SCHEDULE "GS LV"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area, except if the customer's maximum demand is equal to or in excess of one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months, the customer will be transferred to Schedule "GT LV", "GT 3A", or "GT 3B" in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June. Customers with monthly maximum demands less than 25 kW are served on Schedule “GS ND” subject to the provisions stated therein.

Available for low voltage electric service at sixty hertz.



CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, either (i) single phase, three wire, 120/240 volts or 120/208 volts, or (ii) three phase, four wire, 120/208 volts or 265/460 volts.

MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 44.43 per month $ 44.43 per month Kilowatt-hour Charge First 6,000 kilowatt-hours $ 0.02680 per kwhr $ 0.02031 per kwhr Additional kilowatt-hours $ 0.02680 per kwhr $ 0.02031 per kwhr Demand Charge $ 10.44 per kw $ 10.44 per kw



Electricity--P.S.C. of D.C. No. 1 DC - GS LV Fourteenth Revised Page No. R-6.3









APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GS 3A Fifteenth Revised Page No. R-6.4


GENERAL SERVICE - PRIMARY SERVICE

SCHEDULE "GS 3A"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS”, or Distribution Service in the District of Columbia portion of the Company's service area, except if the customer's maximum demand is equal to or in excess of one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months, the customer will be transferred to Schedule "GT LV", "GT 3A", or "GT 3B" in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June. Customers with monthly maximum demands less than 25 kW are served on Schedule “GS ND” subject to the provisions stated therein.

Available for primary service furnished directly from the Company's electric system at voltages of 4.16 kV, 13.2 kV or 33 kV, when the customer provides at the customer's own expense, all necessary transformers, converting apparatus, switches, disconnects, regulators and protective equipment. Not available for railway propulsion service. Not available for secondary temporary service or supplementary loads metered separately from lighting and other usage in the same occupancy. CHARACTER OF SERVICE The service under this schedule, normally will be alternating current, sixty hertz, three phase, three wire, at 4.16kV, 13.2kV or 33kV. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served.

MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 97.02 per month $ 97.02 per month Kilowatt-hour Charge

First 6000 kilowatt-hours $ 0.02158 per kwhr $ 0.01551 per kwhr Additional kilowatt-hours $ 0.02158 per kwhr $ 0.01551 per kwhr





Electricity--P.S.C. of D.C. No. 1 DC - GS 3A Fifteenth Revised Page No. R-6.5


Demand metering equipment will be installed and charges subsequent to the installation of this equipment will be computed under the demand billing provision when the customer's load is of such a magnitude and of such a nature as to indicate any of the following: 1. Monthly energy consumption in excess of 6,000 kilowatt-hours in two (2) consecutive winter

billing months (November through May, inclusive).

2. Monthly energy consumption in excess of 7,500 kilowatt-hours for a single summer billing month (June through October, inclusive).





APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - T Twelfth Revised Page No. R-7


TEMPORARY SERVICE

SCHEDULE "T" AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service for construction or other commercial purposes furnished through service connection facilities of a temporary rather than a permanent nature, or for temporary electric service supplied for a limited time, such as for carnivals, festivals, etc. However, customers receiving Temporary Service on a continuous basis for five (5) years will normally be transferred to the appropriate General Service Low Voltage Schedule “GS LV” or “GS ND” based on the customer’s maximum demand, in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June.

CHARACTER OF SERVICE The service supplied under this schedule will be alternating current, sixty hertz, at any of the approved classes of service.

MONTHLY RATE

Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Services from the Company under the provisions of Rider “SOS” – Standard Offer Service. Billing Credit - A monthly billing credit in the amount of $0.75 will be applied to the bill of each customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.

BILLING MONTHS Summer – Billing months of June through October. Winter – Billing months of November through May. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations".

Summer Winter Distribution Service Charge Customer Charge $ 33.13 per month $ 33.13 per month Kilowatt-hour Charge $ 0.07046 per kwhr $ 0.05495 per kwhr


Electricity--P.S.C. of D.C. No. 1 DC - T Twelfth Revised Page No. R-7.1


APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GT LV Sixteenth Revised Page No. R-8


TIME METERED GENERAL SERVICE - LOW VOLTAGE SCHEDULE "GT LV"

AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service when modified by Rider “SOS” in the District of Columbia portion of the Company's service area to customers whose maximum thirty (30) minute demand equals or exceeds one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months. New customers will be qualified for Schedule "GT LV" based on estimated load and energy consumption using the above criteria. Once a customer's account is established it will remain on Schedule "GT LV" even if the party responsible for the account should change. Removal from Schedule "GT LV" is based solely on the criteria stated in the following paragraph.

Any customer presently on Schedule "GT LV" whose maximum thirty (30) minute demand is less than eighty (80) kilowatts for twelve (12) consecutive billing months, may at the customer's option elect to continue service on this schedule or elect to be served under any other available schedule. If the customer elects to stay on Schedule "GT LV", the customer will remain on Schedule "GT LV" for at least twelve (12) billing months. Rate schedule transfers will be made annually and become effective with the billing month of June. Available for low voltage electric service at sixty hertz. Available for standby service when modified by Schedule "S". Not available for temporary service. Not available for multiple application to master-metered apartment buildings except for those master-metered apartments served under Schedule "GT LV" prior to December 31, 1982 which will continue to be served under Schedule "GT LV". CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, either (i) single phase, three wire, 120/240 volts or 120/208 volts, or (ii) three phase, four wire, 120/208 volts or 265/460 volts. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 518.02 per month $ 518.02 per month

Kilowatt-hour Charge $ 0.01313 per kwhr $ 0.01313 per kwhr Kilowatt Charge Maximum $ 13.84 per kw $ 13.84 per kw



Electricity--P.S.C. of D.C. No. 1 DC - GT LV Sixteenth Revised Page No. R-8.1


Billing Credit - A monthly billing credit in the amount of $0.75 per bill will be applied to the bill of

each customer receiving generation services from an alternative supplier for each month that the alternative supplier renders a bill to the customer on a consolidated basis for services provided both by Pepco and by the alternative supplier.


BILLING DEMANDS Maximum (All Months) - The billing demand shall be the maximum thirty (30) minute demand recorded during the billing month.

METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly.

GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Excess Facilities Net Energy Metering Rider Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GT 3A Sixteenth Revised Page No. R-8.2


TIME METERED GENERAL SERVICE - PRIMARY SERVICE

SCHEDULE "GT 3A"

AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area to customers whose maximum thirty (30) minute demand equals or exceeds one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months. New customers will be qualified for Schedule "GT 3A" based on estimated load and energy consumption using the above criteria. Once a customer's account is established it will remain on Schedule "GT 3A" even if the party responsible for the account should change. Removal from Schedule "GT 3A" is based solely on the criteria stated in the following paragraph. Any customer presently on Schedule "GT 3A" whose maximum thirty (30) minute demand is less than eighty (80) kilowatts for twelve (12) consecutive billing months, may at the customer's option elect to continue service on this schedule or elect to be served under any other available schedule. If the customer elects to stay on Schedule "GT 3A", the customer will remain on Schedule "GT 3A" for at least twelve (12) billing months. Rate schedule transfers will be made annually and become effective with the billing month of June. Available for primary service furnished directly from the Company's electric system at voltages of 4.16 kV, 13.2 kV or 33 kV, when the customer provides at the customer's own expense, all necessary transformers, converting apparatus, switches, disconnectors, regulators and protective equipment . Available for standby service when modified by Schedule "S". Not available for temporary service. Not available for multiple application to master-metered apartment buildings except for those master-metered apartments served under Schedule "GT 3A" prior to December 31, 1982 which will continue to be served under Schedule "GT 3A".

CHARACTER OF SERVICE The service under this schedule, normally will be alternating current, sixty hertz, three phase, three wire, at 4.16kV, 13.2kV or 33kV. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 203.81 per month $ 203.81 per month Kilowatt-hour Charge $ 0.00511 per kwhr $ 0.00510 per kwhr Kilowatt Charge Maximum $ 10.12 per kw $ 10.12 per kw Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Services from the Company under the provisions of Rider “SOS” – Standard Offer Service.


Electricity--P.S.C. of D.C. No. 1 DC - GT 3A Sixteenth Revised Page No. R-8.3


Billing Credit - A monthly billing credit in the amount of $0.75 per bill will be applied to the bill of each customer receiving generation services from an alternative supplier for each month that the alternative supplier renders a bill to the customer on a consolidated basis for services provided both by Pepco and by the alternative supplier.

BILLING MONTHS


BILLING DEMANDS Maximum (All Months) - The billing demand shall be the maximum thirty (30) minute demand recorded during the billing month. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Excess Facilities Net Energy Metering Rider Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GT 3B Sixteenth Revised Page No. R-8.4


TIME METERED GENERAL SERVICE - HIGH VOLTAGE SERVICE SCHEDULE "GT 3B"

AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area to customers whose maximum thirty (30) minute demand equals or exceeds one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months. New customers will be qualified for Schedule "GT 3B" based on estimated load and energy consumption using the above criteria. Once a customer's account is established it will remain on Schedule "GT 3B" even if the party responsible for the account should change. Removal from Schedule "GT 3B" is based solely on the criteria stated in the following paragraph. Any customer presently on Schedule "GT 3B" whose maximum thirty (30) minute demand is less than eighty (80) kilowatts for twelve (12) consecutive billing months, may at the customer's option elect to continue service on this schedule or elect to be served under any other available schedule. If the customer elects to stay on Schedule "GT 3B", the customer will remain on Schedule "GT 3B" for at least twelve (12) billing months. Rate schedule transfers will be made annually and become effective with the billing month of June. Available for standby service when modified by Schedule "S". Available for high voltage service furnished directly from the Company's electric system at voltages of 66 kV or above, when the customer provides at the customer's own expense, all necessary transformers, converting apparatus, switches, disconnectors, regulators and protective equipment . Not available for temporary service. Not available for multiple application to master-metered apartment buildings except for those master-metered apartments served under Schedule "GT 3B" prior to December 31, 1982 which will continue to be served under Schedule "GT 3B". CHARACTER OF SERVICE The service under this schedule, normally will be 66kV or above. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 322.83 per month $ 322.83 per month Kilowatt-hour Charge $ 0.00000 per kwhr $ 0.00000 per kwhr Kilowatt Charge Maximum $ 1.86 per kw $ 1.86 per kw


Electricity--P.S.C. of D.C. No. 1 DC - GT 3B Sixteenth Revised Page No. R-8.5




BILLING DEMANDS Maximum (All Months) - The billing demand shall be the maximum thirty (30) minute demand recorded during the billing month. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Excess Facilities Net Energy Metering Rider. Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - RT Thirteenth Revised Page No. R-9


RAPID TRANSIT SERVICE

SCHEDULE "RT"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for rapid transit electric service furnished directly from the Company's distribution, subtransmission or transmission systems at available voltages of 13.2kV and higher where the customer provides, at the customer's own expense, all necessary transformers or converting apparatus, switches, disconnectors, regulators, and protective equipment. Available only at points of delivery on contiguous authority right-of-way. Also available for low voltage service for purposes of operating electric chiller plants used for the purpose of providing chilled water to passenger stations associated with the rapid transit service. Not available for partial or auxiliary service. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, three phase, three wire, high tension at 13.2kV or such voltage as is specified by the Company on the basis of its available facilities and the magnitude of load to be served. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 7,092.29 per month $ 7,092.29 per month



BILLING MONTHS


BILLING DEMAND The monthly billing demand will be the maximum thirty (30) minute integrated coincident demand of all delivery points recorded during the billing month.


Electricity--P.S.C. of D.C. No. 1 DC - RT Thirteenth Revised Page No. R-9.1


BILLING ENERGY The monthly billing energy will be the sum of the registrations of kilowatt-hours of all delivery points. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations", except as modified by the agreement by and between the Company and the customer. APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Delivery Tax Public Space Occupancy Surcharge Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - SL Twelfth Revised Page No. R-10


STREET LIGHTING SERVICE

SCHEDULE "SL"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service for street, highway and park lighting purposes in the District of Columbia portion of the Company's service area when owned by agencies of Federal and District of Columbia governments. Also available to private area outdoor LED and Non-LED lighting and governmental and non-governmental customers for holiday lighting and seasonal street decoration lighting where the lights are in public space and where the only load supplied is lighting load. Schedule "SL" is not available for services that supply any load other than lighting. CHARACTER OF SERVICE Electricity supplied to multiple lights normally will be sixty hertz, single phase, 120 volts. MONTHLY RATE

Distribution Service Charge Customer Charge Metered Account $ 22.57 per month Unmetered Account $ 19.30 per month Kilowatt-hour Charge Non-LED Lights $ 0.01026 LED Lights $ 0.02558

The per kWh charge shall be adjusted for any Major Service Outages as defined in Section 3699 of Chapter 36, Electric Quality Service Standards in Title 15 of the District of Columbia Municipal Regulations.


The charges under this schedule are for delivery only and do not include furnishing and/or maintaining street lighting equipment. MEASUREMENTS OF ELECTRICITY If electricity delivered for street lighting is unmetered, monthly kilowatt-hour consumption will be computed on the basis of manufacturers' wattage ratings of installed lamps, auxiliary devices where required, and scheduled 4,200 hours of burning time. If metered, watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. Lights controlled for night burning only will be billed at the monthly rate for Standard Night Burning street lights. Lights not controlled for night burning only will be billed at the monthly rate for 24-Hour Burning street lights.


Electricity--P.S.C. of D.C. No. 1 DC - SL Twelfth Revised Page No. R-10.1


The kilowatt-hours calculated from billing wattages will be reduced by 5.5 percent each month to provide for normal outages.

GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". Holiday and decorative street lighting service connections will be considered temporary service connections as defined in the "Electric Service Rules and Regulations" and will be priced accordingly. APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Telecommunication Network Charge Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - TS Fourth Revised Page No. R-11


TRAFFIC SIGNAL SERVICE SCHEDULE "TS"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service to agencies of the Federal and District of Columbia governments, for operation of traffic signals in the District of Columbia portion of the Company's service area.

CHARACTER OF SERVICE Electricity supplied for traffic signal purposes normally will be sixty hertz, single phase, 120 volts.

MONTHLY RATE Distribution Service Charge Customer Charge $ 9.37 Kilowatt-hour Charge Non-LED Signal $ 0.01971 LED Signals $ 0.11767

The per kWh charge shall be adjusted for any Major Service Outages as defined in Section 3699 of Chapter 36, Electric Quality Service Standards in Title 15 of the District of Columbia Municipal Regulations.



The charges under this schedule are for delivery only and do not include furnishing and/or maintaining traffic signal equipment.

MEASUREMENT OF ELECTRICITY Electricity delivered to traffic signals is unmetered. Monthly kilowatt-hour consumption will be computed on the basis of manufacturers' wattage ratings of installed devices and estimated hours of burning time. The kilowatt-hours calculated from billing wattages will be reduced by 1.5 percent each month to provide for normal outages. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service” and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - SSL - OH Ninth Revised Page No. R-12


CHARGES FOR SERVICING

STREET LIGHTS SERVED FROM OVERHEAD LINES

SCHEDULE "SSL-OH"

APPLICABILITY Applicable only to luminaries meeting ANSI Standards for street lighting equipment when owned by the Company and mounted on Company-owned wooden poles or on poles of another utility with whom the Company has an attachment agreement. AVAILABILITY Available in the District of Columbia portion of the Company's service area to Federal Governmental Agencies for servicing street, highway and park lighting equipment when the electricity supplying such equipment is furnished by the Company from overhead lines and is accessible by conventional wheeled construction and maintenance vehicles.

Available only for lights having a manufacturers' nominal rating of:

Incandescent* 10,000 lumens or less Mercury Vapor* 100 – 400 watts High Pressure Sodium 70 – 400 watts Metal Halide 400 watts

*Not available for new installation or replacement of defective fixtures.

CHARACTER OF SERVICE Service rendered under this schedule will consist of (1) furnishing, installing and maintaining street lighting fixtures and mounting arms or brackets, (2) furnishing, installing, connecting, operating and maintaining the electric service circuits connecting the street lighting equipment to the Company's distribution system, (3) group relamping, (every six (6) months for incandescent, every four (4) years for mercury vapor and every five (5) years for high pressure sodium), (4) washing of globes, (5) furnishing and installing replacement globes, lamps, ballasts and light sensitive switches as needed to maintain the system in an operating mode; all normally limited, to standard items of equipment meeting ANSI Standards for street lighting equipment and approved by the Company for maintenance.

MONTHLY RATE

Fixed Charges O&M Charges Incandescent Lights* - Night Burning

Without Globe - all sizes $1.980 per lamp $0.031 per lamp With Globe - all sizes $2.896 per lamp $0.687 per lamp



Electricity--P.S.C. of D.C. No. 1 DC - SSL - OH Ninth Revised Page No. R-12.1


MONTHLY RATE (continued)

Mercury Vapor Lights* - Night Burning 175 Watt $6.185 per lamp $0.612 per lamp 250 Watt $7.067 per lamp $0.621 per lamp *Not available for new installation or replacement of defective fixtures.

The above charges will be separate from and in addition to charges for electricity supplied under the provisions of Schedule "SL".

NON-STANDARD EQUIPMENT Non Company approved ANSI equipment, if accepted by the Company for maintenance, will be subject to special contracts which may include an initial installation charge.

GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service” and the Company's "Electric Service Rules and Regulations".

Metal Halide Lights – Night Burning 400 Watt $23.947 per lamp $1.001 per lamp


Electricity--P.S.C. of D.C. No. 1 DC - SSL - UG Eleventh Revised Page No. R-13



STREET LIGHTS SERVED FROM UNDERGROUND LINES

SCHEDULE "SSL-UG"

APPLICABILITY Applicable only to posts and luminaries meeting ANSI Standards for street lighting equipment furnished by the customer.

AVAILABILITY Available in the District of Columbia portion of the Company's service area to Federal Governmental Agencies for servicing street, highway and park lighting equipment when the electricity supplying such equipment is furnished by the Company from unmetered underground lines and is accessible by conventional wheeled construction and maintenance vehicles.

Available only for lights having a manufacturers' nominal rating of: Incandescent* 10,000 lumens or less Mercury Vapor* 250 - 400 watts High Pressure Sodium 150 watts Metal Halide 100 - 400 watts *Not available for new installation or replacement of defective fixtures.

CHARACTER OF SERVICE Service rendered under this schedule will consist of (1) furnishing, installing, connecting, operating and maintaining the electric service circuits connecting the street lighting equipment to the Company's distribution system, (2) furnishing and installing post foundations and setting customer owned posts on foundations, (3) installing customer owned street lighting fixtures, (4) group relamping, (every six (6) months for incandescent, every two (2) years for metal halide, every four (4) years for mercury vapor and every five (5) years for high pressure sodium), (5) washing of globes, (6) furnishing and installing of replacement globes, lamps, remote ballasts, and light sensitive switches as needed to maintain the system in an operating mode, (7) repainting posts at approximately six (6) year intervals; all normally limited to standard items of equipment meeting ANSI Standards for street lighting equipment and accepted by the Company for maintenance. MONTHLY RATE


With Globe - all sizes $27.846 per lamp $1.259 per lamp


Mercury Vapor Lights* - Night Burning 250 Watt $28.087per lamp $1.131 per lamp 400 Watt $32.937 per lamp $1.405 per lamp



Electricity--P.S.C. of D.C. No. 1 DC - SSL - UG Eleventh Revised Page No. R-13.1



High Pressure Sodium Lights - Night Burning 150 Watt $24.629 per lamp $0.923 per lamp Metal Halide - Night Burning

100 Watt $21.221 per lamp $0.830 per lamp 175 Watt $23.947 per lamp $1.001 per lamp 400 Watt $23.947 per lamp $1.001 per lamp

*Not available for new installation or replacement of defective posts.


CUSTOMER RESPONSIBILITY AS TO FURNISHING, INSTALLING AND MAINTAINING EQUIPMENT The street lighting posts, fixtures and brackets (if required) shall be furnished by the customer for installation by the Company as set forth under "Character of Service" above. Ballasts for all High Pressure Sodium Lights and any Mercury Vapor Lights to be installed in or on upright posts shall be furnished by the customer. All Metal Halide lamps and ballasts shall be furnished by the customer for installation by the Company.

All maintenance of equipment furnished by the customer will be performed at the customer's expense, except as set forth under "Character of Service".

NON-STANDARD EQUIPMENT Non-company approved ANSI accepted equipment and non-standard, special, experimental and any other such post and luminaries which do not meet ANSI Standards for street lighting equipment, if accepted by the Company for maintenance, will be subjected to special contracts. Lights of this type will be installed in accordance with the customer's instruction, and all installation costs charged to the customer.


Other Posts furnished by the Company, costing*:

$ 15.00 and less $ 1.139 each $ 15.01 to $ 45.00, inclusive $ 1.517 each $ 45.01 to $ 75.00, inclusive $ 3.410 each $ 75.01 to $100.00, inclusive $ 5.687 each $100.01 to $160.00, inclusive $10.047 each


Electricity--P.S.C. of D.C. No. 1 DC - TN Twelfth Revised Page No. R-14


TELECOMMUNICATIONS NETWORK SERVICE

SCHEDULE "TN"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company’s service area for unmetered electric service to multiple telecommunications network devices or other devices with similar load characteristics served directly by the Company and not exceeding 1,800 watts per device. For devices that are currently served by meter, the Customer may choose to have the meter removed at the Customer’s expense and the month Customer Charge without Meter will apply. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, 120 volts. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 8.75 $ 8.75 Kilowatt-hour Charge $ 0.02837 per kwhr $ 0.02837 per kwhr

Customer Charges/Kilowatt-hour Charge – For devices that are served through a meter, the Customer shall pay the monthly “Customer Charge with Meter” and the kilowatt-hour charge will be applied to metered usage. For devices served without a meter, the Customer shall pay the monthly “Customer Charge without Meter” and the kilowatt-hour charge will be applied to estimated monthly usage based on metered usages for similar devices. If similar metered data do not exist, at the customer’s option, the monthly usage will be estimated base on either the manufacturer’s average wattage ratings with no allowance for outage, or on the basis of statistically valid sample estimates using actual current and voltage readings. Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Services from the Company under the provisions of Rider “SOS” – Standard Offer Service.

Billing Credit - A monthly billing credit in the amount of $0.75 will be applied to the bill of each

customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.

MEASUREMENTS OF ELECTRICITY Monthly kilowatt-hour consumption will be computed on the basis of manufacturer’s average wattage ratings of installed devices, with no allowance for outages. The charges under this rider are for electricity only.


Electricity--P.S.C. of D.C. No. 1 DC - TN Ninth Revised Page No. R-14.1


GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Services – Small Commercial Administrative Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Customer Base Rate Credit Rider Underground Rider


REDLINE


Electricity--P.S.C. of D.C. No. 1 DC Ninety-First Second Revised Page No. R-1

Date of Issue:November 29 December 19, 2017 Date Effective: Usage on and after

RATE SCHEDULES

FOR

ELECTRIC SERVICE

IN THE


RATES AND REGULATORY PRACTICES GROUP


Electricity--P.S.C. of D.C. No. 1 DC Ninety-First Second Revised Page No. R-2


TABLE OF CONTENTS

RATE SCHEDULES

RESIDENTIAL SERVICE - SCHEDULE "R" ...................................................................... Page R-3 - 3.1 RESIDENTIAL ALL-ELECTRIC SERVICE - SCHEDULE "AE" ......................................... Page R-4 - 4.1 TIME METERED RESIDENTIAL SERVICE - SCHEDULE "R-TM" ................................... Page R-5 - 5.1 TIME METERED RESIDENTIAL SERVICE - EXPERIMENTAL PROGRAM -

SCHEDULE "R-TM-EX" (THIS SCHEDULE HAS BEEN DELETED) ......................... Page R-5.2 -5.3 MASTER METERED APARTMENT – SCHEDULE “MMA” ………………………………... Page R-5.4 – 5.5 GENERAL SERVICE – NON DEMAND - SCHEDULE "GS ND" ...................................... Page R-6 - 6.1

GENERAL SERVICE - LOW VOLTAGE - SCHEDULE "GS LV" ...................................... Page R-6.2 - 6.3 GENERAL SERVICE - PRIMARY SERVICE - SCHEDULE "GS 3A" ............................... Page R-6.4- 6.5 TEMPORARY OR SUPPLEMENTARY SERVICE - SCHEDULE "T" ............................... Page R-7 - 7.1 TIME METERED GENERAL SERVICE - LOW VOLTAGE -

SCHEDULE "GT LV" ................................................................................................... Page R-8 - 8.1

TIME METERED GENERAL SERVICE - PRIMARY SERVICE - SCHEDULE "GT 3A" ................................................................................................... Page R-8.2- 8.3

TIME METERED GENERAL SERVICE - HIGH VOLTAGE - SCHEDULE "GT 3B" ................................................................................................... Page R-8.4- 8.5

RAPID TRANSIT SERVICE - SCHEDULE "RT" ................................................................ Page R-9 - 9.1 STREET LIGHTING SERVICE - SCHEDULE "SL" ........................................................... Page R-10 - 10.1 TRAFFIC SIGNAL SERVICE - SCHEDULE "TS" .............................................................. Page R-11 - 11.1 SERVICING STREET LIGHTS SERVED FROM OVERHEAD LINES -

SCHEDULE "SSL-OH" ................................................................................................ Page R-12 - 12.1

SERVICING STREET LIGHTS SERVED FROM UNDERGROUND LINES - SCHEDULE "SSL-UG" .................................................................................. Page R-13 - 13.1

TELECOMMUNICATIONS NETWORK SERVICE - SCHEDULE "TN" ............................. Page R-14 – 14.1

COGENERATION AND SMALL POWER PRODUCTION INTERCONNECTION SERVICE -

SCHEDULE "CG-SPP" ................................................................................................ Page R-15 - 15.4


Electricity--P.S.C. of D.C. No. 1 DC Sixtieth Sixty-First Revised Page No. 2.2



STANDBY SERVICE - SCHEDULE "S" ............................................................................ Page R-16 - 16.1 COMMUNITY RENEWABLE ENERGY FACILITY - SCHEDULE "CREF"........................ Page R-17 – 17.2 RESERVED FOR FUTURE USE ....................................................................................... Page R-18 - 24 RIDERS MARKET PRICE SERVICE - RIDER "MPS" ..................................................................... Page R-25 (THIS RIDER HAS BEEN DELETED) RELIABLE ENERGY TRUST FUND- RIDER "RETF" ....................................................... Page R-26 (THIS RIDER HAS BEEN DELETED) EXPERIMENTAL RESIDENTIAL ELECTRIC VEHICLE SERVICE - RIDER "R-EV"(THIS RIDER HAS BEEN DELETED) ................................................. Page R-27 EXPERIMENTAL RESIDENTIAL TIME-OF-USE ELECTRIC VEHICLE SERVICE - RIDER "R-TM-EV" (THIS RIDER HAS BEEN DELETED) ....................... Page R-28 RESIDENTIAL AID DISCOUNT - RIDER "RAD" ............................................................... Page R-29 POWER FACTOR - RIDER "PF" ....................................................................................... Page R-30 TELECOMMUNICATION NETWORK CHARGE - RIDER "SL-TN" .................................. Page R-31 DELIVERY TAX - RIDER "DT" ........................................................................................... Page R-32

PUBLIC SPACE OCCUPANCY SURCHARGE - RIDER "PSOS" ..................................... Page R-33 GENERATION PROCUREMENT CREDIT - RIDER "GPC" .............................................. Page R-34 - 34.1 (THIS RIDER HAS BEEN DELETED)

FUEL ADJUSTMENT CHARGE - RIDER "FA" (THIS RIDER HAS BEEN DELETED) ..... Page R-35 - 35.1 ENVIRONMENTAL COST RECOVERY RIDER - RIDER "ECRR" ................................... Page R-36 - 36.3 (THIS RIDER HAS BEEN DELETED) EXCESS FACILITIES - RIDER "EF" .................................................................................. Page R-37

OPTIONAL METER EQUIPMENT RELATED SERVICES - RIDER "OMRS" ................... Page R-38 - 38.1 DIVESTITURE SHARING CREDIT - RESIDENTIAL - RIDER "DS-R" .............................. Page R-39 (THIS RIDER HAS BEEN DELETED) DIVESTITURE SHARING CREDIT- NON-RESIDENTIAL - RIDER "DS-NR” ................... Page R-40 - 40.1 (THIS RIDER HAS BEEN DELETED) STANDARD OFFER SERVICE - RIDER “SOS” ................................................................ Page R-41 - 41.8 ADMINISTRATIVE CREDIT - RIDER “AC” ........................................................................ Page R-42


Electricity--P.S.C. of D.C. No. 1 DC Sixtieth Sixty-First Revised Page No. 2.2



RESERVED DELIVERY CAPACITY SERVICE – RIDER "RDCS"……………………… Page R-43 – 43.1 RIDER “PCDC” – POWERCENTSDC™ PROJECT

(THIS RIDER HAS BEEN DELETED) …………..………………………………. Page R-44 – 44.6 NET ENERGY METERING RIDER – RIDER “NEM”……………………………………… Page R-45 – 45.1 RESIDENTIAL AID DISCOUNT SURCHARGE RIDER – RIDER “RADS” ……..…… Page R-46 SUSTAINABLE ENERGY TRUST FUND – RIDER “SETF”..……………………………. Page R-47 ENERGY ASSISTANCE TRUST FUND – RIDER “EATF” ………………………………. Page R-48 BILL STABILIZATION ADJUSTMENT – RIDER “BSA” ………………………………. Page R-49 RESIDENTIAL DIRECT LOAD CONTROL – RIDER “R-DLC” …………………………. Page R-50 UNDERGROUND PROJECT CHARGE – RIDER “UPC” ……………………………….. Page R-51 COMMUNITY NET METERING – RIDER “CNM” ………………………………………… Page R-52 – 52.1 CUSTOMER BASE RATE CREDIT – RIDER “CBRC”……………………………..…….. Page R-53 UNDERGROUND RIDER……………………………………………………………………. Page R-54


Electricity--P.S.C. of D.C. No. 1 DC - R Seventeenth Eighteenth Revised Page No. R-3

Date of Issue: November 29December 19, 2017 Date Effective: Usage on and after

RESIDENTIAL SERVICE

SCHEDULE "R" AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service where the use is primarily for residential purposes and for farm operations where the electricity for both farm and residential purposes is delivered through the same meter. Available only in individual residences and in individually metered dwelling units in multi-family buildings. Not available for residential premises in which five (5) or more rooms are for hire. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE Distribution Service Charge

Summer Winter

Customer Charge – Residential $15.09 per month $ 15.09 per month Kilowatt-hour Charge

First 400 kilowatt-hours $ 0.00759 02076 per kwhr

$ 0.0075902076 per kwhr

In excess of 400 kilowatt hours $ 0.02166 02076 per kwhr

$ 0.01512 02076 per kwhr





Electricity--P.S.C. of D.C. No. 1 DC - R Seventeenth Eighteenth Revised Page No. R-3.1



APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Generation Procurement Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Optional Meter Equipment Related Services Divestiture Sharing Credit – Residential POWERCENTSDC™ Project Rider Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - AE Seventeenth Eighteenth Revised Page No. R-4


RESIDENTIAL ALL-ELECTRIC SERVICE

SCHEDULE "AE" AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service where electricity is the sole source of energy for space heating or the primary source with the application of an add-on heat pump or solar space heating system supplemented by electric space heating servicing the entire conditioned space. Available only in individual residences and in individually metered dwelling units in multi-family buildings. Not available for residential premises in which five (5) or more rooms are for hire. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. This schedule will be eliminated as of June 1, 2018. Customers taking service on this schedule will be moved to Schedule “R”. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE Distribution Service Charge

Summer Winter

Customer Charge – Residential $15.09 per month $15.09 per month Kilowatt-hour Charge First 400 kilowatt-hours $ 0.0207600759 per

kwhr $ 0.02076 00759per kwhr

In excess of 400 kilowatt-hours $ 0.0207602166 per kwhr

$ 0.0207601512 per kwhr



BILLING MONTHS



Electricity--P.S.C. of D.C. No. 1 DC - AE Sixteenth Seventeenth Revised Page No. R-4.1



APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Generation Procurement Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Optional Meter Equipment Related Services Divestiture Sharing Credit – Residential POWERCENTSDC™ Project Rider Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Rider Community Net Metering Rider

Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - R - TM Fifteenth Sixteenth Revised Page No. R-5.1


TIME METERED RESIDENTIAL SERVICE

SCHEDULE "R-TM" AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area to approximately the eight hundred (800) largest residential customers who have participated in the residential time-of-use rates program and who are served under Schedule "R-TM". Any customer presently on Schedule "R-TM" whose energy consumption is less than 2,500 kilowatt-hours for each of the five (5) summer billing months in a calendar year may at the customer's option elect to continue service under this schedule or be served under any other applicable schedule. If the customer elects to stay on Schedule "R-TM", the customer will remain on Schedule "R-TM" for at least twelve (12) billing months. Rate schedule changes will be made annually and become effective with the billing month of June.

Available only for low voltage electric service where the use is primarily for residential purposes and for farm operations where the electricity for both farm and residential purposes is delivered through the same meter.

Available only in individual residences and in individually metered dwelling units in multi-family buildings. Not available for multiple application to master-metered apartment buildings where the use is predominantly residential. Not available for residential premises in which five (5) or more rooms are for hire. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. Not available for customers certified as eligible to be billed under Rider "RAD". This schedule will be eliminated as of June 1, 2018. Customers taking service on this schedule will be moved to the schedule with the appropriate character of service prior to June 1, 2018.

CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE Distribution Service Charge

Summer Winter

Customer Charge $ 15.09 per month $ 15.09 per month Kilowatt-hour Charge First 400 kilowatt-hours $ 0.0075902076 per

kwhr $ 0.0075902076 per kwhr

In excess of 400 kilowatt-hours $ 0.0216602076 per kwhr

$ 0.0151202076 per kwhr


Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will


Electricity--P.S.C. of D.C. No. 1 DC - R - TM Fifteenth Sixteenth Revised Page No. R-5.1


receive Generation and Transmission Services from the Company under the provisions of Rider “SOS” – Standard Offer Service. Billing Credit - A monthly billing credit in the amount of $0.62 will be applied to the bill of each customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.

BILLING MONTHS Summer – Billing months of June through October.

Winter – Billing months of November through May. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. BILLING DEMAND The billing demand shall be the average of the maximum hourly demands recorded for each day of the billing month between the hours of 1p.m. and 9 p.m. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations." APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Generation Procurement Credit Delivery Tax Public Space Occupancy Surcharge Optional Meter Equipment Related Services Divestiture Sharing Credit - Residential Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - MMA First Second Revised Page No. R-5.4


MASTER METERED APARTMENT SERVICE SCHEDULE "MMA"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service for multiple application to master-metered apartment buildings where the use is predominantly residential and not for retail business establishments. Not available for separately metered service billed on Schedule “GS ND” that did not qualify for multiple application of the residential rate as of December 31, 1982. Not available for seasonal loads metered separately from lighting and other usage in the same occupancy. Not available for temporary, auxiliary or emergency service. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, three wire, 120/240 volts, or three wire, 120/208 volts. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $11.8413.71 per month $11.8413.71 per month

Kilowatt-hour Charge First 400 kilowatt-hours $ 0.00759 01027 per kwhr $ 0.00759 01027 per kwhr

In excess of 400 kilowatt-hours $ 0.02166 02930 per kwhr $ 0.01512 02045 per kwhr Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Service from the Company under the provisions of Rider “SOS” – Standard Offer Service. Billing Credit - A monthly billing credit in the amount of $0.62 will be applied to the bill of each customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.



Electricity--P.S.C. of D.C. No. 1 DC - MMA First Second Revised Page No. R-5.5


METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations."

APPLICABLE RIDERS Standard Offer Service - Residential Administrative Credit Generation Procurement Credit Delivery Tax Public Space Occupancy Surcharge Optional Meter Equipment Related Services Divestiture Sharing Credit – Residential Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Residential Direct Load Control Rider Underground Project Charge Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GS ND Fourteenth Fifteenth Revised Page No. R-6


GENERAL SERVICE – NON DEMAND

SCHEDULE "GS ND"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for “GS LV” customers whose maximum monthly demand is less than 25 kW. Customers whose maximum demand is between 25 kW and 99 kW will be served on Schedule GS LV or GS 3A subject to the provisions stated therein. Customers whose maximum demand is equal to or in excess of one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months will be transferred to Schedule "GT LV", "GT 3A", or "GT 3B" in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June.

Available for low voltage electric service at sixty hertz and for primary service furnished directly from the Company’s electric system at voltages of 4.16 kV, 13.2 kV, or 33 kV, when the customer provides at the customer’s own expense, all necessary transformers, converting apparatus, switches, disconnects, regulators and protective equipment.



CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, either (i) single phase, three wire, 120/240 volts or 120/208 volts, or (ii) three phase, four wire, 120/208 volts or 265/460 volts for GS Low Voltage Non Demand customers. For GS 3A Non Demand customers, the service under this schedule, normally will be alternating current, sixty hertz, three phase, three wire, at 4.16kV, 13.2kV or 33 kV. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served. MONTHLY RATE Summer Winter GS LOW VOLTAGE NON DEMAND

Distribution Service Charge Customer Charge $ 27.4233.99 per month $ 27.42 33.99 per month


All kilowatt-hours $ 0.03125 04467 per kwhr $ 0.02446 03497 per kwhr




Electricity--P.S.C. of D.C. No. 1 DC - GS ND Fourteenth Fifteenth Revised Page No. R-6.1








APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Generation Procurement Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Divestiture Sharing Credit – Non-Residential Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GS LV Thirteenth Fourteenth Revised Page No. R-6.2


GENERAL SERVICE - LOW VOLTAGE

SCHEDULE "GS LV"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area, except if the customer's maximum demand is equal to or in excess of one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months, the customer will be transferred to Schedule "GT LV", "GT 3A", or "GT 3B" in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June. Customers with monthly maximum demands less than 25 kW are served on Schedule “GS ND” subject to the provisions stated therein.

Available for low voltage electric service at sixty hertz.



CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, either (i) single phase, three wire, 120/240 volts or 120/208 volts, or (ii) three phase, four wire, 120/208 volts or 265/460 volts.

MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 35.1744.43 per month $ 35.1744.43 per month Kilowatt-hour Charge First 6,000 kilowatt-hours $ 0.03009 02680 per kwhr $ 0.02280 02031 per kwhr Additional kilowatt-hours $ 0.03009 02680 per kwhr $ 0.02280 02031 per kwhr Demand Charge $ 8.6410.44 per kw $ 8.6410.44 per kw



Electricity--P.S.C. of D.C. No. 1 DC - GS LV Thirteenth Fourteenth Revised Page No. R-6.3









APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Generation Procurement Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Divestiture Sharing Credit – Non-Residential Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GS 3A Fourteenth Fifteenth Revised Page No. R-6.4


GENERAL SERVICE - PRIMARY SERVICE

SCHEDULE "GS 3A"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS”, or Distribution Service in the District of Columbia portion of the Company's service area, except if the customer's maximum demand is equal to or in excess of one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months, the customer will be transferred to Schedule "GT LV", "GT 3A", or "GT 3B" in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June. Customers with monthly maximum demands less than 25 kW are served on Schedule “GS ND” subject to the provisions stated therein.

Available for primary service furnished directly from the Company's electric system at voltages of 4.16 kV, 13.2 kV or 33 kV, when the customer provides at the customer's own expense, all necessary transformers, converting apparatus, switches, disconnects, regulators and protective equipment. Not available for railway propulsion service. Not available for secondary temporary service or supplementary loads metered separately from lighting and other usage in the same occupancy. CHARACTER OF SERVICE The service under this schedule, normally will be alternating current, sixty hertz, three phase, three wire, at 4.16kV, 13.2kV or 33kV. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served.

MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 89.4197.02 per month $ 89.4197.02 per month Kilowatt-hour Charge

First 6000 kilowatt-hours $ 0.02015 02158 per kwhr $ 0.01448 01551 per kwhr Additional kilowatt-hours $ 0.02015 02158 per kwhr $ 0.01448 01551 per kwhr

Demand Charge $ 10.6111.95 per kw $ 10.6111.95 per kw




Electricity--P.S.C. of D.C. No. 1 DC - GS 3A Fourteenth Fifteenth Revised Page No. R-6.5


Demand metering equipment will be installed and charges subsequent to the installation of this equipment will be computed under the demand billing provision when the customer's load is of such a magnitude and of such a nature as to indicate any of the following: 1. Monthly energy consumption in excess of 6,000 kilowatt-hours in two (2) consecutive winter

billing months (November through May, inclusive).

2. Monthly energy consumption in excess of 7,500 kilowatt-hours for a single summer billing month (June through October, inclusive).





APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Generation Procurement Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Divestiture Sharing Credit – Non-Residential Net Energy Metering Rider Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - T Eleventh Twelfth Revised Page No. R-7


TEMPORARY SERVICE

SCHEDULE "T" AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for low voltage electric service for construction or other commercial purposes furnished through service connection facilities of a temporary rather than a permanent nature, or for temporary electric service supplied for a limited time, such as for carnivals, festivals, etc. However, customers receiving Temporary Service on a continuous basis for five (5) years will normally be transferred to the appropriate General Service Low Voltage Schedule “GS LV” or “GS ND” based on the customer’s maximum demand, in accordance with the availability provisions therein. Rate schedule transfers will be made annually and become effective with the billing month of June.

CHARACTER OF SERVICE The service supplied under this schedule will be alternating current, sixty hertz, at any of the approved classes of service.

MONTHLY RATE


BILLING MONTHS Summer – Billing months of June through October. Winter – Billing months of November through May. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations".

Summer Winter Distribution Service Charge Customer Charge $ 27.4233.13 per month $ 27.4233.13 per month Kilowatt-hour Charge $ 0.06362 07046 per kwhr $ 0.04961 05495 per kwhr


Electricity--P.S.C. of D.C. No. 1 DC - T Eleventh Twelfth Revised Page No. R-7.1


APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Generation Procurement Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Divestiture Sharing Credit – Non-Residential Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GT LV Fifteenth Sixteenth Revised Page No. R-8


TIME METERED GENERAL SERVICE - LOW VOLTAGE SCHEDULE "GT LV"

AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service when modified by Rider “SOS” in the District of Columbia portion of the Company's service area to customers whose maximum thirty (30) minute demand equals or exceeds one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months. New customers will be qualified for Schedule "GT LV" based on estimated load and energy consumption using the above criteria. Once a customer's account is established it will remain on Schedule "GT LV" even if the party responsible for the account should change. Removal from Schedule "GT LV" is based solely on the criteria stated in the following paragraph.

Any customer presently on Schedule "GT LV" whose maximum thirty (30) minute demand is less than eighty (80) kilowatts for twelve (12) consecutive billing months, may at the customer's option elect to continue service on this schedule or elect to be served under any other available schedule. If the customer elects to stay on Schedule "GT LV", the customer will remain on Schedule "GT LV" for at least twelve (12) billing months. Rate schedule transfers will be made annually and become effective with the billing month of June. Available for low voltage electric service at sixty hertz. Available for standby service when modified by Schedule "S". Not available for temporary service. Not available for multiple application to master-metered apartment buildings except for those master-metered apartments served under Schedule "GT LV" prior to December 31, 1982 which will continue to be served under Schedule "GT LV". CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, either (i) single phase, three wire, 120/240 volts or 120/208 volts, or (ii) three phase, four wire, 120/208 volts or 265/460 volts. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 456.76518.02 per month $ 456.76518.02 per month

Kilowatt-hour Charge $ 0.00925 01313 per kwhr $ 0.00925 01313 per kwhr Kilowatt Charge Maximum $ 11.4713.84 per kw $ 11.4713.84 per kw



Electricity--P.S.C. of D.C. No. 1 DC - GT LV Fifteenth Sixteenth Revised Page No. R-8.1


Billing Credit - A monthly billing credit in the amount of $0.75 per bill will be applied to the bill of

each customer receiving generation services from an alternative supplier for each month that the alternative supplier renders a bill to the customer on a consolidated basis for services provided both by Pepco and by the alternative supplier.


BILLING DEMANDS Maximum (All Months) - The billing demand shall be the maximum thirty (30) minute demand recorded during the billing month.

METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly.

GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Generation Procurement Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Excess Facilities Divestiture Sharing Credit – Non-Residential Net Energy Metering Rider Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GT 3A Fifteenth Sixteenth Revised Page No. R-8.2


TIME METERED GENERAL SERVICE - PRIMARY SERVICE

SCHEDULE "GT 3A"

AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area to customers whose maximum thirty (30) minute demand equals or exceeds one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months. New customers will be qualified for Schedule "GT 3A" based on estimated load and energy consumption using the above criteria. Once a customer's account is established it will remain on Schedule "GT 3A" even if the party responsible for the account should change. Removal from Schedule "GT 3A" is based solely on the criteria stated in the following paragraph. Any customer presently on Schedule "GT 3A" whose maximum thirty (30) minute demand is less than eighty (80) kilowatts for twelve (12) consecutive billing months, may at the customer's option elect to continue service on this schedule or elect to be served under any other available schedule. If the customer elects to stay on Schedule "GT 3A", the customer will remain on Schedule "GT 3A" for at least twelve (12) billing months. Rate schedule transfers will be made annually and become effective with the billing month of June. Available for primary service furnished directly from the Company's electric system at voltages of 4.16 kV, 13.2 kV or 33 kV, when the customer provides at the customer's own expense, all necessary transformers, converting apparatus, switches, disconnectors, regulators and protective equipment . Available for standby service when modified by Schedule "S". Not available for temporary service. Not available for multiple application to master-metered apartment buildings except for those master-metered apartments served under Schedule "GT 3A" prior to December 31, 1982 which will continue to be served under Schedule "GT 3A".

CHARACTER OF SERVICE The service under this schedule, normally will be alternating current, sixty hertz, three phase, three wire, at 4.16kV, 13.2kV or 33kV. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 187.64203.81 per month $ 187.64203.81 per month Kilowatt-hour Charge $ 0.00428 00511 per kwhr $ 0.00427 00510 per kwhr Kilowatt Charge Maximum $ 8.3610.12 per kw $ 8.3610.12 per kw Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Services from the Company under the provisions of Rider “SOS” – Standard Offer Service.


Electricity--P.S.C. of D.C. No. 1 DC - GT 3A Fifteenth Sixteenth Revised Page No. R-8.3


Billing Credit - A monthly billing credit in the amount of $0.75 per bill will be applied to the bill of each customer receiving generation services from an alternative supplier for each month that the alternative supplier renders a bill to the customer on a consolidated basis for services provided both by Pepco and by the alternative supplier.

BILLING MONTHS


BILLING DEMANDS Maximum (All Months) - The billing demand shall be the maximum thirty (30) minute demand recorded during the billing month. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Generation Procurement Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Excess Facilities Divestiture Sharing Credit – Non-Residential Net Energy Metering Rider Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - GT 3B Fifteenth Sixteenth Revised Page No. R-8.4


TIME METERED GENERAL SERVICE - HIGH VOLTAGE SERVICE SCHEDULE "GT 3B"

AVAILABILITY Shall be applicable for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area to customers whose maximum thirty (30) minute demand equals or exceeds one hundred (100) kilowatts during two (2) or more billing months within twelve (12) consecutive billing months. New customers will be qualified for Schedule "GT 3B" based on estimated load and energy consumption using the above criteria. Once a customer's account is established it will remain on Schedule "GT 3B" even if the party responsible for the account should change. Removal from Schedule "GT 3B" is based solely on the criteria stated in the following paragraph. Any customer presently on Schedule "GT 3B" whose maximum thirty (30) minute demand is less than eighty (80) kilowatts for twelve (12) consecutive billing months, may at the customer's option elect to continue service on this schedule or elect to be served under any other available schedule. If the customer elects to stay on Schedule "GT 3B", the customer will remain on Schedule "GT 3B" for at least twelve (12) billing months. Rate schedule transfers will be made annually and become effective with the billing month of June. Available for standby service when modified by Schedule "S". Available for high voltage service furnished directly from the Company's electric system at voltages of 66 kV or above, when the customer provides at the customer's own expense, all necessary transformers, converting apparatus, switches, disconnectors, regulators and protective equipment . Not available for temporary service. Not available for multiple application to master-metered apartment buildings except for those master-metered apartments served under Schedule "GT 3B" prior to December 31, 1982 which will continue to be served under Schedule "GT 3B". CHARACTER OF SERVICE The service under this schedule, normally will be 66kV or above. Primary nominal service voltage levels will be specified by the Company on the basis of its available facilities and the magnitude of the load to be served. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 423.38322.83 per month $ 423.38322.83 per month Kilowatt-hour Charge $ 0.00000 per kwhr $ 0.00000 per kwhr Kilowatt Charge Maximum $ 1.40 86 per kw $ 1.50 86 per kw


Electricity--P.S.C. of D.C. No. 1 DC - GT 3B Fifteenth Sixteenth Revised Page No. R-8.5




BILLING DEMANDS Maximum (All Months) - The billing demand shall be the maximum thirty (30) minute demand recorded during the billing month. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Generation Procurement Credit Power Factor Delivery Tax Public Space Occupancy Surcharge Excess Facilities Divestiture Sharing Credit – Non - Residential Net Energy Metering Rider. Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Bill Stabilization Adjustment Underground Project Charge Rider Community Net Metering Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - RT Twelfth Thirteenth Revised Page No. R-9


RAPID TRANSIT SERVICE

SCHEDULE "RT"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company's service area for rapid transit electric service furnished directly from the Company's distribution, subtransmission or transmission systems at available voltages of 13.2kV and higher where the customer provides, at the customer's own expense, all necessary transformers or converting apparatus, switches, disconnectors, regulators, and protective equipment. Available only at points of delivery on contiguous authority right-of-way. Also available for low voltage service for purposes of operating electric chiller plants used for the purpose of providing chilled water to passenger stations associated with the rapid transit service. Not available for partial or auxiliary service. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, three phase, three wire, high tension at 13.2kV or such voltage as is specified by the Company on the basis of its available facilities and the magnitude of load to be served. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 6,208.787,092.29 per month $ 6,208.78 7,092.29 per month



BILLING MONTHS


BILLING DEMAND The monthly billing demand will be the maximum thirty (30) minute integrated coincident demand of all delivery points recorded during the billing month.


Electricity--P.S.C. of D.C. No. 1 DC - RT TwelfthThirteenth Revised Page No. R-9.1


BILLING ENERGY The monthly billing energy will be the sum of the registrations of kilowatt-hours of all delivery points. METER READING Watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations", except as modified by the agreement by and between the Company and the customer. APPLICABLE RIDERS Standard Offer Service – Large Commercial Administrative Credit Generation Procurement Credit Delivery Tax Public Space Occupancy Surcharge Divestiture Sharing Credit – Non-Residential Reserved Delivery Capacity Service Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - SL Eleventh Twelfth Revised Page No. R-10


STREET LIGHTING SERVICE

SCHEDULE "SL"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service for street, highway and park lighting purposes in the District of Columbia portion of the Company's service area when owned by agencies of Federal and District of Columbia governments. Also available to private area outdoor LED and Non-LED lighting and governmental and non-governmental customers for holiday lighting and seasonal street decoration lighting where the lights are in public space and where the only load supplied is lighting load. Schedule "SL" is not available for services that supply any load other than lighting. CHARACTER OF SERVICE Electricity supplied to multiple lights normally will be sixty hertz, single phase, 120 volts. MONTHLY RATE

Distribution Service Charge Customer Charge Metered Account $ 17.1922.57 per month Unmetered Account $ 14.7019.30 per month Per Lamp Charge Kilowatt-hour Charge $ 0.55497 per lamp per month Non-LED Lights $ 0.01026 LED Lights $ 0.02558

The per lamp kWh charge shall be adjusted for any Major Service Outages as defined in Section 3699 of Chapter 36, Electric Quality Service Standards in Title 15 of the District of Columbia Municipal Regulations.


The charges under this schedule are for delivery only and do not include furnishing and/or maintaining street lighting equipment. MEASUREMENTS OF ELECTRICITY If electricity delivered for street lighting is unmetered, monthly kilowatt-hour consumption will be computed on the basis of manufacturers' wattage ratings of installed lamps, auxiliary devices where required, and scheduled 4,200 hours of burning time. If metered, watt-hour meters will be read to the nearest multiple of the meter constant and bills rendered accordingly. Lights controlled for night burning only will be billed at the monthly rate for Standard Night Burning street lights. Lights not controlled for night burning only will be billed at the monthly rate for 24-Hour Burning street lights.


Electricity--P.S.C. of D.C. No. 1 DC - SL Eleventh Twelfth Revised Page No. R-10.1


The kilowatt-hours calculated from billing wattages will be reduced by 5.5 percent each month to provide for normal outages.

GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". Holiday and decorative street lighting service connections will be considered temporary service connections as defined in the "Electric Service Rules and Regulations" and will be priced accordingly. APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Generation Procurement Credit Delivery Tax Public Space Occupancy Surcharge Divestiture Sharing Credit – Non-Residential Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Telecommunication Network Charge Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - TS Third Fourth Revised Page No. R-11


TRAFFIC SIGNAL SERVICE SCHEDULE "TS"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service to agencies of the Federal and District of Columbia governments, for operation of traffic signals in the District of Columbia portion of the Company's service area.

CHARACTER OF SERVICE Electricity supplied for traffic signal purposes normally will be sixty hertz, single phase, 120 volts. MONTHLY RATE

Distribution Service Charge Customer Charge $ 8.039.37 Kilowatt-hour Charge Per Lamp Charge $ 0.30291 Non-LED Signal $ 0.01971 LED Signals $ 0.11767

The per kWhlamp charge shall be adjusted for any Major Service Outages as defined in Section 3699 of Chapter 36, Electric Quality Service Standards in Title 15 of the District of Columbia Municipal Regulations.



The charges under this schedule are for delivery only and do not include furnishing and/or maintaining traffic signal equipment.

MEASUREMENT OF ELECTRICITY Electricity delivered to traffic signals is unmetered. Monthly kilowatt-hour consumption will be computed on the basis of manufacturers' wattage ratings of installed devices and estimated hours of burning time. The kilowatt-hours calculated from billing wattages will be reduced by 1.5 percent each month to provide for normal outages. GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service” and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Service – Small Commercial Administrative Credit Generation Procurement Credit Delivery Tax Public Space Occupancy Surcharge Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC - SSL - OH Eighth Ninth Revised Page No. R-12

Date of Issue: April 9, 2014December 19, 2017 Date Effective: Usage on and after


STREET LIGHTS SERVED FROM OVERHEAD LINES

SCHEDULE "SSL-OH"

APPLICABILITY Applicable only to luminaries meeting ANSI Standards for street lighting equipment when owned by the Company and mounted on Company-owned wooden poles or on poles of another utility with whom the Company has an attachment agreement. AVAILABILITY Available in the District of Columbia portion of the Company's service area to Federal Governmental Agencies for servicing street, highway and park lighting equipment when the electricity supplying such equipment is furnished by the Company from overhead lines and is accessible by conventional wheeled construction and maintenance vehicles.

Available only for lights having a manufacturers' nominal rating of:

Incandescent* 10,000 lumens or less Mercury Vapor* 100 – 400 watts High Pressure Sodium 70 – 400 watts Metal Halide 400 watts


CHARACTER OF SERVICE Service rendered under this schedule will consist of (1) furnishing, installing and maintaining street lighting fixtures and mounting arms or brackets, (2) furnishing, installing, connecting, operating and maintaining the electric service circuits connecting the street lighting equipment to the Company's distribution system, (3) group relamping, (every six (6) months for incandescent, every four (4) years for mercury vapor and every five (5) years for high pressure sodium), (4) washing of globes, (5) furnishing and installing replacement globes, lamps, ballasts and light sensitive switches as needed to maintain the system in an operating mode; all normally limited, to standard items of equipment meeting ANSI Standards for street lighting equipment and approved by the Company for maintenance.

MONTHLY RATE


Without Globe - all sizes $2.4781.980 per lamp $0.039 031 per lamp With Globe - all sizes $3.6252.896 per lamp $0.860 687 per lamp



Electricity--P.S.C. of D.C. No. 1 DC - SSL - OH Eighth Ninth Revised Page No. R-12.1



Mercury Vapor Lights* - Night Burning 175 Watt $7.742 6.185 per lamp $0.767 612 per lamp 250 Watt $8.8467.067 per lamp $0.777 621 per lamp *Not available for new installation or replacement of defective fixtures.


NON-STANDARD EQUIPMENT Non Company approved ANSI equipment, if accepted by the Company for maintenance, will be subject to special contracts which may include an initial installation charge.


Metal Halide Lights – Night Burning 400 Watt $29.97523.947 per lamp $1.253001 per lamp


Electricity--P.S.C. of D.C. No. 1 DC - SSL - UG Tenth Eleventh Revised Page No. R-13



STREET LIGHTS SERVED FROM UNDERGROUND LINES

SCHEDULE "SSL-UG"

APPLICABILITY Applicable only to posts and luminaries meeting ANSI Standards for street lighting equipment furnished by the customer.

AVAILABILITY Available in the District of Columbia portion of the Company's service area to Federal Governmental Agencies for servicing street, highway and park lighting equipment when the electricity supplying such equipment is furnished by the Company from unmetered underground lines and is accessible by conventional wheeled construction and maintenance vehicles.

Available only for lights having a manufacturers' nominal rating of: Incandescent* 10,000 lumens or less Mercury Vapor* 250 - 400 watts High Pressure Sodium 150 watts Metal Halide 100 - 400 watts *Not available for new installation or replacement of defective fixtures.

CHARACTER OF SERVICE Service rendered under this schedule will consist of (1) furnishing, installing, connecting, operating and maintaining the electric service circuits connecting the street lighting equipment to the Company's distribution system, (2) furnishing and installing post foundations and setting customer owned posts on foundations, (3) installing customer owned street lighting fixtures, (4) group relamping, (every six (6) months for incandescent, every two (2) years for metal halide, every four (4) years for mercury vapor and every five (5) years for high pressure sodium), (5) washing of globes, (6) furnishing and installing of replacement globes, lamps, remote ballasts, and light sensitive switches as needed to maintain the system in an operating mode, (7) repainting posts at approximately six (6) year intervals; all normally limited to standard items of equipment meeting ANSI Standards for street lighting equipment and accepted by the Company for maintenance. MONTHLY RATE


With Globe - all sizes $34.85527.846

per lamp $1.5761.259 per lamp


Mercury Vapor Lights* - Night Burning 250 Watt $35.15628.087

per lamp $1.4161.131 per lamp

400 Watt $41.22732.937 per lamp

$1.7591.405 per lamp



Electricity--P.S.C. of D.C. No. 1 DC - SSL - UG Tenth Eleventh Revised Page No. R-13.1



High Pressure Sodium Lights - Night Burning 150 Watt $30.82824.629 per

lamp $1.1550.923 per lamp

Metal Halide - Night Burning

100 Watt $26.56321.221 per

lamp $1.0390.830 per lamp

175 Watt $29.97523.947 per lamp

$1.2531.001 per lamp

400 Watt $29.97523.947 per lamp

$1.2531.001 per lamp

*Not available for new installation or replacement of defective posts.


CUSTOMER RESPONSIBILITY AS TO FURNISHING, INSTALLING AND MAINTAINING EQUIPMENT The street lighting posts, fixtures and brackets (if required) shall be furnished by the customer for installation by the Company as set forth under "Character of Service" above. Ballasts for all High Pressure Sodium Lights and any Mercury Vapor Lights to be installed in or on upright posts shall be furnished by the customer. All Metal Halide lamps and ballasts shall be furnished by the customer for installation by the Company.

All maintenance of equipment furnished by the customer will be performed at the customer's expense, except as set forth under "Character of Service".

NON-STANDARD EQUIPMENT Non-company approved ANSI accepted equipment and non-standard, special, experimental and any other such post and luminaries which do not meet ANSI Standards for street lighting equipment, if accepted by the Company for maintenance, will be subjected to special contracts. Lights of this type will be installed in accordance with the customer's instruction, and all installation costs charged to the customer.


Other Posts furnished by the Company, costing*:

$ 15.00 and less $ 1.139 each $ 15.01 to $ 45.00, inclusive $ 1.517 each $ 45.01 to $ 75.00, inclusive $ 3.410 each $ 75.01 to $100.00, inclusive $ 5.687 each $100.01 to $160.00, inclusive $10.047 each


Electricity--P.S.C. of D.C. No. 1 DC - TN Eleventh Twelfth Revised Page No. R-14


TELECOMMUNICATIONS NETWORK SERVICE

SCHEDULE "TN"

AVAILABILITY Available for either Standard Offer Service when modified by Rider “SOS” or Distribution Service in the District of Columbia portion of the Company’s service area for unmetered electric service to multiple telecommunications network devices or other devices with similar load characteristics served directly by the Company and not exceeding 1,800 watts per device. For devices that are currently served by meter, the Customer may choose to have the meter removed at the Customer’s expense and the month Customer Charge without Meter will apply. CHARACTER OF SERVICE The service supplied under this schedule normally will be alternating current, sixty hertz, single phase, 120 volts. MONTHLY RATE

Summer Winter Distribution Service Charge Customer Charge $ 15.318.75 $ 15.318.75 Kilowatt-hour Charge $ 0.01427 02837 per kwhr $ 0.01427 02837 per kwhr

Customer Charges/Kilowatt-hour Charge – For devices that are served through a meter, the Customer shall pay the monthly “Customer Charge with Meter” and the kilowatt-hour charge will be applied to metered usage. For devices served without a meter, the Customer shall pay the monthly “Customer Charge without Meter” and the kilowatt-hour charge will be applied to estimated monthly usage based on metered usages for similar devices. If similar metered data do not exist, at the customer’s option, the monthly usage will be estimated base on either the manufacturer’s average wattage ratings with no allowance for outage, or on the basis of statistically valid sample estimates using actual current and voltage readings. Generation and Transmission Service Charges – Customers who do not receive service from an alternative Electric Supplier as defined in the Company’s General Terms and Conditions will receive Generation and Transmission Services from the Company under the provisions of Rider “SOS” – Standard Offer Service.

Billing Credit - A monthly billing credit in the amount of $0.75 will be applied to the bill of each

customer receiving a consolidated bill from an alternative supplier for services provided both by Pepco and by the alternative supplier.

MEASUREMENTS OF ELECTRICITY Monthly kilowatt-hour consumption will be computed on the basis of manufacturer’s average wattage ratings of installed devices, with no allowance for outages. The charges under this rider are for electricity only.


Electricity--P.S.C. of D.C. No. 1 DC - TN Eighth Ninth Revised Page No. R-14.1


GENERAL TERMS AND CONDITIONS This schedule is subject in all respects to the Company's "General Terms and Conditions for Furnishing Electric Service" and the Company's "Electric Service Rules and Regulations". APPLICABLE RIDERS Standard Offer Services – Small Commercial Administrative Credit Generation Procurement CreditDelivery Tax Public Space Occupancy Surcharge Divestiture Sharing Credit – Non-Residential Residential Aid Discount Surcharge Rider Sustainable Energy Trust Fund Energy Assistance Trust Fund Underground Project Charge Rider Customer Base Rate Credit Rider Underground Rider


Electricity--P.S.C. of D.C. No. 1 DC Eighth Revised Page No. R-34

Date of Issue: March 13, 2009 Date Effective: Billing Month of April 2009 Date Expires: Billing Month of March 2010

GENERATION PROCUREMENT CREDIT

RIDER "GPC"

GENERATION PROCUREMENT CREDIT – RIDER "GPC” Rates for electric service are subject to a credit adjustment if the Company is able to procure power at a lower cost than is contained in rates at the time of the sale of the Company’s generating assets (less any Competitive Transition Charge). The adjustment applicable to each schedule will be computed in accordance with the procedure described below:

The profit component of the Rider “GPC” adjustment will be determined annually based on the difference between actual prior year Generation Procurement costs for providing Standard Offer Service (SOS) and the revenues for providing generation service to SOS customers. The first application of the profit component of the GPC is effective for bills rendered August 15, 2002 through August 14, 2003, based on the costs and revenues experienced for the twelve month period ending February 7, 2002. The second application of the profit component of the GPC will be effective from the billing month of June 2003 through the billing month of May 2004, based on the costs and revenues experienced for the twelve month period ending February 7, 2003. Subsequent filings will also become effective in the billing month of June based on the twelve months ending the previous February 7, in order to permit the actual cost computation and filing with the Commission. Generation Procurement Costs are those costs incurred by Pepco to secure the necessary energy supply for default service from third party suppliers (including affiliates), from purchases in the wholesale market, through buy-back arrangements made during the divestiture process, from the Company’s own units until they have been divested, and/or other appropriate methods. If the deferred fuel balance at the time of the asset sale indicates that a refund is necessary, the Company agrees to include an additional credit in Rider “GPC” that will return the balance to customers. If the deferred fuel balance at the time of the asset sale indicates that an additional charge is required, the Company will collect this as a charge through Rider “GPC”. Any charge for deferred fuel will not exceed the credit amount provided by the operation of Rider “GPC” so the Rider “GPC” will not result in a net charge to customers, and any costs that remain unrecovered due to this limitation will be deferred for recovery in a subsequent period.

If the SOS revenue is greater than the cost to the Company of procuring power for its SOS, the Company will share with customers 80% of the profit if the profit is $20 million or less. If the Company receives profits in excess of $20 million, customers will receive 60% of the profits in excess of $20 million in addition to 80% of the first $20 million of profit.

The Company will retain the portion of the net profit, if any, that would otherwise be allocated to residential and commercial customers until such amount equals the total amount of the guaranteed residential rate reduction of 3 ½% ($.00277) and the guaranteed commercial reduction of 1 ½% ($.00109) that is funded through the operation of Rider “GPC”. Accordingly, residential and commercial customers will receive payments under Rider “GPC” only when the amounts exceed the amounts of their respective guaranteed rate reductions.


Electricity--P.S.C. of D.C. No. 1 DC Eighth Revised Page No. R-34.1

Date of Issue: March 13, 2009 Date Effective: Billing Month of April 2009 Date Expires: Billing Month of March 2010

The credits/charges for Rider “GPC” will be effective with the billing month of April 2009 through the billing month of March 2010. The Generation Procurement Credit effective with the billing month of April 2009 is $0.000000 per Kilowatt-hour for residential customer on Schedules “R”,”AE”, and ”RTM”. The Generation Procurement Credit effective with the billing month of April 2009 is $0.000056 per kilowatt-hour for non-Residential customers on Schedules “GS ND”, “GS LV”, "GS 3A", “T”, “GT-LV”, “GT-3A”, “GT-3B”, “RT”, “SL”, “TS” and “TN”. Details of the calculation of the Generation Procurement credit are filed with the District of Columbia Public Service Commission for approval prior to any change in the billing rates.


Electric--P.S.C. of D.C. No. 1 DC Sixth Revised Page No. R-39

Date of Issue: August 8, 2017 Date Effective: Usage on and after August 15, 2017

DIVESTITURE SHARING CREDIT - RESIDENTIAL

RIDER “DS-R”

RIDER “DS-R”- DIVESTITURE SHARING CREDIT– RESIDENTAL This rider is applicable to Schedules “R”, “AE”, “R-TM”, and “MMA”. Pursuant to Order No. 12159 issued on September 19, 2001 and Order No. 12203 issued on October 10, 2001 by the Public Service Commission of the District of Columbia, the Company will provide to its District of Columbia residential customers a share of the net proceeds received from the sale of the generation assets through a bill credit. The residential credit is distributed on a per customer basis. The amount of credit to be provided to each residential customer is calculated by dividing the amount of Residential Sharing by the total number of residential customers of record as of September 19, 2001 served by the Company in the District of Columbia. Residential customers will receive a one-time credit of $75.39 with the first billing cycle after October 22, 2001. Residential customers will receive an additional one-time credit of $5.03 on bills rendered for the billing month of December, 2002 to reflect the customer’s share of additional proceeds from the sale of generation assets. This credit will be provided to residential customers of record as of October 31, 2002 served by the Company in the District of Columbia. Residential customers will receive a third one-time credit of $16.84 on bills rendered for the billing month of April, 2009 to reflect the customer’s share of additional proceeds resulting from the settlement with the Mirant Bankruptcy Estate and the transfer of responsibility for the Panda Power Purchase Agreement to a third party. This credit will be provided to residential customers of record as of March 5, 2009 served by the Company in the District of Columbia. Residential customers will receive a fourth one-time credit of $7.83 on bills rendered for the billing month of September 2010 in compliance with Commission Order Nos. 15810 and 15883. This credit will be provided to residential customers of record as of June 30, 2010 served by the Company in the District of Columbia.


Electric--P.S.C. of D.C. No. 1 DC Fourth Revised Page No. R-40


DIVESTITURE SHARING CREDIT – NON-RESIDENTIAL

RIDER “DS-NR”

RIDER “DS-NR”- DIVESTITURE SHARING CREDIT-NON-RESIDENTAL This rider is applicable to non-residential customers in the District of Columbia. Non-residential customers are those customers served under Schedules “GS LV”, “GS 3A”, “T”, “GT LV”, “GT 3A”, “GT 3B”, “RT”, “SL”, “TS”, “TN” and master-metered apartment buildings served under Schedules “R”, “AE” and “RTM”. Pursuant to Order No. 12159 issued on September 19, 2001 and Order No. 12203 issued on October 10, 2001 by the Public Service Commission of the District of Columbia, the Company will provide to its District of Columbia non-residential customers a share of the net proceeds received from the sale of the generation assets through a bill credit.

The amount of the one-time credit to be provided will be calculated by the Company on an individual

customer basis for each non-residential customer served by the Company in its District of Columbia service territory, as shown on the books and records of the Company as of the close of business September 19, 2001. The non-residential credits are distributed on a per kilowatt-hour basis. The amount of credit to be provided to each non-residential customer is calculated by dividing the amount of Non-residential Sharing by the total kilowatt-hours delivered by the Company to its District of Columbia non-residential customers during the twelve (12) months ended March 31, 2001. Each non-residential customer’s credit is determined by multiplying the Divestiture Sharing Credit shown below by the number of kilowatt-hours delivered by the Company to such customer’s premises during the twelve (12) months ended March 31, 2001

The Divestiture Sharing Credits for non-residential customers effective with the first billing cycle after October 22, 2001 are as follows:

Master-metered apartment buildings $ 0.00876 per kwhr Schedules “GS LV”, “GS 3A”, “T”, “GT LV”, “GT 3A”, “GT 3B”, “RT”, “SL”, “TS”, and “TN”

$ 0.00393 per kwhr


Electric--P.S.C. of D.C. No. 1 DC Third Revised Page No. R-40.1


Non-residential customers will receive an additional one-time credit on bills rendered for the billing month of January, 2003 to reflect the customer’s share of additional proceeds from the sale of generation assets. This credit will be provided to non-residential customers of record as of October 31, 2002 served by the Company in the District of Columbia. The additional credit per kilowatt-hour is calculated by dividing the additional amount of the non-residential customers’ share by the total kilowatt-hours delivered by the Company to its District of Columbia non-residential customers during the twelve (12) months ended August 31, 2002. The additional one-time credit on each bill is calculated by multiplying the total kilowatt-hours delivered to the premises for the 12 billing months ended August 31, 2002, by the appropriate credit per kilowatt-hour stated below: Master-metered apartment buildings $ 0.00057 per kwhr Schedules “GS LV”, “GS 3A”, “T”, “GT LV”, “GT 3A”, “GT 3B”, “RT”, “SL”, “TS”, and “TN”

$ 0.00069 per kwhr

Non-residential customers will receive a third one-time credit on bills rendered for the billing month of April, 2009 to reflect the customer’s share of additional proceeds resulting from the settlement with the Mirant Bankruptcy Estate and the transfer of responsibility for the Panda Power Purchase Agreement to a third party. This credit will be provided to non-residential customers of record as of March 5, 2009 served by the Company in the District of Columbia. The additional credit per kilowatt-hour is calculated by dividing the additional amount of the non-residential customers’ share by the total kilowatt-hours delivered by the Company to its District of Columbia non-residential customers during the twelve (12) months ended February 28, 2009. The additional one-time credit on each bill is calculated by multiplying the total kilowatt-hours delivered to the premises for the 12 billing months ended February 28, 2009, by the appropriate credit per kilowatt-hour stated below: Master-metered apartment buildings $ 0.00192 per kwhr Schedules “GS LV”, “GS 3A”, “T”, “GT LV”, “GT 3A”, “GT 3B”, “RT”, “SL”, “TS”, and “TN”

$ 0.00215 per kwhr

Non-residential customers will receive a fourth one-time credit on bills rendered for the billing month of September, 2010 in compliance with Commission Order Nos. 15810 and 15883. This credit will be provided to non-residential customers of record as of June 30, 2010 served by the Company in the District of Columbia. The additional credit per kilowatt-hour is calculated by dividing the additional amount of the non-residential customers’ share by the total kilowatt-hours delivered by the Company to its District of Columbia non-residential customers during the twelve (12) months ended June 30, 2010. The additional one-time credit on each bill is calculated by multiplying the total kilowatt-hours delivered to the premises for the 12 billing months ended June 30, 2010, by the appropriate credit per kilowatt-hour stated below: Master-metered apartment buildings $ 0.00091 per kwhr Schedules “GS LV”, “GS 3A”, “T”, “GT LV”, “GT 3A”, “GT 3B”, “RT”, “SL”, “TS”, and “TN”

$ 0.00095 per kwhr


Electric--P.S.C. of D.C. No. 1 DC Third Revised Page No. R-44

Date of Issue: May 29, 2009 Date Effective: Service on and after June 1, 2009

POWERCENTSDC™ PROJECT RIDER RIDER “PCDC”

RIDER “PCDC” – POWERCENTSDC™ PROJECT Available in the District of Columbia portion of the Company’s service area for the provision of Generation Services to customers who are offered participation by the Smart Meter Pilot Program, Inc (“SMPPI”) who voluntarily enroll in the PowerCentsDC™ Project. This Rider terminates as of February 28, 2010, or as authorized by the District of Columbia Public Service Commission.

GENERAL TERMS AND CONDITIONS

This Rider is subject in all respects to the Company’s “General Terms and Conditions for Furnishing Electric Service” and the Company’s “Electric Service Rules and Regulations.” Customers participating in the Average Payment Plan prior to their participation in this Project may continue to do so when they are billed under this Rider. All other customers choosing to participate in PowerCentsDC™ will not be permitted to join the Average Payment Plan. DESCRIPTION OF PROJECT RATE TYPES Hourly Pricing Option “HP” Applicable to eligible customers selected by SMPPI who are receiving Standard Offer Service (Rider “SOS”) under Schedules “R” and “AE”, and associated riders, except for Residential Aid Discount Rider “RAD”. Under Hourly Pricing, the customer will receive a bill that reflects the hour to hour variation in the wholesale price of electricity. Available from May 2008 through February 2010, or as authorized by the District of Columbia Public Service Commission. Critical Peak Pricing Option “CPP” Applicable to eligible customers selected by SMPPI who are receiving SOS under Schedules “R” and “AE”, and associated riders, except for Residential Aid Discount Rider “RAD”. Under Critical Peak Pricing, the customer’s bill will reflect the value of electricity during certain high cost hours. Available from May 2008 through February 2010, or as authorized by the District of Columbia Public Service Commission. Critical Peak Rebate Option “CPR” Applicable to eligible customers selected by SMPPI who are receiving SOS under Schedules “R”, “AE”, and Rider “RAD”, and associated riders. Under the Critical Peak Rebate option, the customer’s bill will be credited during certain months to reflect the value of load reduced from a designated level during certain high cost hours. Available from May 2008 through February 2010, or as authorized by the District of Columbia Public Service Commission. Opt Out Provision Residential customers that elect the HP, CPP, or CPR shall not change their rate schedule or Project Rate Type nor leave Standard Offer Service while enrolled in the Project. Customers may elect to leave the Project at any time after enrollment by completing a Project Exit Form, which may be obtained by contacting Project customer service at a toll free number that will be provided to participants in marketing materials, educational materials, and bill inserts.




MONTHLY RATE Hourly Pricing Option “HP” The generation portion of the bills for Hourly Pricing (“HP”) customers shall be calculated based on the hourly PJM Pepco DC Day-Ahead Locational Marginal Prices (LMP). When LMP prices exceed the SOS Price (If the date for the hourly price calculation is within June 1 through October 31, the summer SOS rate is used. Otherwise, the winter SOS rate is used.) the hourly price will be determined by applying a LMP Price Factor. The LMP Price Factor is calculated so that the total annual bill for generation for the average customer will be 1.25 percent less than the average customer would pay under the SOS generation rates in effect at the time for a recent annual period, assuming that no changes in the pattern of electricity use occur. The hourly rates are calculated to provide for a small annual savings of 1.25 percent for the average customer due to the risk associated with the trend of increasing wholesale market prices which, all else being equal, is expected to continue in the near-term. The goal is to be close to the revenue neutrality goal without exceeding the SOS revenue. Hourly rates are reviewed each quarter by calculating the annual savings rate for the average customer for a recent annual test period. If this calculation does not result in an annual savings rate between 0 and 2.5 percent, then SMPPI will recalculate the LMP Price Factor so that the annual savings rate equals 1.25 percent. By adjusting the LMP Price Factor quarterly, this will keep the overall annual revenue aligned with the corresponding SOS revenue. The scheduled dates for review are in the table below.

Annual test year period Review Month Effective date of new HP rate

December 2006 to November 2007 February 2008 March 1, 2008 March 2007 to February 2008 May 2008 June 1, 2008 June 2007 to May 2008 August 2008 September 1, 2008 September 2007 to August 2008 November 2008 December 1, 2008 December 2007 to November 2008 February 2009 March 1, 2009 March 2008 to February 2009 May 2009 June 1, 2009 June 2008 to May 2009 August 2009 September 1, 2009 September 2008 to August 2009 November 2009 December 1, 2009

For example, in February 2008, SMPPI analyzed the annual test period from December 1, 2006 through November 30, 2007 and determined that the annual savings rate was outside the range of 0 to 2.5 percent. SMPPI then calculated a new LMP Price Factor effective as of March 1, 2008.


Electric--P.S.C. of D.C. No. 1 DC Fourth Revised Page No. R-44.2


LMP Price Factor The current LMP Price Factor is shown on the Company’s website at www.pepco.com. The hourly PJM day ahead Pepco LMPs are shown on the PJM website at www.pjm.com. Schedule R:

In the following LMP priceh calculations, the R SOS Price = Summer R SOS price if the date falls within June 1 through October 31. Otherwise, R SOS Price = Winter R SOS price.

If the LMP priceh > R SOS price, HP-R hourly priceh = LMP Price Factor (R) * LMP priceh

If the LMP priceh <= R SOS price, HP-R hourly priceh = LMP priceh If the LMP priceh < zero, then the HP-R hourly priceh will be zero.

Schedule AE:

In the following LMP priceh calculations, the AE SOS Price = Summer AE SOS price if the date falls within June 1 through October 31. Otherwise, AE SOS Price = Winter AE SOS price.

If the LMP priceh > AE SOS price, HP-AE hourly priceh = LMP Price Factor (AE) * LMP priceh

If the LMP priceh <= AE SOS price, HP-AE hourly priceh = LMP priceh If the LMP priceh < zero, then the HP-AE hourly priceh will be zero.

LMP Price Factor Calculations The LMP Price Factor (R) is calculated by setting the following ratio = 1.25 percent.

Annual Savings = [(SOS Revenue) – (HP-R Revenue)]/(SOS Revenue) Where:

(a) SOS Revenue = sum of the daily usage for the average R customer times the SOS price in effect for that day for each day in the annual test period.

d = days in annual test period

SOS Revenue =∑(SOS priced * daily usaged) d = 1

For days in the annual test period from June 1 through October 31, the

Summer SOS price for R customers is used. For days in the annual test period from November 1 through May 31, the

Winter SOS price for R customers is used. (b) HP-R Revenue = sum of the hourly usage for the average R customer times the HP-R hourly price for each hour in the annual test period.

h = hours in annual test period HP-R Revenue = ∑(HP-R hourly priceh * hourly usageh)

h = 1




The LMP Price Factor (AE) is calculated by setting the following ratio = 1.25 percent.

Annual Savings = [(SOS Revenue) – (HP-AE Revenue)]/(SOS Revenue) Where:

(a) SOS Revenue = sum of the daily usage for the average AE customer times the SOS price in effect for that day for each day in the annual test period.

d = days in annual test period

SOS Revenue =∑(SOS priced * daily usaged) d = 1

For days in the annual test period from June 1 through October 31, the

Summer SOS price for AE customers is used. For days in the annual test period from November 1 through May 31, the

Winter SOS price for AE customers is used. (b) HP-AE Revenue = sum of the hourly usage for the average AE customer times the HP-AE hourly price for each hour in the annual test period.

h = hours in annual test period HP-AE Revenue = ∑(HP-AE hourly priceh * hourly usageh)

h = 1 Hourly Minimum Bill Charge

Schedule R: Summer: (effective June 1 through October 31) Minimum bill charge = Schedule R summer minimum bill charge

Winter: (effective November 1 through May 31) Minimum bill charge = Schedule R winter minimum bill charge Schedule AE: Summer: (effective June 1 through October 31) Minimum bill charge = Schedule AE summer minimum bill charge

Winter: (effective November 1 through May 31) Minimum bill charge = Schedule AE winter minimum bill charge

Critical Peak Pricing Option “CPP” The generation portion of the bills for Critical Peak Pricing (“CPP”) customers shall be based on a CPP price for use during critical peak hours, and a non-CPP price that is lower than the applicable SOS price during non-critical peak hours. The CPP and non-CPP prices are calculated so that the total annual bill for generation is the same as the average customer would pay under the SOS generation rates for the annual test period from February 1, 2008 to January 31, 2009, assuming that no changes in the pattern of electricity use occur. The CPP and non-CPP prices are:

Schedule R: Summer: (effective June 1 through October 31)

CPP price: $0.83 per kWh Non-CPP price: $0.10654 per kWh Minimum charge = $3.37 per month




Winter: (effective November 1 through May 31) CPP price: $0.79 per kWh Non-CPP price: $0.09759 per kWh Minimum charge = $3.23 per month

Schedule AE: Summer: (effective June 1 through October 31)

CPP price: $0.79 per kWh Non-CPP price: $0.10751 per kWh Minimum charge = $3.35 per month

Winter: (effective November 1 through May 31) CPP price: $0.74 per kWh Non-CPP price: $0.09678 per kWh Minimum charge = $3.14 per month

Critical Peak Rebate Option “CPR” Customers who reduce use during critical peak hours will be paid rebates calculated using the following Critical Peak Rebate Adjustment Rates (CPRARs):

Schedule R: Summer: (effective June 1 through October 31): $0.76 per kWh Winter: (effective November 1 through May 31): $0.35 per kWh

Schedule AE: Summer: (effective June 1 through October 31): $0.77 per kWh Winter: (effective November 1 through May 31): $0.40 per kWh

Schedule RAD: Summer: (effective June 1 through October 31): $1.65 per kWh Winter: (effective November 1 through May 31): $1.00 per kWh

Schedule RAD-AE: Summer: (effective June 1 through October 31): $1.65 per kWh Winter: (effective November 1 through May 31): $1.22 per kWh

MONTHLY GENERATION CHARGE CALCULATION Hourly Pricing Option “HP” The smart metering installed at the customer premises will measure the hourly use. The generation portion of the bill is calculated by multiplying the measured hourly use by the hourly price for the corresponding hour to determine the bill amount for each hour. The bill amounts for each hour within the billing period are then added together to create the monthly generation energy charge. If the generation energy charge is less than the minimum charge for generation service specified above, then the minimum charge will be applied and the generation energy charges shall be set to zero. Critical Peak Pricing Option “CPP” The smart metering installed at the customer premises will measure the hourly use. The CPP use equals the sum of the measured hourly use in the critical peak hours of the billing period. The non-CPP use equals the sum of the measured hourly use in the non-critical peak hours of the billing period.


Electric--P.S.C. of D.C. No. 1 DC First Revised Page No. R-44.5


The generation energy charge for the bill equals: (CPP use * CPP price) + (non-CPP use * non-CPP price). If the generation energy charge is less than the minimum charge for generation service specified above, then the minimum charge shall be applied and the generation energy charges shall be set to zero. Critical Peak Rebate Option “CPR” For Critical Peak Rebate (“CPR”) customer participants, bills shall be calculated based on Standard Offer Service, with an adjustment based on a rebate for a reduction in use during the critical peak hours. The adjustment is calculated by subtracting the Critical Peak Rebate Amount (“CPRA”) from the total monthly bill. The CPRA shall be calculated by subtracting the customer’s use during critical peak hours of the billing period from the Customer Baseline Level (CBL), then multiplying the result times the applicable CPRA Rate (“CPRAR”). The CBL shall be calculated as the average of the customer’s use during the similar critical peak hours for the three days with the highest use during that time in that billing period. Weekends, holidays and critical peak days are not included in this calculation. The CPRA calculation is summarized as follows:

CPRA = (CBL – Use during Critical Peak Events) * CPRAR CRITICAL PEAK SEASONS The critical peak seasons define the periods in which critical peak events may be called by SMPPI and are independent of billing cycles. Summer - Summer is defined for CPP and CPR customers as June 1 through October 31, wherein there will be 12 critical peak events. SMPPI plans to call the summer events in the months of June through September. Events may be called, including but not limited to, when day-ahead LMP prices are higher than normal or temperatures are high. Winter - Winter is defined for CPP and CPR customers as November 1 through May 31, wherein there will be 3 critical peak events. SMPPI plans to call the winter events in the months of November through February. Events may be called, including but not limited to, when day ahead LMP prices are higher than normal or temperatures are low. CRITICAL PEAK HOURS Summer Summer critical peak hours are weekdays, 2 p.m. to 6 p.m. Winter Winter critical peak hours are weekdays, 6 a.m. to 8 a.m. and 6 p.m. to 8 p.m. CRITICAL PEAK HOLIDAYS For the purpose of this tariff, holidays will be all Federal holidays: New Year’s Day, Rev. Martin Luther King’s Birthday, Presidents’ Day, Memorial Day, Independence Day, Labor Day, Columbus Day, Veterans’ Day, Thanksgiving Day, and Christmas Day. No critical peak event shall be called on a Holiday. INTERVAL METER REQUIREMENT All customers electing service under the Rider PCDC are required to have interval meters, furnished by the Company. Customers without interval billing meters that are enrolled in the Project shall have installed an interval billing meter by the Company before such customers are placed on the applicable Rider PCDC rate option.


Electric--P.S.C. of D.C. No. 1 DC First Revised Page No. 44.6


NOTIFICATION Hourly Pricing HP rates for each 24 hour period, from midnight to midnight, shall be posted on the PowerCentsDC™ website, www.PowerCentsDC.org, by 7 p.m. of the prior day. In addition, customers will receive an automated phone call, email, or text page, at the customer’s option, notifying them when hourly prices the next day are high. Other notification may be available at SMPPI’s option. Customers may also contact the project’s customer service at a toll free number that will be provided to participants in marketing materials, educational materials, and bill inserts to obtain hourly pricing information. Critical Peak Pricing By 7 p.m. of the day prior to an event, customers will receive an automated phone call, email, or text page, or combination thereof, at the customer’s option, notifying them that a critical peak event will occur on the following day. Other notification may be available at SMPPI’s option. Customers may also contact the project’s customer service at a toll free number that will be provided to participants in marketing materials, educational materials, and bill inserts to obtain event information. Critical Peak Rebate By 7 p.m. of the day prior to an event, customers will receive an automated phone call, email, or text page, or combination thereof, at the customer’s option, notifying them that a critical peak event will occur on the following day. Other notification may be available at SMPPI’s option. Customers may also contact the project’s customer service at a toll free number that will be provided to participants in marketing materials, educational materials, and bill inserts to obtain event information.


PEPCO (E)-3Page 1 of 11

POTOMAC ELECTRIC POWER COMPANYEXAMPLES COMPARING BILLS UNDER PRESENT AND PROPOSED RESIDENTIAL SERVICE RATESSCHEDULE "R"DISTRICT OF COLUMBIA

PRESENT SCHEDULE R PROPOSED SCHEDULE R KWH kW $ AMOUNT OF BILL $/KWH $ AMOUNT OF BILL $/KWH ($) ($) (%) (%) ($) (%)

SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER ANNUAL ANNUAL

0 - 17.30$ 17.49$ - - 17.30$ 17.49$ - - 0.00 0.00 0.00% 0.00% 0.00 0.00%10 0.02 17.49$ 17.68$ 1.74897 1.76797 17.51$ 17.70$ 1.75136 1.77036 0.02 0.02 0.11% 0.11% 0.02 0.11%20 0.03 17.68$ 17.87$ 0.88397 0.89347 17.73$ 17.92$ 0.88636 0.89586 0.05 0.05 0.28% 0.28% 0.05 0.28%30 0.05 17.87$ 18.06$ 0.59563 0.60197 17.94$ 18.13$ 0.59802 0.60436 0.07 0.07 0.39% 0.39% 0.07 0.39%40 0.07 18.82$ 19.07$ 0.47053 0.47685 19.44$ 19.70$ 0.48609 0.49241 0.62 0.62 3.29% 3.25% 0.62 3.27%50 0.08 19.77$ 20.09$ 0.39546 0.40179 20.55$ 20.87$ 0.41102 0.41735 0.78 0.78 3.94% 3.88% 0.78 3.91%

100 0.17 24.53$ 25.17$ 0.24533 0.25165 26.09$ 26.72$ 0.26089 0.26721 1.56 1.56 6.36% 6.20% 1.56 6.26%200 0.33 34.05$ 35.32$ 0.17027 0.17658 37.17$ 38.43$ 0.18583 0.19214 3.11 3.11 9.13% 8.81% 3.11 8.94%300 0.50 43.57$ 45.47$ 0.14525 0.15156 48.24$ 50.14$ 0.16081 0.16712 4.67 4.67 10.72% 10.27% 4.67 10.45%400 0.66 53.10$ 55.62$ 0.13274 0.13905 59.32$ 61.84$ 0.14830 0.15461 6.22 6.22 11.71% 11.18% 6.22 11.40%500 0.83 64.02$ 66.52$ 0.12805 0.13305 70.40$ 73.55$ 0.14079 0.14710 6.37 7.03 9.95% 10.57% 6.76 10.32%600 0.99 74.95$ 77.43$ 0.12492 0.12905 81.47$ 85.26$ 0.13579 0.14210 6.52 7.83 8.70% 10.11% 7.28 9.53%

648 1.07 80.20$ 82.66$ 0.12376 0.12757 86.79$ 90.88$ 0.13393 0.14024 6.59 8.22 8.22% 9.94% 7.54 9.24%650 1.07 80.41$ 82.88$ 0.12371 0.12751 87.01$ 91.11$ 0.13386 0.14017 6.60 8.23 8.21% 9.93% 7.55 9.22%700 1.16 85.88$ 88.33$ 0.12268 0.12619 92.55$ 96.97$ 0.13221 0.13852 6.67 8.63 7.77% 9.77% 7.81 8.95%750 1.24 91.34$ 93.79$ 0.12179 0.12505 98.09$ 102.82$ 0.13078 0.13709 6.75 9.03 7.39% 9.63% 8.08 8.71%800 1.32 96.81$ 99.24$ 0.12101 0.12405 103.63$ 108.67$ 0.12953 0.13584 6.82 9.44 7.05% 9.51% 8.35 8.50%850 1.40 102.27$ 104.69$ 0.12032 0.12317 109.16$ 114.53$ 0.12843 0.13474 6.89 9.84 6.74% 9.40% 8.61 8.31%900 1.49 107.73$ 110.14$ 0.11970 0.12238 114.70$ 120.38$ 0.12745 0.13376 6.97 10.24 6.47% 9.30% 8.88 8.13%950 1.57 113.20$ 115.60$ 0.11915 0.12168 120.24$ 126.24$ 0.12657 0.13288 7.04 10.64 6.22% 9.20% 9.14 7.98%

1,000 1.65 118.66$ 121.05$ 0.11866 0.12105 125.78$ 132.09$ 0.12578 0.13209 7.12 11.04 6.00% 9.12% 9.41 7.84%1,250 2.06 145.98$ 148.31$ 0.11678 0.11865 153.47$ 161.36$ 0.12278 0.12909 7.49 13.05 5.13% 8.80% 10.73 7.28%1,500 2.48 173.30$ 175.57$ 0.11553 0.11705 181.16$ 190.63$ 0.12077 0.12708 7.86 15.06 4.54% 8.58% 12.06 6.91%1,750 2.89 200.62$ 202.83$ 0.11464 0.11590 208.85$ 219.90$ 0.11934 0.12565 8.23 17.06 4.10% 8.41% 13.38 6.63%2,000 3.30 227.94$ 230.09$ 0.11397 0.11505 236.54$ 249.16$ 0.11827 0.12458 8.61 19.07 3.78% 8.29% 14.71 6.42%2,250 3.72 255.26$ 257.36$ 0.11345 0.11438 264.24$ 278.43$ 0.11744 0.12375 8.98 21.08 3.52% 8.19% 16.04 6.25%

2,500 4.13 282.58$ 284.62$ 0.11303 0.11385 291.93$ 307.70$ 0.11677 0.12308 9.35 23.09 3.31% 8.11% 17.37 6.12%3,000 4.96 337.21$ 339.14$ 0.11240 0.11305 347.31$ 366.24$ 0.11577 0.12208 10.10 27.10 3.00% 7.99% 20.02 5.92%3,500 5.78 391.85$ 393.66$ 0.11196 0.11248 402.69$ 424.78$ 0.11506 0.12137 10.84 31.12 2.77% 7.91% 22.67 5.77%4,000 6.61 446.49$ 448.19$ 0.11162 0.11205 458.08$ 483.32$ 0.11452 0.12083 11.59 35.13 2.60% 7.84% 25.32 5.66%5,000 8.26 555.77$ 557.23$ 0.11115 0.11145 568.84$ 600.39$ 0.11377 0.12008 13.08 43.16 2.35% 7.75% 30.63 5.50%

SUMMER WINTER SUMMER WINTER*

Customer & Minimum Charges 17.30 17.49 17.30 17.49Demand Charge 1.45 1.45

First 30 0.01897 0.01897 0.03214 0.03214Next 370 0.09521 0.10152 0.10838 0.11469In excess of 400 kWh 0.10928 0.10905 0.10838 0.11469

* Includes Distribution Customer Charge, Generation Minimum Charge and Transmission Minimum Charge1.07

647.45

BLOCKPRESENT PROPOSED

INCREASE


POTOMAC ELECTRIC POWER COMPANYEXAMPLES COMPARING BILLS UNDER PRESENT AND PROPOSED MASTER-METERED APARTMENT SERVICE RATESSCHEDULE "MMA" - per Dwelling UnitDISTRICT OF COLUMBIA

PRESENT SCHEDULE MMA PROPOSED SCHEDULE MMA KWH $ AMOUNT OF BILL $/KWH $ AMOUNT OF BILL $/KWH ($) ($) (%) (%) ($) (%)


0 - 14.05$ 14.24$ - - 15.92$ 16.11$ - - 1.87 1.87 13.31% 13.13% 1.87 13.21%10 0.02 14.24$ 14.43$ 1.42397 1.44297 16.11$ 16.30$ 1.61097 1.62997 1.87 1.87 13.13% 12.96% 1.87 13.03%20 0.03 14.43$ 14.62$ 0.72147 0.73097 16.30$ 16.49$ 0.81497 0.82447 1.87 1.87 12.96% 12.79% 1.87 12.86%30 0.05 14.62$ 14.81$ 0.48730 0.49363 16.49$ 16.68$ 0.54963 0.55597 1.87 1.87 12.79% 12.63% 1.87 12.70%40 0.07 15.57$ 15.82$ 0.38928 0.39560 17.55$ 17.80$ 0.43871 0.44503 1.98 1.98 12.72% 12.51% 1.98 12.60%50 0.08 16.52$ 16.84$ 0.33046 0.33679 18.53$ 18.84$ 0.37054 0.37687 2.00 2.00 12.10% 11.88% 2.00 11.97%

100 0.17 21.28$ 21.92$ 0.21283 0.21915 23.42$ 24.05$ 0.23421 0.24053 2.14 2.14 10.05% 9.76% 2.14 9.88%200 0.33 30.80$ 32.07$ 0.15402 0.16033 33.21$ 34.47$ 0.16605 0.17236 2.41 2.41 7.82% 7.52% 2.41 7.64%300 0.50 40.32$ 42.22$ 0.13442 0.14073 43.00$ 44.89$ 0.14333 0.14964 2.67 2.67 6.62% 6.32% 2.67 6.44%400 0.66 49.85$ 52.37$ 0.12461 0.13092 52.79$ 55.31$ 0.13197 0.13828 2.94 2.94 5.90% 5.61% 2.94 5.73%500 0.83 60.77$ 63.27$ 0.12155 0.12655 64.48$ 66.75$ 0.12896 0.13350 3.71 3.48 6.10% 5.50% 3.58 5.75%600 0.99 71.70$ 74.18$ 0.11950 0.12363 76.17$ 78.19$ 0.12695 0.13031 4.47 4.01 6.23% 5.41% 4.20 5.74%

650 1.07 77.16$ 79.63$ 0.11871 0.12251 82.02$ 83.91$ 0.12618 0.12909 4.85 4.27 6.29% 5.36% 4.51 5.74%675 1.12 79.90$ 82.36$ 0.11836 0.12201 84.94$ 86.77$ 0.12584 0.12854 5.04 4.41 6.31% 5.35% 4.67 5.74%700 1.16 82.63$ 85.08$ 0.11804 0.12155 87.86$ 89.62$ 0.12552 0.12804 5.23 4.54 6.33% 5.34% 4.83 5.74%750 1.24 88.09$ 90.54$ 0.11746 0.12071 93.71$ 95.34$ 0.12494 0.12712 5.62 4.81 6.38% 5.31% 5.15 5.75%800 1.32 93.56$ 95.99$ 0.11694 0.11999 99.55$ 101.06$ 0.12444 0.12633 6.00 5.07 6.41% 5.28% 5.46 5.75%850 1.41 99.02$ 101.44$ 0.11649 0.11934 105.40$ 106.78$ 0.12400 0.12563 6.38 5.34 6.44% 5.26% 5.77 5.75%900 1.49 104.48$ 106.89$ 0.11609 0.11877 111.25$ 112.50$ 0.12361 0.12500 6.76 5.61 6.47% 5.25% 6.09 5.75%950 1.57 109.95$ 112.35$ 0.11573 0.11826 117.09$ 118.22$ 0.12325 0.12444 7.14 5.87 6.49% 5.22% 6.40 5.75%

1,000 1.65 115.41$ 117.80$ 0.11541 0.11780 122.94$ 123.94$ 0.12294 0.12394 7.53 6.14 6.52% 5.21% 6.72 5.75%1,250 2.07 142.73$ 145.06$ 0.11418 0.11605 152.17$ 152.53$ 0.12173 0.12203 9.44 7.47 6.61% 5.15% 8.29 5.75%1,500 2.48 170.05$ 172.32$ 0.11337 0.11488 181.40$ 181.13$ 0.12093 0.12075 11.35 8.81 6.67% 5.11% 9.87 5.76%1,750 2.89 197.37$ 199.58$ 0.11278 0.11405 210.62$ 209.72$ 0.12036 0.11984 13.26 10.14 6.72% 5.08% 11.44 5.76%2,000 3.31 224.69$ 226.84$ 0.11234 0.11342 239.85$ 238.31$ 0.11993 0.11916 15.17 11.47 6.75% 5.06% 13.01 5.76%2,250 3.72 252.01$ 254.11$ 0.11200 0.11294 269.08$ 266.91$ 0.11959 0.11863 17.08 12.80 6.78% 5.04% 14.58 5.76%

2,500 4.13 279.33$ 281.37$ 0.11173 0.11255 298.31$ 295.50$ 0.11932 0.11820 18.99 14.14 6.80% 5.03% 16.16 5.76%3,000 4.96 333.96$ 335.89$ 0.11132 0.11196 356.77$ 352.69$ 0.11892 0.11756 22.81 16.80 6.83% 5.00% 19.30 5.76%3,500 5.79 388.60$ 390.41$ 0.11103 0.11155 415.23$ 409.88$ 0.11864 0.11711 26.63 19.47 6.85% 4.99% 22.45 5.76%4,000 6.61 443.24$ 444.94$ 0.11081 0.11123 473.69$ 467.07$ 0.11842 0.11677 30.45 22.13 6.87% 4.97% 25.60 5.76%5,000 8.27 552.52$ 553.98$ 0.11050 0.11080 590.60$ 581.44$ 0.11812 0.11629 38.09 27.46 6.89% 4.96% 31.89 5.76%

SUMMER WINTER SUMMER WINTER*

Customer & Minimum Charges 14.05 14.24 15.92 16.11Demand Charge 0.00 0.00

First 30 0.01897 0.01897 0.02165 0.02165Next 370 0.09521 0.10152 0.09789 0.10420In excess of 400 kWh 0.10928 0.10905 0.11692 0.11438

* Includes Distribution Customer Charge, Generation Minimum Charge and Transmission Minimum Charge1.12

INCREASE (PER DWELLING UNIT)

PRESENT PROPOSEDBLOCK


POTOMAC ELECTRIC POWER COMPANYEXAMPLES COMPARING BILLS UNDER PRESENT AND PROPOSED GENERAL SERVICE RATESSCHEDULE "GS ND"DISTRICT OF COLUMBIA

PRESENT GS_ND PROPOSED GS_ND KWH $ AMOUNT OF BILL $/KWH $ AMOUNT OF BILL $/KWH ($) ($) (%) (%) ($) (%)


0 27.42 27.42 - - 33.99 33.99 - - 6.57 6.57 23.96% 23.96% 6.57 23.96%10 28.59 28.56 2.85900 2.85600 35.29 35.24 3.52900 3.52400 6.70 6.68 23.43% 23.39% 6.69 23.41%20 29.76 29.70 1.48800 1.48500 36.60 36.48 1.83000 1.82400 6.84 6.78 22.98% 22.83% 6.81 22.89%30 30.93 30.84 1.03100 1.02800 37.90 37.73 1.26333 1.25767 6.97 6.89 22.53% 22.34% 6.92 22.42%40 32.10 31.98 0.80250 0.79950 39.20 38.97 0.98000 0.97425 7.10 6.99 22.12% 21.86% 7.04 21.97%50 33.27 33.12 0.66540 0.66240 40.51 40.22 0.81020 0.80440 7.24 7.10 21.76% 21.44% 7.16 21.57%

100 39.11 38.83 0.39110 0.38830 47.02 46.45 0.47020 0.46450 7.91 7.62 20.23% 19.62% 7.74 19.88%150 44.96 44.53 0.29973 0.29687 53.54 52.67 0.35693 0.35113 8.58 8.14 19.08% 18.28% 8.32 18.62%200 50.80 50.23 0.25400 0.25115 60.06 58.90 0.30030 0.29450 9.26 8.67 18.23% 17.26% 8.92 17.67%250 56.65 55.93 0.22660 0.22372 66.57 65.13 0.26628 0.26052 9.92 9.20 17.51% 16.45% 9.50 16.89%300 62.49 61.64 0.20830 0.20547 73.09 71.36 0.24363 0.23787 10.60 9.72 16.96% 15.77% 10.09 16.27%400 74.18 73.04 0.18545 0.18260 86.12 83.82 0.21530 0.20955 11.94 10.78 16.10% 14.76% 11.26 15.32%

500 85.87 84.45 0.17174 0.16890 99.15 96.27 0.19830 0.19254 13.28 11.82 15.47% 14.00% 12.43 14.61%600 97.56 95.85 0.16260 0.15975 112.19 108.73 0.18698 0.18122 14.63 12.88 15.00% 13.44% 13.61 14.09%700 109.25 107.26 0.15607 0.15323 125.22 121.19 0.17889 0.17313 15.97 13.93 14.62% 12.99% 14.78 13.67%800 120.94 118.66 0.15118 0.14833 138.25 133.64 0.17281 0.16705 17.31 14.98 14.31% 12.62% 15.95 13.34%900 132.64 130.07 0.14738 0.14452 151.28 146.10 0.16809 0.16233 18.64 16.03 14.05% 12.32% 17.12 13.05%

1,000 144.33 141.48 0.14433 0.14148 164.32 158.56 0.16432 0.15856 19.99 17.08 13.85% 12.07% 18.29 12.82%

1,250 173.55 169.99 0.13884 0.13599 196.90 189.70 0.15752 0.15176 23.35 19.71 13.45% 11.59% 21.23 12.38%1,500 202.78 198.50 0.13519 0.13233 229.48 220.84 0.15299 0.14723 26.70 22.34 13.17% 11.25% 24.16 12.06%1,750 232.01 227.02 0.13258 0.12973 262.06 251.98 0.14975 0.14399 30.05 24.96 12.95% 10.99% 27.08 11.82%2,000 261.23 255.53 0.13062 0.12777 294.64 283.12 0.14732 0.14156 33.41 27.59 12.79% 10.80% 30.02 11.64%2,500 319.69 312.56 0.12788 0.12502 359.81 345.41 0.14392 0.13816 40.12 32.85 12.55% 10.51% 35.88 11.37%3,000 378.14 369.59 0.12605 0.12320 424.97 407.69 0.14166 0.13590 46.83 38.10 12.38% 10.31% 41.74 11.19%

3,500 436.59 426.62 0.12474 0.12189 490.13 469.97 0.14004 0.13428 53.54 43.35 12.26% 10.16% 47.60 11.05%4,000 495.04 483.64 0.12376 0.12091 555.29 532.25 0.13882 0.13306 60.25 48.61 12.17% 10.05% 53.46 10.95%5,000 611.95 597.70 0.12239 0.11954 685.62 656.82 0.13712 0.13136 73.67 59.12 12.04% 9.89% 65.18 10.80%6,000 728.86 711.76 0.12148 0.11863 815.95 781.39 0.13599 0.13023 87.09 69.63 11.95% 9.78% 76.91 10.70%

SUMMER WINTER SUMMER WINTERCUSTOMER 27.42 27.42 33.99 33.99ENERGY (kWh)

0.11691 0.11406 0.13033 0.12457

PRESENT PROPOSED

All Kilowatt-hours

INCREASE


POTOMAC ELECTRIC POWER COMPANYEXAMPLES COMPARING BILLS UNDER PRESENT AND PROPOSED GENERAL SERVICE RATESSCHEDULE "GS D LV"DISTRICT OF COLUMBIA

PRESENT GS_D_LV PROPOSED GS_D_LV INCREASEKW Hours Use KWH $ AMOUNT OF BILL $/KWH $ AMOUNT OF BILL $/KWH ($) ($) (%) (%)

SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER SUMMER WINTER

10 100 1000 233.59 233.04 0.23359 0.23304 257.56 257.81 0.25756 0.25781 23.97 24.77 10.26% 10.63%10 200 2000 345.60 344.50 0.17280 0.17225 366.28 366.78 0.18314 0.18339 20.68 22.28 5.98% 6.47%10 300 3000 457.62 455.97 0.15254 0.15199 475.01 475.76 0.15834 0.15859 17.39 19.79 3.80% 4.34%10 400 4000 569.63 567.43 0.14241 0.14186 583.73 584.73 0.14593 0.14618 14.10 17.30 2.48% 3.05%10 500 5000 681.65 678.90 0.13633 0.13578 692.46 693.71 0.13849 0.13874 10.81 14.81 1.59% 2.18%10 600 6000 793.67 790.37 0.13228 0.13173 801.19 802.69 0.13353 0.13378 7.52 12.32 0.95% 1.56%

25 100 2,500 531.21 529.84 0.21248 0.21193 577.25 577.87 0.23090 0.23115 46.04 48.04 8.67% 9.07%25 200 5,000 811.25 808.50 0.16225 0.16170 849.06 850.31 0.16981 0.17006 37.81 41.81 4.66% 5.17%25 300 7,500 1,091.29 1,087.17 0.14551 0.14496 1,120.88 1,122.75 0.14945 0.14970 29.59 35.59 2.71% 3.27%25 400 10,000 1,371.33 1,365.83 0.13713 0.13658 1,392.69 1,395.19 0.13927 0.13952 21.36 29.36 1.56% 2.15%25 500 12,500 1,651.37 1,644.50 0.13211 0.13156 1,664.51 1,667.63 0.13316 0.13341 13.14 23.14 0.80% 1.41%25 600 15,000 1,931.41 1,923.16 0.12876 0.12821 1,936.32 1,940.07 0.12909 0.12934 4.91 16.91 0.25% 0.88%

50 100 5,000 1,027.25 1,024.50 0.20545 0.20490 1,110.06 1,111.31 0.22201 0.22226 82.81 86.81 8.06% 8.47%50 200 10,000 1,587.33 1,581.83 0.15873 0.15818 1,653.69 1,656.19 0.16537 0.16562 66.36 74.36 4.18% 4.70%50 300 15,000 2,147.41 2,139.16 0.14316 0.14261 2,197.32 2,201.07 0.14649 0.14674 49.91 61.91 2.32% 2.89%50 400 20,000 2,707.49 2,696.49 0.13537 0.13482 2,740.95 2,745.95 0.13705 0.13730 33.46 49.46 1.24% 1.83%50 500 25,000 3,267.58 3,253.83 0.13070 0.13015 3,284.59 3,290.84 0.13138 0.13163 17.01 37.01 0.52% 1.14%50 600 30,000 3,827.66 3,811.16 0.12759 0.12704 3,828.22 3,835.72 0.12761 0.12786 0.56 24.56 0.01% 0.64%

75 100 7,500 1,523.29 1,519.17 0.20311 0.20256 1,642.88 1,644.75 0.21905 0.21930 119.59 125.59 7.85% 8.27%75 200 15,000 2,363.41 2,355.16 0.15756 0.15701 2,458.32 2,462.07 0.16389 0.16414 94.91 106.91 4.02% 4.54%75 300 22,500 3,203.53 3,191.16 0.14238 0.14183 3,273.77 3,279.39 0.14550 0.14575 70.23 88.23 2.19% 2.76%75 400 30,000 4,043.66 4,027.16 0.13479 0.13424 4,089.22 4,096.72 0.13631 0.13656 45.56 69.56 1.13% 1.73%75 500 37,500 4,883.78 4,863.15 0.13023 0.12968 4,904.66 4,914.04 0.13079 0.13104 20.88 50.89 0.43% 1.05%75 600 45,000 5,723.90 5,699.15 0.12720 0.12665 5,720.11 5,731.36 0.12711 0.12736 -3.79 32.21 -0.07% 0.57%

SUMMER WINTER SUMMER WINTERCUSTOMER 35.17 35.17 44.43 44.43ENERGY (kWh) 0.11202 0.11147 0.10873 0.10898DEMAND (kW) 8.64 8.64 10.44 10.44

PRESENT PROPOSED


POTOMAC ELECTRIC POWER COMPANYEXAMPLES COMPARING BILLS UNDER PRESENT AND PROPOSED TIME METERED GENERAL SERVICE RATESSCHEDULE "GT LV " - DELIVERY ONLYDISTRICT OF COLUMBIA

PRESENT 'GT-LV' PROPOSED 'GT- LV' INCREASEKW Hours Use KWH $ AMOUNT OF BILL $/KWH $ AMOUNT OF BILL $/KWH ($) ($) (%) (%)


100 200 20,000 2,030.28 2,030.28 0.10151 0.10151 2,406.14 2,406.14 0.12031 0.12031 375.86 375.86 18.51% 18.51%100 300 30,000 2,243.55 2,243.55 0.07479 0.07479 2,658.21 2,658.21 0.08861 0.08861 414.66 414.66 18.48% 18.48%100 400 40,000 2,456.81 2,456.81 0.06142 0.06142 2,910.27 2,910.27 0.07276 0.07276 453.46 453.46 18.46% 18.46%100 500 50,000 2,670.07 2,670.07 0.05340 0.05340 3,162.33 3,162.33 0.06325 0.06325 492.26 492.26 18.44% 18.44%100 600 60,000 2,883.33 2,883.33 0.04806 0.04806 3,414.39 3,414.39 0.05691 0.05691 531.06 531.06 18.42% 18.42%

300 200 60,000 5,177.33 5,177.33 0.08629 0.08629 6,182.39 6,182.39 0.10304 0.10304 1,005.06 1,005.06 19.41% 19.41%300 300 90,000 5,817.12 5,817.12 0.06463 0.06463 6,938.58 6,938.58 0.07710 0.07710 1,121.46 1,121.46 19.28% 19.28%300 400 120,000 6,456.90 6,456.90 0.05381 0.05381 7,694.76 7,694.76 0.06412 0.06412 1,237.86 1,237.86 19.17% 19.17%300 500 150,000 7,096.69 7,096.69 0.04731 0.04731 8,450.95 8,450.95 0.05634 0.05634 1,354.26 1,354.26 19.08% 19.08%300 600 180,000 7,736.48 7,736.48 0.04298 0.04298 9,207.14 9,207.14 0.05115 0.05115 1,470.66 1,470.66 19.01% 19.01%

500 200 100,000 8,324.38 8,324.38 0.08324 0.08324 9,958.64 9,958.64 0.09959 0.09959 1,634.26 1,634.26 19.63% 19.63%500 300 150,000 9,390.69 9,390.69 0.06260 0.06260 11,218.95 11,218.95 0.07479 0.07479 1,828.26 1,828.26 19.47% 19.47%500 400 200,000 10,457.00 10,457.00 0.05229 0.05229 12,479.26 12,479.26 0.06240 0.06240 2,022.26 2,022.26 19.34% 19.34%500 500 250,000 11,523.31 11,523.31 0.04609 0.04609 13,739.57 13,739.57 0.05496 0.05496 2,216.26 2,216.26 19.23% 19.23%500 600 300,000 12,589.62 12,589.62 0.04197 0.04197 14,999.88 14,999.88 0.05000 0.05000 2,410.26 2,410.26 19.14% 19.14%

1000 200 200,000 16,192.00 16,192.00 0.08096 0.08096 19,399.26 19,399.26 0.09700 0.09700 3,207.26 3,207.26 19.81% 19.81%1000 300 300,000 18,324.62 18,324.62 0.06108 0.06108 21,919.88 21,919.88 0.07307 0.07307 3,595.26 3,595.26 19.62% 19.62%1000 400 400,000 20,457.24 20,457.24 0.05114 0.05114 24,440.50 24,440.50 0.06110 0.06110 3,983.26 3,983.26 19.47% 19.47%1000 500 500,000 22,589.86 22,589.86 0.04518 0.04518 26,961.12 26,961.12 0.05392 0.05392 4,371.26 4,371.26 19.35% 19.35%1000 600 600,000 24,722.48 24,722.48 0.04120 0.04120 29,481.74 29,481.74 0.04914 0.04914 4,759.26 4,759.26 19.25% 19.25%

2000 200 400,000 31,927.24 31,927.24 0.07982 0.07982 38,280.50 38,280.50 0.09570 0.09570 6,353.26 6,353.26 19.90% 19.90%2000 300 600,000 36,192.48 36,192.48 0.06032 0.06032 43,321.74 43,321.74 0.07220 0.07220 7,129.26 7,129.26 19.70% 19.70%2000 400 800,000 40,457.72 40,457.72 0.05057 0.05057 48,362.98 48,362.98 0.06045 0.06045 7,905.26 7,905.26 19.54% 19.54%2000 500 1,000,000 44,722.96 44,722.96 0.04472 0.04472 53,404.22 53,404.22 0.05340 0.05340 8,681.26 8,681.26 19.41% 19.41%2000 600 1,200,000 48,988.20 48,988.20 0.04082 0.04082 58,445.46 58,445.46 0.04870 0.04870 9,457.26 9,457.26 19.31% 19.31%

4000 200 800,000 63,397.72 63,397.72 0.07925 0.07925 76,042.98 76,042.98 0.09505 0.09505 12,645.26 12,645.26 19.95% 19.95%4000 300 1,200,000 71,928.20 71,928.20 0.05994 0.05994 86,125.46 86,125.46 0.07177 0.07177 14,197.26 14,197.26 19.74% 19.74%4000 400 1,600,000 80,458.68 80,458.68 0.05029 0.05029 96,207.94 96,207.94 0.06013 0.06013 15,749.26 15,749.26 19.57% 19.57%4000 500 2,000,000 88,989.16 88,989.16 0.04449 0.04449 106,290.42 106,290.42 0.05315 0.05315 17,301.26 17,301.26 19.44% 19.44%4000 600 2,400,000 97,519.64 97,519.64 0.04063 0.04063 116,372.90 116,372.90 0.04849 0.04849 18,853.26 18,853.26 19.33% 19.33%

6000 200 1,200,000 94,868.20 94,868.20 0.07906 0.07906 113,805.46 113,805.46 0.09484 0.09484 18,937.26 18,937.26 19.96% 19.96%6000 300 1,800,000 107,663.92 107,663.92 0.05981 0.05981 128,929.18 128,929.18 0.07163 0.07163 21,265.26 21,265.26 19.75% 19.75%6000 400 2,400,000 120,459.64 120,459.64 0.05019 0.05019 144,052.90 144,052.90 0.06002 0.06002 23,593.26 23,593.26 19.59% 19.59%6000 500 3,000,000 133,255.36 133,255.36 0.04442 0.04442 159,176.62 159,176.62 0.05306 0.05306 25,921.26 25,921.26 19.45% 19.45%6000 600 3,600,000 146,051.08 146,051.08 0.04057 0.04057 174,300.34 174,300.34 0.04842 0.04842 28,249.26 28,249.26 19.34% 19.34%

8000 200 1,600,000 126,338.68 126,338.68 0.07896 0.07896 151,567.94 151,567.94 0.09473 0.09473 25,229.26 25,229.26 19.97% 19.97%8000 300 2,400,000 143,399.64 143,399.64 0.05975 0.05975 171,732.90 171,732.90 0.07156 0.07156 28,333.26 28,333.26 19.76% 19.76%8000 400 3,200,000 160,460.60 160,460.60 0.05014 0.05014 191,897.86 191,897.86 0.05997 0.05997 31,437.26 31,437.26 19.59% 19.59%8000 500 4,000,000 177,521.56 177,521.56 0.04438 0.04438 212,062.82 212,062.82 0.05302 0.05302 34,541.26 34,541.26 19.46% 19.46%8000 600 4,800,000 194,582.52 194,582.52 0.04054 0.04054 232,227.78 232,227.78 0.04838 0.04838 37,645.26 37,645.26 19.35% 19.35%

PRESENT PROPOSED

SUMMER WINTER SUMMER WINTER CUSTOMER 456.76 456.76 CUSTOMER 518.02 518.02 DEMAND (kW) DEMAND (kW) Maximum 11.4700 11.4700 Maximum 13.8400 13.8400 ENERGY (kWh) ENERGY (kWh) SURCHARGES 0.02133 0.02133 SURCHARGES 0.02521 0.02521


POTOMAC ELECTRIC POWER COMPANYEXAMPLES COMPARING BILLS UNDER PRESENT AND PROPOSED TIME METERED GENERAL SERVICE RATESSCHEDULE "GT 3A " - DELIVERY ONLYDISTRICT OF COLUMBIA

PRESENT 'GT-3A' PROPOSED 'GT- 3A' INCREASEKW Hours Use KWH $ AMOUNT OF BILL $/KWH $ AMOUNT OF BILL $/KWH ($) ($) (%) (%)


100 200 20,000 1,350.76 1,350.76 0.06754 0.06754 1,559.53 1,559.53 0.07798 0.07798 208.77 208.77 15.46% 15.46%100 300 30,000 1,514.33 1,514.33 0.05048 0.05048 1,731.40 1,731.40 0.05771 0.05771 217.07 217.07 14.33% 14.33%100 400 40,000 1,677.89 1,677.89 0.04195 0.04195 1,903.26 1,903.26 0.04758 0.04758 225.37 225.37 13.43% 13.43%100 500 50,000 1,841.45 1,841.45 0.03683 0.03683 2,075.12 2,075.12 0.04150 0.04150 233.67 233.67 12.69% 12.69%100 600 60,000 2,005.01 2,005.01 0.03342 0.03342 2,246.98 2,246.98 0.03745 0.03745 241.97 241.97 12.07% 12.07%

300 200 60,000 3,677.01 3,677.01 0.06128 0.06128 4,270.98 4,270.98 0.07118 0.07118 593.97 593.97 16.15% 16.15%300 300 90,000 4,167.70 4,167.70 0.04631 0.04631 4,786.57 4,786.57 0.05318 0.05318 618.87 618.87 14.85% 14.85%300 400 120,000 4,658.38 4,658.38 0.03882 0.03882 5,302.15 5,302.15 0.04418 0.04418 643.77 643.77 13.82% 13.82%300 500 150,000 5,149.07 5,149.07 0.03433 0.03433 5,817.74 5,817.74 0.03878 0.03878 668.67 668.67 12.99% 12.99%300 600 180,000 5,639.76 5,639.76 0.03133 0.03133 6,333.33 6,333.33 0.03519 0.03519 693.57 693.57 12.30% 12.30%

500 200 100,000 6,003.26 6,003.26 0.06003 0.06003 6,982.43 6,982.43 0.06982 0.06982 979.17 979.17 16.31% 16.31%500 300 150,000 6,821.07 6,821.07 0.04547 0.04547 7,841.74 7,841.74 0.05228 0.05228 1,020.67 1,020.67 14.96% 14.96%500 400 200,000 7,638.88 7,638.88 0.03819 0.03819 8,701.05 8,701.05 0.04351 0.04351 1,062.17 1,062.17 13.90% 13.90%500 500 250,000 8,456.69 8,456.69 0.03383 0.03383 9,560.36 9,560.36 0.03824 0.03824 1,103.67 1,103.67 13.05% 13.05%500 600 300,000 9,274.50 9,274.50 0.03092 0.03092 10,419.67 10,419.67 0.03473 0.03473 1,145.17 1,145.17 12.35% 12.35%

1000 200 200,000 11,818.88 11,818.88 0.05909 0.05909 13,761.05 13,761.05 0.06881 0.06881 1,942.17 1,942.17 16.43% 16.43%1000 300 300,000 13,454.50 13,454.50 0.04485 0.04485 15,479.67 15,479.67 0.05160 0.05160 2,025.17 2,025.17 15.05% 15.05%1000 400 400,000 15,090.12 15,090.12 0.03773 0.03773 17,198.29 17,198.29 0.04300 0.04300 2,108.17 2,108.17 13.97% 13.97%1000 500 500,000 16,725.74 16,725.74 0.03345 0.03345 18,916.91 18,916.91 0.03783 0.03783 2,191.17 2,191.17 13.10% 13.10%1000 600 600,000 18,361.36 18,361.36 0.03060 0.03060 20,635.53 20,635.53 0.03439 0.03439 2,274.17 2,274.17 12.39% 12.39%

2000 200 400,000 23,450.12 23,450.12 0.05863 0.05863 27,318.29 27,318.29 0.06830 0.06830 3,868.17 3,868.17 16.50% 16.50%2000 300 600,000 26,721.36 26,721.36 0.04454 0.04454 30,755.53 30,755.53 0.05126 0.05126 4,034.17 4,034.17 15.10% 15.10%2000 400 800,000 29,992.60 29,992.60 0.03749 0.03749 34,192.77 34,192.77 0.04274 0.04274 4,200.17 4,200.17 14.00% 14.00%2000 500 1,000,000 33,263.84 33,263.84 0.03326 0.03326 37,630.01 37,630.01 0.03763 0.03763 4,366.17 4,366.17 13.13% 13.13%2000 600 1,200,000 36,535.08 36,535.08 0.03045 0.03045 41,067.25 41,067.25 0.03422 0.03422 4,532.17 4,532.17 12.40% 12.40%

4000 200 800,000 46,712.60 46,712.60 0.05839 0.05839 54,432.77 54,432.77 0.06804 0.06804 7,720.17 7,720.17 16.53% 16.53%4000 300 1,200,000 53,255.08 53,255.08 0.04438 0.04438 61,307.25 61,307.25 0.05109 0.05109 8,052.17 8,052.17 15.12% 15.12%4000 400 1,600,000 59,797.56 59,797.56 0.03737 0.03737 68,181.73 68,181.73 0.04261 0.04261 8,384.17 8,384.17 14.02% 14.02%4000 500 2,000,000 66,340.04 66,340.04 0.03317 0.03317 75,056.21 75,056.21 0.03753 0.03753 8,716.17 8,716.17 13.14% 13.14%4000 600 2,400,000 72,882.52 72,882.52 0.03037 0.03037 81,930.69 81,930.69 0.03414 0.03414 9,048.17 9,048.17 12.41% 12.41%

6000 200 1,200,000 69,975.08 69,975.08 0.05831 0.05831 81,547.25 81,547.25 0.06796 0.06796 11,572.17 11,572.17 16.54% 16.54%6000 300 1,800,000 79,788.80 79,788.80 0.04433 0.04433 91,858.97 91,858.97 0.05103 0.05103 12,070.17 12,070.17 15.13% 15.13%6000 400 2,400,000 89,602.52 89,602.52 0.03733 0.03733 102,170.69 102,170.69 0.04257 0.04257 12,568.17 12,568.17 14.03% 14.03%6000 500 3,000,000 99,416.24 99,416.24 0.03314 0.03314 112,482.41 112,482.41 0.03749 0.03749 13,066.17 13,066.17 13.14% 13.14%6000 600 3,600,000 109,229.96 109,229.96 0.03034 0.03034 122,794.13 122,794.13 0.03411 0.03411 13,564.17 13,564.17 12.42% 12.42%

8000 200 1,600,000 93,237.56 93,237.56 0.05827 0.05827 108,661.73 108,661.73 0.06791 0.06791 15,424.17 15,424.17 16.54% 16.54%8000 300 2,400,000 106,322.52 106,322.52 0.04430 0.04430 122,410.69 122,410.69 0.05100 0.05100 16,088.17 16,088.17 15.13% 15.13%8000 400 3,200,000 119,407.48 119,407.48 0.03731 0.03731 136,159.65 136,159.65 0.04255 0.04255 16,752.17 16,752.17 14.03% 14.03%8000 500 4,000,000 132,492.44 132,492.44 0.03312 0.03312 149,908.61 149,908.61 0.03748 0.03748 17,416.17 17,416.17 13.15% 13.15%8000 600 4,800,000 145,577.40 145,577.40 0.03033 0.03033 163,657.57 163,657.57 0.03410 0.03410 18,080.17 18,080.17 12.42% 12.42%

PRESENT PROPOSED



POTOMAC ELECTRIC POWER COMPANYEXAMPLES COMPARING BILLS UNDER PRESENT AND PROPOSED TIME METERED GENERAL SERVICE RATESSCHEDULE "GT 3B " - DELIVERY ONLYDISTRICT OF COLUMBIA

PRESENT 'GT-3B' PROPOSED 'GT- 3B' INCREASEKW Hours Use KWH $ AMOUNT OF BILL $/KWH $ AMOUNT OF BILL $/KWH ($) ($) (%) (%)


100 200 20,000 804.90 814.90 0.04025 0.04075 750.35 750.35 0.03752 0.03752 (54.55) (64.55) -6.78% -7.92%100 300 30,000 925.67 935.67 0.03086 0.03119 871.12 871.12 0.02904 0.02904 (54.55) (64.55) -5.89% -6.90%100 400 40,000 1,046.43 1,056.43 0.02616 0.02641 991.88 991.88 0.02480 0.02480 (54.55) (64.55) -5.21% -6.11%100 500 50,000 1,167.19 1,177.19 0.02334 0.02354 1,112.64 1,112.64 0.02225 0.02225 (54.55) (64.55) -4.67% -5.48%100 600 60,000 1,287.95 1,297.95 0.02147 0.02163 1,233.40 1,233.40 0.02056 0.02056 (54.55) (64.55) -4.24% -4.97%

300 200 60,000 1,567.95 1,597.95 0.02613 0.02663 1,605.40 1,605.40 0.02676 0.02676 37.45 7.45 2.39% 0.47%300 300 90,000 1,930.24 1,960.24 0.02145 0.02178 1,967.69 1,967.69 0.02186 0.02186 37.45 7.45 1.94% 0.38%300 400 120,000 2,292.52 2,322.52 0.01910 0.01935 2,329.97 2,329.97 0.01942 0.01942 37.45 7.45 1.63% 0.32%300 500 150,000 2,654.81 2,684.81 0.01770 0.01790 2,692.26 2,692.26 0.01795 0.01795 37.45 7.45 1.41% 0.28%300 600 180,000 3,017.10 3,047.10 0.01676 0.01693 3,054.55 3,054.55 0.01697 0.01697 37.45 7.45 1.24% 0.24%

500 200 100,000 2,331.00 2,381.00 0.02331 0.02381 2,460.45 2,460.45 0.02460 0.02460 129.45 79.45 5.55% 3.34%500 300 150,000 2,934.81 2,984.81 0.01957 0.01990 3,064.26 3,064.26 0.02043 0.02043 129.45 79.45 4.41% 2.66%500 400 200,000 3,538.62 3,588.62 0.01769 0.01794 3,668.07 3,668.07 0.01834 0.01834 129.45 79.45 3.66% 2.21%500 500 250,000 4,142.43 4,192.43 0.01657 0.01677 4,271.88 4,271.88 0.01709 0.01709 129.45 79.45 3.12% 1.90%500 600 300,000 4,746.24 4,796.24 0.01582 0.01599 4,875.69 4,875.69 0.01625 0.01625 129.45 79.45 2.73% 1.66%

1000 200 200,000 4,238.62 4,338.62 0.02119 0.02169 4,598.07 4,598.07 0.02299 0.02299 359.45 259.45 8.48% 5.98%1000 300 300,000 5,446.24 5,546.24 0.01815 0.01849 5,805.69 5,805.69 0.01935 0.01935 359.45 259.45 6.60% 4.68%1000 400 400,000 6,653.86 6,753.86 0.01663 0.01688 7,013.31 7,013.31 0.01753 0.01753 359.45 259.45 5.40% 3.84%1000 500 500,000 7,861.48 7,961.48 0.01572 0.01592 8,220.93 8,220.93 0.01644 0.01644 359.45 259.45 4.57% 3.26%1000 600 600,000 9,069.10 9,169.10 0.01512 0.01528 9,428.55 9,428.55 0.01571 0.01571 359.45 259.45 3.96% 2.83%

2000 200 400,000 8,053.86 8,253.86 0.02013 0.02063 8,873.31 8,873.31 0.02218 0.02218 819.45 619.45 10.17% 7.50%2000 300 600,000 10,469.10 10,669.10 0.01745 0.01778 11,288.55 11,288.55 0.01881 0.01881 819.45 619.45 7.83% 5.81%2000 400 800,000 12,884.34 13,084.34 0.01611 0.01636 13,703.79 13,703.79 0.01713 0.01713 819.45 619.45 6.36% 4.73%2000 500 1,000,000 15,299.58 15,499.58 0.01530 0.01550 16,119.03 16,119.03 0.01612 0.01612 819.45 619.45 5.36% 4.00%2000 600 1,200,000 17,714.82 17,914.82 0.01476 0.01493 18,534.27 18,534.27 0.01545 0.01545 819.45 619.45 4.63% 3.46%

4000 200 800,000 15,684.34 16,084.34 0.01961 0.02011 17,423.79 17,423.79 0.02178 0.02178 1,739.45 1,339.45 11.09% 8.33%4000 300 1,200,000 20,514.82 20,914.82 0.01710 0.01743 22,254.27 22,254.27 0.01855 0.01855 1,739.45 1,339.45 8.48% 6.40%4000 400 1,600,000 25,345.30 25,745.30 0.01584 0.01609 27,084.75 27,084.75 0.01693 0.01693 1,739.45 1,339.45 6.86% 5.20%4000 500 2,000,000 30,175.78 30,575.78 0.01509 0.01529 31,915.23 31,915.23 0.01596 0.01596 1,739.45 1,339.45 5.76% 4.38%4000 600 2,400,000 35,006.26 35,406.26 0.01459 0.01475 36,745.71 36,745.71 0.01531 0.01531 1,739.45 1,339.45 4.97% 3.78%

6000 200 1,200,000 23,314.82 23,914.82 0.01943 0.01993 25,974.27 25,974.27 0.02165 0.02165 2,659.45 2,059.45 11.41% 8.61%6000 300 1,800,000 30,560.54 31,160.54 0.01698 0.01731 33,219.99 33,219.99 0.01846 0.01846 2,659.45 2,059.45 8.70% 6.61%6000 400 2,400,000 37,806.26 38,406.26 0.01575 0.01600 40,465.71 40,465.71 0.01686 0.01686 2,659.45 2,059.45 7.03% 5.36%6000 500 3,000,000 45,051.98 45,651.98 0.01502 0.01522 47,711.43 47,711.43 0.01590 0.01590 2,659.45 2,059.45 5.90% 4.51%6000 600 3,600,000 52,297.70 52,897.70 0.01453 0.01469 54,957.15 54,957.15 0.01527 0.01527 2,659.45 2,059.45 5.09% 3.89%

8000 200 1,600,000 30,945.30 31,745.30 0.01934 0.01984 34,524.75 34,524.75 0.02158 0.02158 3,579.45 2,779.45 11.57% 8.76%8000 300 2,400,000 40,606.26 41,406.26 0.01692 0.01725 44,185.71 44,185.71 0.01841 0.01841 3,579.45 2,779.45 8.82% 6.71%8000 400 3,200,000 50,267.22 51,067.22 0.01571 0.01596 53,846.67 53,846.67 0.01683 0.01683 3,579.45 2,779.45 7.12% 5.44%8000 500 4,000,000 59,928.18 60,728.18 0.01498 0.01518 63,507.63 63,507.63 0.01588 0.01588 3,579.45 2,779.45 5.97% 4.58%8000 600 4,800,000 69,589.14 70,389.14 0.01450 0.01466 73,168.59 73,168.59 0.01524 0.01524 3,579.45 2,779.45 5.14% 3.95%

PRESENT PROPOSED



Distribution SOS Transmission DT PSOS EATF SETF RADSResidentialCust/Min 15.09000$ 2.28000$ 0.12 -$ -$ -$ -$ -$ 17.49000$

15.09000$ 2.09000$ 0.12 17.30000$ Winter1st 30 0.00759$ -$ -$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01897$ Next 370 kwh 0.00759$ 0.07290$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.10152$ Excess of 400 kwh 0.01512$ 0.07290$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.10905$

Summer1st 30 0.00759$ -$ -$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01897$ Next 370 kwh 0.00759$ 0.06659$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.09521$ Excess of 400 kwh 0.02166$ 0.06659$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.10928$

Residential- AECust/Min 15.09000$ 2.21000$ 0.12 17.42000$

15.09000$ 2.05000$ 0.12 17.26000$ Winter1st 30 0.00759$ -$ -$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01897$ Next 370 kwh 0.00759$ 0.07068$ 0.00439$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.09704$ Excess of 400 kwh 0.01512$ 0.07068$ 0.00439$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.10457$


MMA - RCust/Min 11.84000$ 2.28000$ 0.12000$ 14.24000$

11.84000$ 2.09000$ 0.12000$ 14.05000$ Winter1st 30 0.00759$ -$ -$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01897$ Next 370 kwh 0.00759$ 0.07290$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.10152$ Excess of 400 kwh 0.01512$ 0.07290$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.10905$


MMA - AECust/Min 11.84000$ 2.21000$ 0.12000$ 14.17000$

11.84000$ 2.05000$ 0.12000$ 14.01000$ Winter1st 30 0.00759$ -$ -$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01897$ Next 370 kwh 0.00759$ 0.07068$ 0.00439$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.09704$ Excess of 400 kwh 0.01512$ 0.07068$ 0.00439$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.10457$


RTM Customers 15.09000$

Winter

1st 30 0.00759$ -$ Next 370 kwh 0.00759$ -$ Excess of 400 kwh 0.01512$ -$

Summer1st 30 0.00759$ -$ Next 370 kwh 0.00759$ -$ Excess of 400 kwh 0.02166$ -$

GSLV ND -Customers 27.42000$ 27.42000$ Summer kWh 0.03125$ 0.06373$ 0.00535$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00450$ 0.11691$ Winter kWh 0.02446$ 0.06767$ 0.00535$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00450$ 0.11406$


GS LV D (180 and 186)Customers 35.17000$ 35.17000$ kW 8.64000$ 8.64000$ Summer kWh 0.03009$ 0.05936$ 0.00549$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.11202$ Winter kWh 0.02280$ 0.06610$ 0.00549$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.11147$

GS 3ACustomers 89.41000$ 89.41000$ kW 10.61000$ 10.61000$ Summer kWh 0.02015$ 0.05460$ 0.00516 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.09699$ Winter kWh 0.01448$ 0.06091$ 0.00516 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.09763$ Kw

GT LVCustomers 456.76000$ 456.76000$ Summer kWh 0.00925$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.02133$ Winter kWh 0.00925$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.02133$ Kw 11.47000$ -$ -$ 11.47000$

GT 3ACustomers 187.64000$ 187.64000$ Summer kWh 0.00428$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01636$ Winter kWh 0.00427$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01635$ Kw 8.36000$ -$ -$ 8.36000$

GT 3BCustomers 423.38000$ 423.38000$ Kwh -$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01208$ kW Summer 1.40000$ 1.40000$

kW Winter 1.50000$ 1.50000$


Distribution SOS Transmission DT PSOS EATF SETF RADS Admin ChargeResidentialCust/Min 15.09000$ 2.28000$ 0.12000$ -$ -$ -$ -$ -$ -$ 17.49000$

15.09000$ 2.09000$ 0.12000$ -$ -$ -$ -$ -$ -$ 17.30000$ Winter1st 30 0.02076$ -$ -$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.03214$ Next 370 kwh 0.02076$ 0.07290$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.11469$ Excess of 400 kwh 0.02076$ 0.07290$ 0.00665$ 0.00700$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00300$ 0.11469$


Residential- AECust/Min 15.09000$ 2.21000$ 0.12000$ -$ -$ -$ -$ -$ -$ 17.42000$



MMA - RCust/Min 13.71000$ 2.28000$ 0.12000$ -$ -$ -$ -$ -$ -$ 16.11000$



MMA - AECust/Min 13.71000$ 2.21000$ 0.12000$ -$ -$ -$ -$ -$ -$ 16.04000$



RTM Customers 15.09000$

Winter

1st 30 0.02076$ -$ Next 370 kwh 0.02076$ -$ Excess of 400 kwh 0.02076$ -$

Summer1st 30 0.02076$ -$ Next 370 kwh 0.02076$ -$ Excess of 400 kwh 0.02076$ -$

GSLV ND -Customers 33.99000$ 33.99000$ Summer kWh 0.04467$ 0.06373$ 0.00535$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00450$ 0.13033$ Winter kWh 0.03497$ 0.06767$ 0.00535$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00450$ 0.12457$


GS LV D (180 and 186)Customers 44.43000$ 44.43000$ kW 10.44000$ 10.44000$ Summer kWh 0.02680$ 0.05936$ 0.00549$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.10873$ Winter kWh 0.02031$ 0.06610$ 0.00549$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.10898$

GS 3ACustomers 97.02000$ 97.02000$ kW 11.95000$ 11.95000$ Summer kWh 0.02158$ 0.05460$ 0.00516$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.09842$ Winter kWh 0.01551$ 0.06091$ 0.00516$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ 0.00500$ 0.09866$ Kw

GT LVCustomers 518.02000$ 518.02000$ Summer kWh 0.01313$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.02521$ Winter kWh 0.01313$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.02521$ Kw 13.84000$ -$ -$ -$ -$ -$ -$ -$ -$ 13.84000$

GT 3ACustomers 203.81000$ 203.81000$ Summer kWh 0.00511$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01719$ Winter kWh 0.00510$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01718$ Kw 10.12000$ -$ -$ -$ -$ -$ -$ -$ -$ 10.12000$

GT 3BCustomers 322.83000$ 322.83000$ Kwh -$ -$ -$ 0.00770$ 0.00209$ 0.00023$ 0.00161$ 0.00044$ -$ 0.01208$ kW Summer 1.86000$ 1.86000$

kW Winter 1.86000$


Hour Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec0 0 0 0 0 21 15 0 0 0 0 0 01 0 0 0 0 21 15 0 0 0 0 0 02 0 0 0 0 21 15 0 0 0 0 0 03 0 0 0 0 21 15 0 0 0 0 0 04 0 0 0 0 21 15 0 0 0 0 0 05 0 0 0 0 21 15 0 0 0 0 0 06 0 0 0 0 21 15 0 0 0 0 0 07 2 0 2 1 21 15 0 0 0 0 2 18 8 4 6 1 21 15 0 0 0 0 1 49 5 2 3 1 21 16 0 0 0 0 1 410 4 6 4 2 21 14 0 0 0 0 1 611 3 4 2 0 23 15 0 0 0 0 2 212 1 2 2 0 26 17 0 1 1 1 4 413 2 2 3 3 26 19 6 3 3 2 3 114 1 1 2 5 27 19 9 3 4 10 3 215 0 0 2 6 27 15 6 6 6 5 2 116 0 0 1 6 32 19 10 8 8 3 3 017 0 2 1 3 33 28 2 6 10 3 1 518 4 5 1 5 23 18 2 13 2 1 1 1019 9 10 6 1 24 17 7 3 0 11 5 620 5 7 11 3 24 15 0 2 9 11 11 221 3 3 4 11 29 18 6 0 3 4 8 422 0 2 0 4 24 16 0 0 0 0 4 123 0 0 0 0 22 14 0 0 0 0 1 0

Number of Substation Experiencing Daily Peaks in Each Hour


0

20000000

40000000

60000000

80000000

100000000

120000000

140000000

2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

KWh

Hours

Annual Energy Sum for PEPCO Residential Customers

RES TOTAL 16 RES TOTAL 15 RES TOTAL 14


0

10000000

20000000

30000000

40000000

50000000

60000000

70000000

H1 H2 H3 H4 H5 H6 H7 H8 H9 H10 H11 H12 H13 H14 H15 H16 H17 H18 H19 H20 H21 H22 H23 H24

kWh

Hours

Pepco Residential ‐ Seasonal ‐ 2014

SUMMER

WINTER


0

10000000

20000000

30000000

40000000

50000000

60000000

70000000


KWh

Hours


SUMMER

WINTER


0

10000000

20000000

30000000

40000000

50000000

60000000

70000000


kWh

Hours


SUMMER

WINTER


0

10000000

20000000

30000000

40000000

50000000

60000000

70000000


kWh

Hours

PEPCO DC Residential Summers 2014 ‐ 2016

Summer14 Summer15 Summer16


0

10000000

20000000

30000000

40000000

50000000

60000000

70000000


kWh

Hours

PEPCO DC Residential Winters 2014 ‐ 2016

Winter14 Winter15 Winter16


Pepco - District of ColumbiaProposed Resideniatial Demand Charge StructureScenario 1 10% Recovery

RATE SCHDEULES WITH A RESIDENTIAL END-USE 75,430,724$ 10%

Billing Current Present Billing Proposed ProposedDelivery Service Determinants Rate Revenue Determinants Rate Revenue

RATE SCHEDULE Residential Monthly Customer Charge

Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$

Distribution Demand - -$ -$ 3,302,173 0.82109$ 2,711,379$


Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.01181$ 5,055,533$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.01181$ 7,061,389$

Over 400 kWhSummer 550,076,420 0.02166$ 11,914,655$ 550,076,420 0.01181$ 6,496,403$ Winter 490,203,689 0.01512$ 7,411,880$ 490,203,689 0.01181$ 5,789,306$

Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 24,402,630$

Total Revenue at Authorized Rates 73,274,413$ 73,274,635$

7,782,911,944






Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$



Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.00656$ 2,808,154$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.00656$ 3,922,329$


Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 13,554,721$


7,782,911,944






Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$



Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.01181$ 5,055,533$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.01181$ 7,061,389$


Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 24,402,630$


7,782,911,944






Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$



Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.00656$ 2,808,154$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.00656$ 3,922,329$


Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 13,554,721$


7,782,911,944






Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$



Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.01181$ 5,055,533$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.01181$ 7,061,389$


Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 24,402,630$


7,782,911,944






Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$



Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.00656$ 2,808,154$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.00656$ 3,922,329$


Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 13,554,721$


7,782,911,944






Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$



Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.01181$ 5,055,533$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.01181$ 7,061,389$


Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 24,402,630$


7,782,911,944






Total Customer 3,059,021 15.09$ 46,160,627$ 3,059,021 15.09$ 46,160,627$



Summer 428,072,195 0.00759$ 3,249,068$ 428,072,195 0.00656$ 2,808,154$ Winter 597,916,070 0.00759$ 4,538,183$ 597,916,070 0.00656$ 3,922,329$


Total kWh Charge 2,066,268,375 27,113,786$ 2,066,268,375 13,554,721$


7,782,911,944



Distribution Demand Rate Structure

Residential Bill Impact Frequency Distribution - 2014

10% Demand Rate Recovery

Bill Impact (%)Percentage of

AccountsCumulative Percentage

Total Difference ($)

Percentage of Accounts

Cumulative Percentage








‐9% 0.00% 0.00% ‐$ 0.00% 0.00% (13,593)$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ ‐8% 0.00% 0.00% (11,890)$ 0.00% 0.00% ‐$ 0.00% 0.00% (11,766)$ 0.00% 0.00% ‐$ ‐7% 0.00% 0.00% ‐$ 0.00% 0.00% (414)$ 0.00% 0.00% ‐$ 0.00% 0.00% (4,195)$ ‐6% 0.00% 0.00% (497)$ 0.00% 0.00% (490)$ 0.00% 0.00% (502)$ 0.00% 0.00% (367)$ ‐5% 0.01% 0.01% (506)$ 0.06% 0.06% (517)$ 0.01% 0.02% (490)$ 0.08% 0.09% (447)$ ‐4% 0.26% 0.27% (226)$ 0.56% 0.61% (156)$ 0.30% 0.32% (215)$ 0.69% 0.77% (147)$ ‐3% 1.77% 2.05% (87)$ 2.49% 3.11% (79)$ 1.88% 2.20% (86)$ 2.64% 3.42% (77)$ ‐2% 6.36% 8.40% (42)$ 6.83% 9.94% (40)$ 6.44% 8.64% (42)$ 6.75% 10.17% (39)$ ‐1% 11.74% 20.15% (16)$ 11.38% 21.31% (15)$ 11.80% 20.44% (16)$ 11.16% 21.33% (15)$ 0% 16.67% 36.82% (0)$ 15.44% 36.76% (0)$ 16.67% 37.11% (0)$ 15.70% 37.03% (0)$ 1% 19.19% 56.01% 8$ 17.79% 54.55% 8$ 19.11% 56.22% 8$ 18.23% 55.26% 8$ 2% 19.23% 75.24% 13$ 17.55% 72.10% 13$ 19.20% 75.42% 13$ 18.20% 73.46% 13$ 3% 21.00% 96.24% 16$ 20.66% 92.76% 16$ 20.92% 96.34% 16$ 20.10% 93.56% 16$ 4% 2.93% 99.17% 21$ 6.73% 99.49% 20$ 2.90% 99.24% 21$ 6.24% 99.80% 21$ 5% 0.57% 99.74% 25$ 0.41% 99.90% 22$ 0.54% 99.78% 25$ 0.20% 100.00% 26$ 6% 0.20% 99.95% 29$ 0.06% 99.96% 22$ 0.17% 99.96% 29$ 0.00% 100.00% 28$ 7% 0.05% 99.99% 35$ 0.02% 99.98% 23$ 0.04% 99.99% 35$ 0.00% 100.00% 24$ 8% 0.00% 100.00% 37$ 0.01% 99.99% 27$ 0.00% 100.00% 36$ 0.00% 100.00% ‐$ 9% 0.00% 100.00% 44$ 0.00% 99.99% 29$ 0.00% 100.00% 52$ 0.00% 100.00% ‐$ 10% 0.00% 100.00% 62$ 0.00% 100.00% 27$ 0.00% 100.00% 63$ 0.00% 100.00% ‐$ 11% 0.00% 100.00% 65$ 0.00% 100.00% 32$ 0.00% 100.00% 163$ 0.00% 100.00% ‐$ 12% 0.00% 100.00% 172$ 0.00% 100.00% 35$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 13% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 14% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 15% 0.00% 100.00% ‐$ 0.00% 100.00% 36$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 16% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 17% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 18% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 19% 0.00% 100.00% 64$ 0.00% 100.00% ‐$ 0.00% 100.00% 62$ 0.00% 100.00% ‐$ 20% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 21% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 22% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 23% 0.00% 100.00% ‐$ 0.00% 100.00% 63$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 24% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 25% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 26% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 27% 0.00% 100.00% 101$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 28% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 29% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 30% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 31% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 32% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$

Scenario 1 Scenario 2 Scenario 3 Scenario 4


33% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 34% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 35% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 36% 0.00% 100.00% 458$ 0.00% 100.00% ‐$ 37% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 38% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 39% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 40% 0.00% 100.00% 83$ 0.00% 100.00% ‐$

(12,675)$ (14,290)$ (12,595)$ (5,151)$


















‐14% 0.00% 0.00% ‐$ 0.00% 0.00% (20,852)$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ ‐13% 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ ‐12% 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ ‐11% 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ ‐10% 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ ‐9% 0.00% 0.00% ‐$ 0.00% 0.00% (419)$ 0.00% 0.00% ‐$ 0.00% 0.00% (5,568)$ ‐8% 0.00% 0.00% (12,335)$ 0.01% 0.02% (1,092)$ 0.00% 0.00% (11,714)$ 0.02% 0.03% (776)$ ‐7% 0.00% 0.00% ‐$ 0.07% 0.08% (410)$ 0.00% 0.00% ‐$ 0.15% 0.18% (352)$ ‐6% 0.00% 0.00% (217)$ 0.31% 0.39% (224)$ 0.00% 0.00% (305)$ 0.47% 0.65% (212)$ ‐5% 0.04% 0.04% (361)$ 1.04% 1.43% (143)$ 0.06% 0.06% (366)$ 1.27% 1.92% (142)$ ‐4% 0.42% 0.46% (156)$ 2.73% 4.16% (94)$ 0.56% 0.62% (162)$ 2.85% 4.77% (90)$ ‐3% 2.78% 3.24% (79)$ 5.29% 9.45% (57)$ 3.22% 3.85% (77)$ 5.18% 9.95% (56)$ ‐2% 7.89% 11.13% (38)$ 8.16% 17.61% (31)$ 8.30% 12.15% (37)$ 7.71% 17.66% (30)$ ‐1% 12.83% 23.96% (14)$ 10.18% 27.80% (13)$ 13.01% 25.16% (14)$ 9.56% 27.22% (13)$ 0% 16.80% 40.76% (0)$ 12.68% 40.48% (0)$ 16.71% 41.87% (0)$ 12.89% 40.11% (0)$ 1% 18.72% 59.48% 7$ 13.37% 53.85% 8$ 18.40% 60.27% 7$ 14.96% 55.07% 7$ 2% 20.13% 79.61% 12$ 13.67% 67.53% 14$ 20.12% 80.39% 12$ 15.22% 70.29% 13$ 3% 13.49% 93.10% 16$ 12.70% 80.22% 18$ 13.61% 94.00% 16$ 12.23% 82.53% 18$ 4% 2.97% 96.07% 22$ 8.52% 88.74% 22$ 2.31% 96.31% 23$ 8.06% 90.59% 24$ 5% 0.55% 96.63% 36$ 4.69% 93.44% 27$ 0.43% 96.74% 36$ 4.77% 95.36% 29$ 6% 0.35% 96.98% 43$ 2.53% 95.97% 31$ 0.35% 97.09% 43$ 2.63% 97.99% 34$ 7% 0.36% 97.34% 48$ 1.46% 97.42% 35$ 0.38% 97.47% 48$ 1.23% 99.22% 39$ 8% 0.37% 97.71% 54$ 0.87% 98.29% 39$ 0.38% 97.85% 52$ 0.49% 99.72% 44$ 9% 0.35% 98.06% 59$ 0.55% 98.84% 42$ 0.33% 98.18% 56$ 0.18% 99.90% 49$ 10% 0.30% 98.36% 63$ 0.35% 99.20% 44$ 0.32% 98.50% 64$ 0.07% 99.96% 51$ 11% 0.31% 98.67% 70$ 0.23% 99.43% 47$ 0.30% 98.80% 67$ 0.02% 99.98% 55$ 12% 0.27% 98.94% 72$ 0.14% 99.57% 49$ 0.25% 99.06% 71$ 0.01% 99.99% 58$ 13% 0.24% 99.18% 79$ 0.10% 99.67% 52$ 0.23% 99.29% 78$ 0.00% 99.99% 62$ 14% 0.19% 99.37% 84$ 0.07% 99.74% 52$ 0.19% 99.47% 84$ 0.00% 100.00% 58$ 15% 0.17% 99.54% 90$ 0.05% 99.79% 56$ 0.14% 99.62% 89$ 0.00% 100.00% 59$ 16% 0.13% 99.66% 93$ 0.04% 99.83% 59$ 0.12% 99.73% 94$ 0.00% 100.00% 81$ 17% 0.11% 99.77% 100$ 0.03% 99.86% 59$ 0.08% 99.82% 96$ 0.00% 100.00% 86$ 18% 0.07% 99.84% 101$ 0.03% 99.89% 62$ 0.06% 99.88% 102$ 0.00% 100.00% ‐$ 19% 0.05% 99.89% 111$ 0.01% 99.90% 64$ 0.04% 99.92% 109$ 0.00% 100.00% 91$ 20% 0.03% 99.93% 111$ 0.02% 99.92% 67$ 0.03% 99.95% 104$ 0.00% 100.00% ‐$ 21% 0.02% 99.95% 108$ 0.01% 99.93% 62$ 0.02% 99.96% 107$ 0.00% 100.00% 304$ 22% 0.01% 99.96% 119$ 0.01% 99.94% 75$ 0.01% 99.97% 122$ 0.00% 100.00% 65$ 23% 0.01% 99.98% 122$ 0.01% 99.95% 77$ 0.01% 99.98% 114$ 0.00% 100.00% ‐$ 24% 0.01% 99.98% 117$ 0.01% 99.96% 79$ 0.00% 99.99% 126$ 0.00% 100.00% ‐$ 25% 0.00% 99.99% 134$ 0.00% 99.96% 79$ 0.00% 99.99% 116$ 0.00% 100.00% 82,388$ 26% 0.00% 99.99% 121$ 0.00% 99.96% 62$ 0.00% 99.99% 125$ 0.00% 100.00% ‐$ 27% 0.00% 99.99% 130$ 0.01% 99.97% 78$ 0.00% 99.99% 127$ 0.00% 100.00% ‐$



28% 0.00% 99.99% 132$ 0.00% 99.97% 90$ 0.00% 99.99% ‐$ 0.00% 100.00% ‐$ 29% 0.00% 99.99% ‐$ 0.00% 99.98% 90$ 0.00% 99.99% 133$ 0.00% 100.00% ‐$ 30% 0.00% 99.99% 137$ 0.00% 99.98% 79$ 0.00% 99.99% ‐$ 0.00% 100.00% 100$ 31% 0.00% 99.99% ‐$ 0.00% 99.98% 82$ 0.00% 100.00% 161$ 0.00% 100.00% ‐$ 32% 0.00% 100.00% 167$ 0.00% 99.99% 83$ 0.00% 100.00% 162$ 0.00% 100.00% ‐$ 33% 0.00% 100.00% 161$ 0.00% 99.99% 79$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 34% 0.00% 100.00% 182$ 0.00% 99.99% 108$ 0.00% 100.00% 262$ 0.00% 100.00% ‐$ 35% 0.00% 100.00% 374$ 0.00% 99.99% 100$ 0.00% 100.00% 84$ 0.00% 100.00% ‐$ 36% 0.00% 100.00% 128$ 0.00% 99.99% 107$ 0.00% 100.00% 176$ 0.00% 100.00% ‐$ 37% 0.00% 100.00% 182$ 0.00% 99.99% 83$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 38% 0.00% 100.00% ‐$ 0.00% 99.99% 292$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 39% 0.00% 100.00% ‐$ 0.00% 99.99% 82$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 40% 0.00% 100.00% ‐$ 0.00% 99.99% 115$ 0.00% 100.00% 244$ 0.00% 100.00% ‐$ 41% 0.00% 100.00% 253$ 0.00% 99.99% 112$ 0.00% 100.00% 332$ 0.00% 100.00% ‐$ 42% 0.00% 100.00% ‐$ 0.00% 99.99% 144$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 43% 0.00% 100.00% 345$ 0.00% 99.99% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 44% 0.00% 100.00% ‐$ 0.00% 99.99% 638$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 45% 0.00% 100.00% ‐$ 0.00% 100.00% 125$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 46% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 47% 0.00% 100.00% ‐$ 0.00% 100.00% 100$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 48% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 49% 0.00% 100.00% ‐$ 0.00% 100.00% 149$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 50% 0.00% 100.00% ‐$ 0.00% 100.00% 136$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 51% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 52% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 53% 0.00% 100.00% ‐$ 0.00% 100.00% 175$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 54% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 55% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 56% 0.00% 100.00% ‐$ 0.00% 100.00% 124$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 57% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 58% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 59% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 60% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 61% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 62% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 63% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 64% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 65% 0.00% 100.00% ‐$ 0.00% 100.00% 180$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 66% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 67% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 68% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 69% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 70% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 71% 0.00% 100.00% ‐$ 0.00% 100.00% 154$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 72% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 73% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 74% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 75% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 76% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 77% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 78% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 79% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 1,145$ 0.00% 100.00% ‐$ 80% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$


81% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 82% 0.00% 100.00% 1,189$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 83% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 84% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 85% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 86% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 87% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 88% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 289$ 0.00% 100.00% ‐$ 89% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 90% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 91% 0.00% 100.00% 299$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$

>100% 0.00% 100.00% 3,480$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ (7,528)$ (15,067)$ (7,599)$ 76,477$


















‐8% 0.00% 0.00% (500)$ 0.00% 0.00% (503)$ 0.00% 0.00% (500)$ 0.00% 0.00% (505)$ ‐7% 0.00% 0.00% ‐$ 0.00% 0.00% (389)$ 0.00% 0.00% ‐$ 0.00% 0.00% (666)$ ‐6% 0.00% 0.00% (599)$ 0.01% 0.01% (1,258)$ 0.00% 0.00% (583)$ 0.04% 0.04% (809)$ ‐5% 0.12% 0.12% (532)$ 0.68% 0.68% (345)$ 0.13% 0.13% (513)$ 1.68% 1.72% (271)$ ‐4% 1.99% 2.11% (201)$ 5.47% 6.16% (155)$ 2.16% 2.30% (197)$ 9.28% 11.00% (137)$ ‐3% 8.00% 10.12% (101)$ 14.06% 20.22% (86)$ 8.46% 10.75% (100)$ 17.62% 28.63% (77)$ ‐2% 14.64% 24.76% (53)$ 17.86% 38.08% (44)$ 14.96% 25.72% (52)$ 18.44% 47.06% (39)$ ‐1% 16.40% 41.16% (21)$ 16.66% 54.73% (17)$ 16.52% 42.24% (21)$ 15.55% 62.61% (15)$ 0% 15.58% 56.74% (1)$ 14.08% 68.81% (0)$ 15.51% 57.75% (0)$ 12.43% 75.04% (0)$ 1% 13.65% 70.39% 12$ 11.13% 79.95% 9$ 13.51% 71.25% 11$ 9.73% 84.77% 8$ 2% 10.41% 80.80% 19$ 8.46% 88.40% 15$ 10.23% 81.48% 19$ 7.61% 92.38% 13$ 3% 8.47% 89.27% 23$ 7.60% 96.01% 18$ 8.35% 89.83% 22$ 6.73% 99.11% 16$ 4% 6.70% 95.97% 25$ 3.48% 99.49% 22$ 6.50% 96.33% 25$ 0.87% 99.98% 24$ 5% 2.91% 98.88% 29$ 0.48% 99.97% 26$ 2.72% 99.05% 29$ 0.01% 100.00% 25$ 6% 0.90% 99.78% 34$ 0.02% 99.99% 30$ 0.78% 99.83% 33$ 0.00% 100.00% 76$ 7% 0.18% 99.96% 38$ 0.00% 100.00% 35$ 0.14% 99.96% 37$ 0.00% 100.00% 24$ 8% 0.03% 99.99% 42$ 0.00% 100.00% 34$ 0.02% 99.99% 42$ 0.00% 100.00% 60$ 9% 0.01% 100.00% 44$ 0.00% 100.00% ‐$ 0.01% 100.00% 45$ 0.00% 100.00% ‐$ 10% 0.00% 100.00% 52$ 0.00% 100.00% 16,782$ 0.00% 100.00% 51$ 0.00% 100.00% ‐$ 11% 0.00% 100.00% 51$ 0.00% 100.00% ‐$ 0.00% 100.00% 163$ 0.00% 100.00% ‐$ 12% 0.00% 100.00% 113$ 0.00% 100.00% 93$ 0.00% 100.00% 53$ 0.00% 100.00% ‐$ 13% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 14% 0.00% 100.00% ‐$ 0.00% 100.00% 109$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 15% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 16% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 17% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 18% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 30,825$ 0.00% 100.00% ‐$ 19% 0.00% 100.00% 64$ 0.00% 100.00% ‐$ 0.00% 100.00% 62$ 0.00% 100.00% ‐$ 20% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 253$ 0.00% 100.00% ‐$ 21% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 22% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 23% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 24% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 183$ 0.00% 100.00% ‐$ 25% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 26% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 776$ 27% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 28% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 29% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 30% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 31% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 32% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 33% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$



34% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 35% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 36% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 37% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 38% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 39% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 40% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 41% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 42% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 43% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 44% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 45% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 46% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 47% 0.00% 100.00% ‐$ 0.00% 100.00% 1,414$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 48% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 49% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 50% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 51% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 52% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 53% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 54% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 55% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 56% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 57% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 58% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 59% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 60% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 61% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 62% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 63% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 64% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 65% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 66% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 67% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 68% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 69% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 70% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 71% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 72% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 73% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 74% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 75% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 1,345$ 76% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 77% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 78% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 79% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 80% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 2,383$ 0.00% 100.00% ‐$

(1,461)$ 15,788$ 32,270$ (153)$


















‐12% 0.00% 0.00% (772)$ 0.00% 0.00% (790)$ 0.00% 0.00% (773)$ 0.00% 0.00% (801)$ ‐11% 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ ‐10% 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% ‐$ 0.00% 0.00% (9,496)$ ‐9% 0.00% 0.00% ‐$ 0.00% 0.00% (6,228)$ 0.00% 0.00% ‐$ 0.08% 0.08% (1,142)$ ‐8% 0.00% 0.00% ‐$ 0.03% 0.03% (1,381)$ 0.00% 0.00% ‐$ 1.02% 1.09% (470)$ ‐7% 0.00% 0.00% (2,477)$ 0.36% 0.39% (498)$ 0.00% 0.01% (2,254)$ 4.35% 5.44% (272)$ ‐6% 0.03% 0.03% (1,003)$ 1.85% 2.24% (273)$ 0.04% 0.04% (878)$ 9.34% 14.78% (182)$ ‐5% 0.22% 0.25% (356)$ 4.72% 6.96% (174)$ 0.29% 0.33% (329)$ 12.78% 27.56% (123)$ ‐4% 0.93% 1.18% (188)$ 8.00% 14.96% (115)$ 1.16% 1.49% (180)$ 13.46% 41.03% (80)$ ‐3% 2.37% 3.55% (112)$ 10.35% 25.30% (73)$ 2.78% 4.27% (109)$ 12.61% 53.64% (50)$ ‐2% 4.21% 7.76% (63)$ 11.16% 36.46% (42)$ 4.72% 8.99% (61)$ 10.87% 64.50% (28)$ ‐1% 6.02% 13.79% (27)$ 10.94% 47.41% (18)$ 6.61% 15.59% (27)$ 9.00% 73.50% (12)$ 0% 7.76% 21.54% 0$ 10.37% 57.77% (0)$ 8.19% 23.79% 0$ 7.67% 81.17% (0)$ 1% 8.64% 30.19% 21$ 10.06% 67.83% 12$ 8.92% 32.71% 21$ 7.82% 88.99% 7$ 2% 9.43% 39.62% 36$ 8.86% 76.69% 21$ 9.63% 42.33% 35$ 5.23% 94.22% 12$ 3% 9.31% 48.93% 49$ 7.17% 83.86% 28$ 9.30% 51.63% 47$ 3.01% 97.22% 17$ 4% 8.73% 57.66% 59$ 5.43% 89.29% 34$ 8.79% 60.42% 57$ 1.63% 98.85% 22$ 5% 8.04% 65.69% 68$ 3.82% 93.11% 40$ 7.88% 68.30% 66$ 0.70% 99.56% 27$ 6% 7.10% 72.80% 75$ 2.56% 95.68% 44$ 6.85% 75.15% 73$ 0.27% 99.82% 31$ 7% 5.93% 78.72% 82$ 1.72% 97.40% 48$ 5.68% 80.82% 79$ 0.10% 99.92% 35$ 8% 4.90% 83.63% 88$ 1.09% 98.49% 53$ 4.61% 85.43% 85$ 0.04% 99.96% 38$ 9% 4.01% 87.63% 94$ 0.68% 99.17% 58$ 3.68% 89.11% 90$ 0.02% 99.98% 44$ 10% 3.15% 90.78% 99$ 0.38% 99.55% 60$ 2.88% 91.99% 96$ 0.01% 99.99% 46$ 11% 2.40% 93.18% 103$ 0.19% 99.75% 66$ 2.18% 94.18% 99$ 0.00% 99.99% 42$ 12% 1.87% 95.05% 105$ 0.10% 99.85% 69$ 1.67% 95.85% 103$ 0.00% 99.99% 67$ 13% 1.42% 96.47% 108$ 0.06% 99.91% 75$ 1.22% 97.07% 104$ 0.00% 100.00% 54$ 14% 1.02% 97.49% 112$ 0.03% 99.95% 72$ 0.88% 97.95% 106$ 0.00% 100.00% 50$ 15% 0.75% 98.24% 112$ 0.02% 99.96% 76$ 0.62% 98.57% 110$ 0.00% 100.00% 45$ 16% 0.53% 98.76% 117$ 0.01% 99.97% 83$ 0.46% 99.03% 116$ 0.00% 100.00% ‐$ 17% 0.40% 99.17% 122$ 0.01% 99.98% 83$ 0.33% 99.36% 118$ 0.00% 100.00% 76$ 18% 0.27% 99.44% 126$ 0.00% 99.99% 82$ 0.21% 99.57% 122$ 0.00% 100.00% ‐$ 19% 0.18% 99.62% 127$ 0.00% 99.99% 101$ 0.14% 99.71% 129$ 0.00% 100.00% ‐$ 20% 0.12% 99.74% 134$ 0.00% 99.99% 92$ 0.09% 99.79% 127$ 0.00% 100.00% ‐$ 21% 0.07% 99.81% 134$ 0.00% 99.99% 89$ 0.06% 99.85% 129$ 0.00% 100.00% 304$ 22% 0.05% 99.86% 139$ 0.00% 99.99% 85$ 0.04% 99.89% 141$ 0.00% 100.00% ‐$ 23% 0.04% 99.90% 146$ 0.00% 99.99% 61$ 0.03% 99.92% 132$ 0.00% 100.00% ‐$ 24% 0.03% 99.93% 139$ 0.00% 100.00% 186$ 0.02% 99.94% 149$ 0.00% 100.00% ‐$ 25% 0.02% 99.95% 157$ 0.00% 100.00% 83$ 0.02% 99.96% 153$ 0.00% 100.00% ‐$ 26% 0.01% 99.96% 156$ 0.00% 100.00% ‐$ 0.01% 99.97% 138$ 0.00% 100.00% ‐$ 27% 0.01% 99.97% 139$ 0.00% 100.00% ‐$ 0.00% 99.97% 130$ 0.00% 100.00% ‐$ 28% 0.00% 99.97% 144$ 0.00% 100.00% ‐$ 0.01% 99.98% 148$ 0.00% 100.00% ‐$ 29% 0.01% 99.98% 153$ 0.00% 100.00% ‐$ 0.00% 99.98% 147$ 0.00% 100.00% 50,241$



30% 0.00% 99.98% 152$ 0.00% 100.00% ‐$ 0.00% 99.98% 144$ 0.00% 100.00% 100$ 31% 0.00% 99.99% 144$ 0.00% 100.00% 137$ 0.00% 99.99% 157$ 0.00% 100.00% ‐$ 32% 0.00% 99.99% 167$ 0.00% 100.00% ‐$ 0.00% 99.99% 163$ 0.00% 100.00% 411$ 33% 0.00% 99.99% 149$ 0.00% 100.00% ‐$ 0.00% 99.99% 110$ 0.00% 100.00% ‐$ 34% 0.00% 99.99% 146$ 0.00% 100.00% ‐$ 0.00% 99.99% 220$ 0.00% 100.00% ‐$ 35% 0.00% 99.99% 270$ 0.00% 100.00% ‐$ 0.00% 99.99% 84$ 0.00% 100.00% ‐$ 36% 0.00% 99.99% 157$ 0.00% 100.00% ‐$ 0.00% 99.99% 182$ 0.00% 100.00% ‐$ 37% 0.00% 100.00% 188$ 0.00% 100.00% ‐$ 0.00% 99.99% 126$ 0.00% 100.00% ‐$ 38% 0.00% 100.00% 130$ 0.00% 100.00% ‐$ 0.00% 99.99% 100$ 0.00% 100.00% ‐$ 39% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 99.99% ‐$ 0.00% 100.00% 300$ 40% 0.00% 100.00% 104$ 0.00% 100.00% ‐$ 0.00% 100.00% 244$ 0.00% 100.00% ‐$ 41% 0.00% 100.00% 253$ 0.00% 100.00% ‐$ 0.00% 100.00% 202$ 0.00% 100.00% ‐$ 42% 0.00% 100.00% 150$ 0.00% 100.00% ‐$ 0.00% 100.00% 357$ 0.00% 100.00% ‐$ 43% 0.00% 100.00% 249$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 44% 0.00% 100.00% 469$ 0.00% 100.00% 638$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 45% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 46% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 47% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 48% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 49% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 50% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 51% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 52% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 230$ 0.00% 100.00% ‐$ 53% 0.00% 100.00% ‐$ 0.00% 100.00% 175$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 54% 0.00% 100.00% 238$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 55% 0.00% 100.00% ‐$ 0.00% 100.00% 96,522$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 56% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 57% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 58% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 59% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 60% 0.00% 100.00% ‐$ 0.00% 100.00% 762$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 61% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 62% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 63% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 64% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 65% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 66% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 67% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 68% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 69% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 70% 0.00% 100.00% ‐$ 0.00% 100.00% 544$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 71% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 72% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 73% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 74% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 75% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 76% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 77% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 78% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 79% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 1,145$ 0.00% 100.00% ‐$ 80% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 81% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 82% 0.00% 100.00% 1,189$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$


83% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 84% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 85% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 86% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 87% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 88% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 289$ 0.00% 100.00% ‐$ 89% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 90% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 91% 0.00% 100.00% 299$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 92% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 93% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 94% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 95% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 96% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 166,738$ 0.00% 100.00% ‐$

2,603$ 90,885$ 168,929$ 39,315$


















‐8% 0.00% 0.00% (508)$ 0.00% 0.00% ‐$ 0.00% 0.00% (508)$ 0.00% 0.00% (508)$ ‐7% 0.00% 0.00% (371)$ 0.00% 0.00% (477)$ 0.00% 0.00% (373)$ 0.00% 0.00% (430)$ ‐6% 0.00% 0.01% (329)$ 0.01% 0.01% (318)$ 0.00% 0.01% (345)$ 0.04% 0.04% (293)$ ‐5% 0.07% 0.08% (276)$ 0.11% 0.13% (289)$ 0.07% 0.07% (277)$ 0.18% 0.22% (260)$ ‐4% 0.45% 0.53% (173)$ 0.67% 0.80% (154)$ 0.48% 0.56% (173)$ 0.80% 1.03% (143)$ ‐3% 2.19% 2.71% (82)$ 2.65% 3.45% (76)$ 2.22% 2.77% (82)$ 2.85% 3.87% (74)$ ‐2% 6.98% 9.69% (40)$ 7.15% 10.60% (38)$ 6.95% 9.72% (40)$ 7.28% 11.15% (38)$ ‐1% 12.43% 22.12% (16)$ 11.84% 22.44% (15)$ 12.37% 22.09% (16)$ 11.60% 22.75% (15)$ 0% 16.52% 38.63% (0)$ 15.68% 38.12% (0)$ 16.47% 38.56% (0)$ 15.11% 37.86% (0)$ 1% 18.12% 56.76% 8$ 17.49% 55.62% 8$ 18.08% 56.64% 8$ 16.90% 54.76% 8$ 2% 19.68% 76.44% 13$ 18.51% 74.13% 13$ 19.57% 76.21% 13$ 17.69% 72.45% 14$ 3% 21.79% 98.22% 16$ 21.80% 95.93% 16$ 21.87% 98.09% 16$ 20.51% 92.96% 17$ 4% 1.77% 100.00% 20$ 4.07% 100.00% 21$ 1.91% 100.00% 20$ 6.80% 99.76% 21$ 5% 0.00% 100.00% 17$ 0.00% 100.00% 22$ 0.00% 100.00% 31$ 0.24% 100.00% 26$ 6% 0.00% 100.00% 42$ 0.00% 100.00% 48$ 0.00% 100.00% 16$ 0.00% 100.00% 37$ 7% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 24$ 8% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 60$ 9% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 10% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 11% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 872$ 12% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 13% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 14% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 15% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 16% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 17% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 18% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 19% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 20% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 21% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 22% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 23% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 24% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 25% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 26% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 820$ 27% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 28% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 29% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 30% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 31% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 32% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$



33% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 34% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 35% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 36% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 37% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 38% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 39% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 40% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 41% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 42% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 43% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 44% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 45% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 46% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 47% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 48% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 49% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 50% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 51% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 52% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 53% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 54% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 55% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 56% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 57% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 58% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 59% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 60% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 61% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 62% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 63% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 64% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 65% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 66% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 67% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 68% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 69% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 70% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 71% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 72% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 73% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 74% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 75% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 76% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 77% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 78% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 79% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 80% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 81% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 82% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 83% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 84% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 85% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$


86% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 87% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 88% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 89% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 90% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 91% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 92% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 93% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 94% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 95% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 96% 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% ‐$ 0.00% 100.00% 1,362$

(1,678)$ (1,239)$ (1,709)$ 1,499$


Pepco - District of ColumbiaDistribution Demand Rate StructureResidential Bill Impact Frequency Distribution - 201650% Demand Rate Recovery














-31% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -30% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -29% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -28% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -27% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -26% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -25% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -24% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -23% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -22% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -21% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -20% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -19% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -18% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -17% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -16% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -15% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -14% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -13% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% (791)$ -12% 0.00% 0.00% (790)$ 0.00% 0.00% -$ 0.00% 0.00% (790)$ 0.00% 0.00% -$ -11% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -10% 0.00% 0.00% (57)$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -9% 0.00% 0.00% (107)$ 0.00% 0.00% (464)$ 0.00% 0.00% (258)$ 0.00% 0.00% (570)$ -8% 0.00% 0.00% (104)$ 0.00% 0.00% (530)$ 0.00% 0.00% (152)$ 0.01% 0.01% (1,062)$ -7% 0.00% 0.01% (76)$ 0.01% 0.01% (1,315)$ 0.00% 0.00% (168)$ 0.08% 0.09% (535)$ -6% 0.01% 0.02% (140)$ 0.08% 0.09% (430)$ 0.01% 0.01% (152)$ 0.31% 0.40% (256)$ -5% 0.04% 0.05% (263)$ 0.49% 0.58% (191)$ 0.05% 0.06% (362)$ 1.12% 1.52% (146)$ -4% 0.41% 0.47% (162)$ 1.79% 2.37% (106)$ 0.45% 0.51% (162)$ 2.80% 4.32% (91)$ -3% 2.77% 3.24% (77)$ 4.52% 6.90% (61)$ 2.77% 3.28% (78)$ 5.19% 9.51% (56)$ -2% 7.84% 11.08% (38)$ 7.82% 14.72% (33)$ 7.69% 10.97% (38)$ 7.63% 17.15% (31)$ -1% 13.02% 24.11% (15)$ 10.62% 25.34% (14)$ 12.71% 23.68% (15)$ 9.64% 26.79% (13)$ 0% 16.86% 40.96% (0)$ 13.53% 38.87% 0$ 16.70% 40.38% (0)$ 11.75% 38.54% (0)$ 1% 19.22% 60.18% 8$ 15.62% 54.48% 8$ 18.95% 59.34% 8$ 14.56% 53.11% 8$ 2% 21.37% 81.55% 13$ 17.11% 71.59% 14$ 21.30% 80.64% 13$ 14.50% 67.61% 14$ 3% 14.97% 96.52% 17$ 16.27% 87.86% 18$ 16.22% 96.86% 17$ 12.33% 79.93% 20$ 4% 2.97% 99.49% 23$ 8.44% 96.29% 24$ 2.79% 99.65% 23$ 8.59% 88.52% 26$ 5% 0.29% 99.78% 38$ 2.92% 99.21% 31$ 0.17% 99.82% 40$ 5.55% 94.07% 31$ 6% 0.08% 99.86% 52$ 0.56% 99.77% 41$ 0.05% 99.87% 51$ 3.23% 97.30% 36$ 7% 0.04% 99.89% 47$ 0.10% 99.87% 57$ 0.03% 99.91% 38$ 1.61% 98.91% 40$ 8% 0.02% 99.92% 35$ 0.06% 99.93% 70$ 0.02% 99.93% 42$ 0.64% 99.55% 46$ 9% 0.03% 99.94% 56$ 0.03% 99.96% 76$ 0.02% 99.95% 40$ 0.26% 99.81% 52$

10% 0.02% 99.96% 33$ 0.02% 99.97% 60$ 0.02% 99.97% 36$ 0.09% 99.91% 60$ 11% 0.02% 99.98% 43$ 0.01% 99.98% 63$ 0.01% 99.98% 48$ 0.04% 99.94% 68$ 12% 0.01% 99.98% 67$ 0.00% 99.99% 85$ 0.00% 99.99% 38$ 0.02% 99.97% 84$ 13% 0.01% 99.99% 48$ 0.01% 99.99% 94$ 0.01% 99.99% 54$ 0.01% 99.97% 105$ 14% 0.00% 99.99% 57$ 0.00% 100.00% 57$ 0.00% 100.00% 74$ 0.01% 99.98% 95$ 15% 0.00% 100.00% 74$ 0.00% 100.00% 74$ 0.00% 100.00% 53$ 0.00% 99.99% 124$ 16% 0.00% 100.00% 46$ 0.00% 100.00% 49$ 0.00% 100.00% 41$ 0.00% 99.99% 129$ 17% 0.00% 100.00% 63$ 0.00% 100.00% 81$ 0.00% 100.00% 56$ 0.00% 99.99% 121$ 18% 0.00% 100.00% 57$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 99.99% 144$ 19% 0.00% 100.00% 157$ 0.00% 100.00% -$ 0.00% 100.00% 122$ 0.00% 100.00% 133$


20% 0.00% 100.00% 97$ 0.00% 100.00% 100$ 0.00% 100.00% -$ 0.00% 100.00% 61$ 21% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 210$ 22% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 266$ 23% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 24% 0.00% 100.00% 65$ 0.00% 100.00% -$ 0.00% 100.00% 63$ 0.00% 100.00% -$ 25% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 303$ 0.00% 100.00% 93$ 26% 0.00% 100.00% 317$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 27% 0.00% 100.00% -$ 0.00% 100.00% 327$ 0.00% 100.00% -$ 0.00% 100.00% -$ 28% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 29% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 101$ 30% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 162$ 31% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 32% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 33% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 412$ 34% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 35% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 36% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 37% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 38% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 39% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 300$ 40% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 41% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 42% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 43% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 44% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 45% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 46% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 47% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 48% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 49% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 50% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 51% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 52% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 53% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 54% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 55% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 56% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 57% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 58% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 59% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% 4,861$ 60% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 61% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 62% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 63% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 64% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 65% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 66% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 67% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 68% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 69% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 70% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 71% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 72% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 73% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 74% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 75% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 76% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 77% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 78% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$


79% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 80% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 81% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 82% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 83% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 84% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 85% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 86% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 87% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 88% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 89% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 90% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 91% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 92% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 93% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 94% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 95% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 96% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 97% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 98% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 99% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$

100% 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ >100% 0.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$ 0.00% 100.00% -$

(415)$ (1,814)$ (1,015)$ 4,250$


Demand Rate Success Criteria

Revenue Neutral Cost Based Price Signals

Minimal Intra Class Impacts

Understandability

Scenario 1

(Average weekday demand during peak)

Scenario 2

(Average of 5 weekday peaks during peak)

Scenario 3

(Average daily peaks during peak)

Scenario 4

(Maximum monthly demand)


0

2000000

4000000

6000000

8000000

10000000

12000000

14000000

0 5 10 15 20 25 30

kWhs

Hour

2014 MMA Usage Profile

Annual Summer Winter


0

10

20

30

40

50

60

0 5 10 15 20 25 30

kWhs

Hour

2014 MMA Usage Profile per Unit

Annual per unit Summer per Unit Winter per Unit Residential Annual


0

2000000

4000000

6000000

8000000

10000000

12000000

14000000

16000000

0 5 10 15 20 25 30

kWhs

Hour




0

10

20

30

40

50

60

0 5 10 15 20 25 30

kWhs

Hour




0

2000000

4000000

6000000

8000000

10000000

12000000

14000000

16000000

0 5 10 15 20 25 30

kWhs

Hour




0

10

20

30

40

50

60

0 5 10 15 20 25 30

kWhs

Hour




Average Monthly Usage per Unit 2014 2015 2016

<100 14.6% 12.6% 15.5%100 1.0% 0.6% 1.8%110 0.8% 1.0% 0.9%120 0.4% 1.2% 1.6%130 0.2% 0.2% 1.5%140 0.5% 0.2% 0.9%150 0.9% 0.4% 0.9%160 0.3% 0.8% 0.3%170 0.5% 0.4% 0.4%180 0.6% 0.8% 0.6%190 0.6% 0.3% 0.7%200 1.0% 0.9% 0.7%210 1.2% 0.7% 0.8%220 0.4% 0.8% 0.7%230 1.2% 0.6% 0.6%240 1.2% 0.9% 1.1%250 0.8% 0.8% 1.6%260 1.2% 0.6% 1.3%270 1.5% 0.9% 1.2%280 2.0% 1.3% 1.3%290 1.5% 1.0% 1.0%300 1.3% 1.0% 1.1%310 2.2% 1.7% 1.5%320 2.0% 1.5% 1.6%330 1.6% 1.8% 2.1%340 2.2% 1.3% 2.4%350 2.3% 1.2% 2.8%360 2.4% 1.5% 2.4%370 3.2% 2.2% 1.8%380 2.4% 1.6% 1.8%390 2.3% 2.0% 2.6%400 2.5% 2.0% 2.6%410 2.9% 2.2% 1.9%420 2.6% 2.1% 2.5%430 2.8% 2.0% 2.4%440 1.7% 1.3% 1.6%450 1.8% 1.5% 2.5%460 1.2% 2.7% 1.7%470 1.4% 2.0% 1.5%480 2.4% 3.3% 1.6%490 1.4% 1.6% 2.0%500 1.9% 2.7% 1.2%510 1.5% 1.7% 1.9%520 1.2% 2.1% 1.6%530 1.3% 1.6% 0.8%540 1.1% 1.0% 1.2%550 1.1% 1.5% 0.4%560 0.4% 1.7% 1.0%

Percentage of Units



Percentage of Units

570 1.3% 1.8% 0.7%580 1.2% 1.3% 0.8%590 0.8% 0.8% 0.9%600 1.1% 0.6% 0.7%610 1.0% 0.8% 0.8%620 0.6% 0.7% 1.0%630 0.4% 1.0% 0.4%640 0.3% 1.0% 0.7%650 0.6% 1.3% 1.1%660 0.5% 0.7% 0.2%670 0.4% 0.4% 0.3%680 0.3% 0.8% 0.1%690 0.1% 0.8% 0.1%700 0.1% 0.7% 0.3%710 0.0% 0.7% 0.1%720 0.6% 0.6% 0.7%730 0.1% 0.2% 0.0%740 0.2% 0.4% 0.2%750 0.2% 0.3% 0.2%760 0.3% 0.1% 0.2%770 0.3% 0.6% 0.1%780 0.2% 0.4% 0.3%790 0.0% 0.2% 0.1%800 0.2% 0.1% 0.1%810 0.3% 0.1% 0.2%820 0.3% 0.4% 0.0%830 0.2% 0.2% 0.0%840 0.2% 0.2% 0.2%850 0.3% 0.0% 0.1%860 0.2% 0.4% 0.6%870 0.0% 0.0% 0.1%880 0.1% 0.1% 0.4%890 0.2% 0.2% 0.0%900 0.0% 0.1% 0.1%910 0.0% 0.0% 0.1%920 0.1% 0.2% 0.0%930 0.2% 0.1% 0.1%940 0.1% 0.3% 0.0%950 0.1% 0.2% 0.3%960 0.0% 0.6% 0.2%970 0.0% 0.0% 0.1%980 0.2% 0.0% 0.0%990 0.2% 0.1% 0.6%

1,000 0.1% 0.1% 0.1%1,010 0.2% 0.2% 0.1%1,020 0.1% 0.1% 0.0%1,030 0.0% 0.0% 0.2%1,040 0.1% 0.1% 0.0%



Percentage of Units

1,050 0.0% 0.3% 0.0%1,060 0.1% 0.1% 0.1%1,070 0.0% 0.1% 0.0%1,080 0.0% 0.0% 0.0%1,090 0.0% 0.1% 0.0%1,100 0.1% 0.0% 0.0%1,110 0.1% 0.1% 0.1%1,120 0.0% 0.0% 0.0%1,130 0.0% 0.2% 0.0%1,140 0.0% 0.1% 0.0%1,150 0.1% 0.0% 0.1%1,160 0.0% 0.1% 0.1%1,170 0.3% 0.3% 0.0%1,180 0.0% 0.0% 0.1%1,190 0.0% 0.1% 0.0%1,200 0.0% 0.0% 0.1%1,210 0.1% 0.0% 0.0%1,220 0.0% 0.0% 0.0%1,230 0.0% 0.0% 0.1%1,240 0.2% 0.1% 0.2%1,250 0.0% 0.0% 0.1%1,260 0.0% 0.2% 0.0%1,270 0.0% 0.0% 0.0%1,280 0.0% 0.0% 0.0%1,290 0.0% 0.0% 0.0%1,300 0.0% 0.0% 0.0%1,310 0.0% 0.0% 0.1%1,320 0.2% 0.1% 0.0%1,330 0.0% 0.0% 0.0%1,340 0.0% 0.0% 0.0%1,350 0.0% 0.1% 0.0%1,360 0.0% 0.0% 0.0%1,370 0.0% 0.1% 0.0%1,380 0.0% 0.0% 0.1%1,390 0.2% 0.0% 0.0%1,400 0.0% 0.1% 0.0%1,410 0.0% 0.0% 0.1%1,420 0.0% 0.0% 0.0%1,430 0.0% 0.0% 0.0%1,440 0.0% 0.0% 0.0%1,450 0.0% 0.0% 0.0%1,460 0.0% 0.0% 0.0%1,470 0.0% 0.1% 0.0%1,480 0.0% 0.0% 0.1%1,490 0.0% 0.0% 0.0%1,500 0.0% 0.0% 0.0%1,510 0.0% 0.0% 0.1%1,520 0.0% 0.0% 0.0%



Percentage of Units

1,530 0.0% 0.1% 0.0%1,540 0.0% 0.0% 0.0%1,550 0.0% 0.1% 0.0%1,560 0.0% 0.0% 0.0%1,570 0.0% 0.0% 0.0%1,580 0.0% 0.0% 0.0%1,590 0.0% 0.0% 0.0%1,600 0.0% 0.1% 0.0%1,610 0.0% 0.0% 0.0%1,620 0.0% 0.1% 0.0%1,630 0.0% 0.0% 0.0%1,640 0.0% 0.0% 0.0%1,650 0.1% 0.0% 0.0%1,660 0.0% 0.0% 0.0%1,670 0.0% 0.0% 0.0%1,680 0.0% 0.0% 0.0%1,690 0.0% 0.0% 0.0%1,700 0.0% 0.0% 0.0%1,710 0.0% 0.0% 0.0%1,720 0.0% 0.0% 0.0%1,730 0.0% 0.0% 0.0%1,740 0.0% 0.0% 0.0%1,750 0.0% 0.0% 0.0%1,760 0.0% 0.0% 0.1%1,770 0.0% 0.0% 0.0%1,780 0.0% 0.0% 0.0%1,790 0.0% 0.0% 0.0%1,800 0.0% 0.0% 0.0%1,810 0.0% 0.0% 0.0%1,820 0.0% 0.0% 0.0%1,830 0.0% 0.0% 0.0%1,840 0.0% 0.0% 0.0%1,850 0.0% 0.0% 0.0%1,860 0.0% 0.0% 0.0%1,870 0.0% 0.0% 0.0%1,880 0.0% 0.0% 0.0%1,890 0.0% 0.0% 0.1%1,900 0.0% 0.0% 0.0%1,910 0.0% 0.0% 0.0%1,920 0.0% 0.0% 0.0%1,930 0.0% 0.0% 0.0%1,940 0.0% 0.1% 0.0%1,950 0.0% 0.0% 0.0%1,960 0.0% 0.0% 0.0%1,970 0.0% 0.0% 0.0%1,980 0.0% 0.0% 0.0%1,990 0.1% 0.0% 0.0%2,000 0.0% 0.0% 0.0%



Percentage of Units

>2000 0.4% 0.7% 0.6%100.0% 100.0% 100.0%


Dwelling Units Average Monthly Usage per Unit4 - 4 10 4 10 4 10 4 10 4 10 4 10 4 10 4 10 4 20 4 20 4 20 4 30 4 30 4 40 4 40 4 40 4 40 4 40 4 50 4 50 4 50 4 60 4 70 4 70 4 80 4 80 4 100 4 150 4 170 4 170 4 180 4 190 4 190 4 210 4 220 4 230 4 230 4 230 4 240 4 240 4 250 4 260 4 260 4 260 4 270 4 270 4 270 4 270 4 270 4 280 4 290


Dwelling Units Average Monthly Usage per Unit4 300 4 310 4 310 4 310 4 310 4 310 4 310 4 310 4 320 4 320 4 330 4 330 4 340 4 340 4 350 4 350 4 350 4 360 4 360 4 370 4 370 4 380 4 380 4 390 4 410 4 410 4 410 4 420 4 430 4 450 4 460 4 490 4 500 4 520 4 570 4 590 4 670 4 680 4 930 4 1,020 5 10 5 10 5 20 5 50 5 110 5 150 5 170 5 180 5 210 5 210 5 230 5 230


Dwelling Units Average Monthly Usage per Unit5 240 5 250 5 280 5 350 5 370 5 430 5 510 5 660 5 860 6 10 6 60 6 90 6 140 6 160 6 200 6 210 6 260 6 280 6 320 6 320 6 370 6 430 6 440 7 20 7 20 7 60 7 100 7 280 7 310 7 360 7 410 7 420 7 460 8 - 8 10 8 20 8 40 8 60 8 190 8 200 8 200 8 230 8 250 8 260 8 260 8 270 8 280 8 280 8 290 8 300 8 330 8 330


Dwelling Units Average Monthly Usage per Unit8 360 8 370 8 370 8 370 8 390 8 420 8 650 8 990 8 1,240 8 1,320 9 10 9 50 9 90 9 170 9 270 9 280 9 290 9 320 9 340 9 360 9 420 9 450 9 510 9 510 9 510 9 550 9 550 9 560 9 990

10 40 10 50 10 220 10 280 10 340 10 340 10 380 10 410 10 450 10 450 10 460 10 470 10 480 10 480 10 480 10 500 10 520 10 550 10 610 11 10 11 30 11 40 11 100


Dwelling Units Average Monthly Usage per Unit11 130 11 200 11 230 11 260 11 330 11 350 11 390 11 400 11 430 11 480 11 500 12 10 12 30 12 50 12 50 12 60 12 60 12 100 12 100 12 100 12 150 12 200 12 230 12 240 12 310 12 310 12 320 12 340 12 350 12 370 12 370 12 380 12 380 12 410 12 420 12 420 12 430 12 430 12 440 12 450 12 460 12 490 12 510 12 520 12 530 12 570 12 600 12 600 12 600 12 630


Dwelling Units Average Monthly Usage per Unit12 630 12 830 12 830 12 1,100 13 30 13 30 13 30 13 40 13 40 13 80 13 140 13 150 13 200 13 200 13 240 13 270 13 280 13 280 13 300 13 330 13 370 13 390 13 400 13 400 13 400 13 420 13 430 13 430 13 480 13 530 13 550 13 560 13 600 13 650 13 720 13 950 14 20 14 30 14 40 14 50 14 60 14 110 14 150 14 300 14 360 14 360 14 380 14 380 14 400 14 410


Dwelling Units Average Monthly Usage per Unit14 410 14 420 14 420 14 430 14 450 14 460 14 470 14 520 14 550 14 580 14 580 14 590 14 620 15 20 15 30 15 80 15 150 15 150 15 160 15 310 15 320 15 320 15 380 15 410 15 410 15 420 15 420 15 430 15 510 15 530 15 600 15 640 15 740 16 - 16 30 16 40 16 240 16 290 16 330 16 330 16 340 16 380 16 410 16 420 16 470 17 30 17 240 17 280 17 290 17 340


Dwelling Units Average Monthly Usage per Unit17 360 17 370 17 380 17 420 17 430 18 - 18 20 18 50 18 60 18 120 18 300 18 360 18 370 18 380 18 400 18 400 18 410 18 430 18 430 18 440 18 460 18 470 18 480 18 500 18 520 18 540 18 620 18 620 18 660 18 690 18 700 19 270 19 270 19 290 19 320 19 370 19 410 19 610 19 980 20 120 20 240 20 430 20 430 20 440 20 450 20 460 20 480 20 510 20 570 20 590


Dwelling Units Average Monthly Usage per Unit20 600 20 630 20 640 20 720 20 850 20 860 21 10 21 60 21 220 21 290 21 360 21 410 21 440 21 460 21 490 21 520 22 70 22 340 22 370 22 430 22 440 22 480 22 500 22 510 22 530 22 540 22 590 22 650 22 780 22 820 23 90 23 380 23 450 24 90 24 100 24 110 24 180 24 240 24 260 24 480 24 530 24 530 24 530 24 550 24 570 24 570 24 610 24 850 25 50 25 50


Dwelling Units Average Monthly Usage per Unit25 260 25 330 25 330 25 330 25 380 25 410 25 490 26 390 26 430 26 480 26 500 26 1,170 27 210 27 300 27 340 27 360 27 370 27 390 28 60 28 60 28 60 28 110 28 210 28 230 28 290 28 300 28 300 28 360 28 370 28 390 28 450 28 490 28 500 28 530 28 620 28 1,390 29 30 29 40 29 220 29 340 29 350 29 360 29 370 29 440 30 70 30 170 30 310 30 360 30 360 30 400


Dwelling Units Average Monthly Usage per Unit30 400 30 400 30 500 30 610 30 980 31 10 31 50 31 340 31 350 31 380 31 390 31 390 31 400 31 420 32 350 32 430 32 590 33 60 33 430 34 - 34 30 34 40 34 310 34 380 34 400 35 20 35 230 35 280 35 300 35 350 35 360 35 440 36 30 36 140 36 230 36 390 36 460 36 470 36 720 36 760 37 30 37 30 37 40 37 80 37 190 37 300 37 320 37 350 37 350 37 450


Dwelling Units Average Monthly Usage per Unit37 500 37 550 37 570 37 650 38 310 38 320 38 390 39 70 39 280 39 290 40 40 40 380 40 410 40 750 41 320 41 350 42 60 42 270 42 400 42 400 42 440 42 450 42 470 42 500 43 50 43 320 43 350 43 380 43 400 43 410 43 440 43 450 43 470 43 480 44 540 44 580 44 600 44 1,010 45 370 46 330 47 380 47 600 48 70 48 180 48 370 48 490 48 1,150 49 350 49 370 49 400


Dwelling Units Average Monthly Usage per Unit49 430 49 430 49 430 49 430 50 420 50 470 50 660 51 650 51 680 51 2,130 52 40 52 50 52 340 54 270 54 720 54 1,040 55 370 55 420 56 550 57 440 57 680 58 370 58 370 58 390 59 210 59 460 59 470 59 540 60 210 60 360 60 370 60 380 60 390 60 2,400 61 400 61 410 61 480 61 480 62 120 63 20 63 140 64 310 64 330 64 510 64 1,170 65 400 65 500 66 110 66 410 66 620


Dwelling Units Average Monthly Usage per Unit67 250 67 360 69 110 70 330 70 380 70 500 71 350 71 480 72 320 72 350 72 560 73 310 74 410 75 490 75 760 76 70 76 310 76 500 77 490 77 890 78 620 78 670 79 320 80 810 81 590 83 320 84 290 84 430 86 600 87 250 87 530 88 140 88 410 88 570 89 340 89 450 89 490 92 580 93 770 93 1,320 94 60 94 190 94 340 94 340 94 360 96 180 96 240 96 610 97 280 99 500


Dwelling Units Average Monthly Usage per Unit99 810

100 280 100 290 100 300 100 320 100 390 100 420 100 540 100 570 101 290 102 350 102 410 103 670 104 240 104 310 104 400 105 840 107 450 107 480 108 250 108 480 109 320 109 540 110 100 110 200 110 390 113 40 113 250 114 340 115 470 115 530 115 610 115 770 116 580 116 640 116 1,000 118 300 118 320 118 460 119 380 120 40 120 400 120 440 120 540 120 610 123 430 123 440 124 490 125 120 125 330


Dwelling Units Average Monthly Usage per Unit126 260 126 2,290 127 390 128 350 128 400 128 420 128 780 128 820 129 370 134 480 135 420 135 580 135 920 137 850 138 370 138 420 140 490 141 610 142 340 142 480 143 800 144 390 145 420 145 800 146 490 147 510 150 340 150 630 152 360 155 480 155 570 156 480 158 60 158 560 160 500 161 10 161 430 163 50 163 90 163 190 165 60 166 370 168 110 168 580 169 40 169 50 169 490 169 510 169 810 170 400


Dwelling Units Average Monthly Usage per Unit181 390 183 520 184 420 184 470 186 40 195 410 195 480 195 1,170 196 390 199 840 200 40 200 470 203 440 203 570 204 410 206 440 207 590 209 520 214 80 216 550 217 210 223 100 224 530 225 510 227 270 234 480 235 550 241 930 246 720 250 660 251 880 258 420 259 180 265 350 270 450 271 410 274 510 274 540 275 530 276 520 276 610 277 660 279 600 280 570 281 370 281 520 282 730 285 1,210 288 770 290 360


Dwelling Units Average Monthly Usage per Unit294 410 304 470 306 130 306 750 306 890 307 440 320 540 328 500 328 510 343 500 352 10 352 210 352 280 358 540 359 740 370 580 391 280 402 720 430 10 457 30 488 280 536 350 557 450 558 390 570 390


Pepco - District of ColumbiaProposed MMA Demand Charge StructureScenario 1

10%



Total Customer 666,144 11.84$ 7,887,145$ 666,144 11.84$ 7,887,145$

Distribution Demand - -$ -$ 414,598 0.89446$ 370,840$


Summer 102,291,135 0.00759$ 776,390$ 102,291,135 0.01030$ 1,053,599$ Winter 120,737,482 0.00759$ 916,397$ 120,737,482 0.01030$ 1,243,596$

Over 400 kWhSummer 74,535,319 0.02166$ 1,614,435$ 74,535,319 0.01030$ 767,714$ Winter 26,532,777 0.01512$ 401,176$ 26,532,777 0.01030$ 273,288$

Total kWh Charge 324,096,713 3,708,398$ 324,096,713 3,338,196$




10%



Total Customer 666,144 11.84$ 7,887,145$ 666,144 11.84$ 7,887,145$



Summer 102,291,135 0.00759$ 776,390$ 102,291,135 0.01030$ 1,053,599$ Winter 120,737,482 0.00759$ 916,397$ 120,737,482 0.01030$ 1,243,596$


Total kWh Charge 324,096,713 3,708,398$ 324,096,713 3,338,196$



Pepco - District of ColumbiaProposed MMA Demand Charge StructureScenario 3 with Existing Block Rleationships

10% 1 1.35



Total Customer 666,144 11.84$ 7,887,145$ 666,144 11.84$ 7,887,145$



Summer 102,291,135 0.00759$ 776,390$ 102,291,135 0.00683$ 698,751$ Winter 120,737,482 0.00759$ 916,397$ 120,737,482 0.00683$ 824,757$

Over 400 kWhSummer 74,535,319 0.02166$ 1,614,435$ 74,535,319 0.01949$ 1,452,992$ Winter 26,532,777 0.01512$ 401,176$ 26,532,777 0.01361$ 361,058$

Total kWh Charge 324,096,713 3,708,398$ 324,096,713 3,337,558$


486.5265063

280,517,564


Pepco - District of ColumbiaProposed MMA Demand Charge StructureScenario 3 with Alternative Block Rleationships

10% 1.35



Total Customer 666,144 11.84$ 7,887,145$ 666,144 11.84$ 7,887,145$



Summer 102,291,135 0.00759$ 776,390$ 102,291,135 0.00922$ 943,314$ Winter 120,737,482 0.00759$ 916,397$ 120,737,482 0.00922$ 1,113,422$

Over 400 kWhSummer 74,535,319 0.02166$ 1,614,435$ 74,535,319 0.01376$ 1,025,894$ Winter 26,532,777 0.01512$ 401,176$ 26,532,777 0.00961$ 254,928$

Total kWh Charge 324,096,713 3,708,398$ 324,096,713 3,337,558$


486.5265063

280,517,564


Pepco - District of ColumbiaDistribution Demand Rate StructureMMA Bill Impact Frequency Distribution - 201410% Demand Rate Recovery













-31% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -30% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -29% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -28% 0.00% 0.00% -$ 0.11% 0.11% (676)$ 0.00% 0.00% -$ 0.00% 0.00% -$ -27% 0.00% 0.00% -$ 0.00% 0.11% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -26% 0.00% 0.00% -$ 0.00% 0.11% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -25% 0.00% 0.00% -$ 0.00% 0.11% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -24% 0.11% 0.11% (287)$ 0.34% 0.45% (28,153)$ 0.11% 0.11% (288)$ 0.00% 0.00% -$ -23% 0.22% 0.34% (26,450)$ 0.22% 0.67% (7,124)$ 0.34% 0.45% (33,317)$ 0.00% 0.00% -$ -22% 0.22% 0.56% (7,297)$ 0.00% 0.67% -$ 0.11% 0.56% (531)$ 0.22% 0.22% (24,910)$ -21% 0.00% 0.56% -$ 0.00% 0.67% -$ 0.00% 0.56% -$ 0.11% 0.34% (6,348)$ -20% 0.11% 0.67% (987)$ 0.00% 0.67% -$ 0.11% 0.67% (990)$ 0.22% 0.56% (724)$ -19% 0.00% 0.67% -$ 0.11% 0.78% (2,244)$ 0.11% 0.78% (237)$ 0.00% 0.56% -$ -18% 0.22% 0.90% (2,439)$ 0.00% 0.78% -$ 0.11% 0.90% (2,210)$ 0.11% 0.67% (918)$ -17% 0.11% 1.01% (246)$ 0.22% 1.01% (6,436)$ 0.11% 1.01% (247)$ 0.00% 0.67% -$ -16% 0.56% 1.57% (23,120)$ 0.56% 1.57% (26,086)$ 0.56% 1.57% (23,206)$ 0.22% 0.90% (2,157)$ -15% 0.00% 1.57% -$ 0.22% 1.79% (15,576)$ 0.00% 1.57% -$ 0.11% 1.01% (5,609)$ -14% 0.34% 1.91% (22,860)$ 0.00% 1.79% -$ 0.34% 1.91% (22,958)$ 0.22% 1.23% (14,103)$ -13% 0.11% 2.02% (383)$ 0.34% 2.13% (1,638)$ 0.11% 2.02% (385)$ 0.34% 1.57% (21,772)$ -12% 0.34% 2.35% (3,287)$ 0.22% 2.35% (2,190)$ 0.34% 2.35% (3,303)$ 0.22% 1.79% (774)$ -11% 0.34% 2.69% (3,026)$ 0.11% 2.47% (1,170)$ 0.34% 2.69% (3,042)$ 0.22% 2.02% (1,068)$ -10% 0.45% 3.14% (1,012)$ 0.67% 3.14% (15,844)$ 0.45% 3.14% (1,018)$ 0.11% 2.13% (412)$ -9% 0.56% 3.70% (19,734)$ 0.78% 3.92% (16,666)$ 0.67% 3.81% (23,191)$ 0.34% 2.47% (8,925)$ -8% 1.12% 4.82% (29,422)$ 0.67% 4.60% (18,314)$ 1.01% 4.82% (26,283)$ 0.56% 3.03% (5,009)$ -7% 1.01% 5.83% (16,631)$ 1.35% 5.94% (26,514)$ 1.01% 5.83% (16,758)$ 0.56% 3.59% (18,470)$ -6% 0.90% 6.73% (9,924)$ 0.78% 6.73% (7,970)$ 0.90% 6.73% (10,009)$ 1.35% 4.93% (22,115)$ -5% 0.45% 7.17% (5,677)$ 0.45% 7.17% (4,985)$ 0.45% 7.17% (5,732)$ 0.78% 5.72% (7,979)$ -4% 1.12% 8.30% (8,077)$ 0.78% 7.96% (5,335)$ 1.12% 8.30% (8,177)$ 0.67% 6.39% (4,806)$ -3% 1.23% 9.53% (8,314)$ 1.35% 9.30% (10,905)$ 1.23% 9.53% (8,455)$ 0.90% 7.29% (6,469)$ -2% 2.02% 11.55% (6,371)$ 2.13% 11.43% (7,283)$ 2.24% 11.77% (7,097)$ 1.23% 8.52% (2,793)$ -1% 2.58% 14.13% (4,331)$ 2.69% 14.13% (3,377)$ 2.35% 14.13% (3,970)$ 1.35% 9.87% (3,770)$ 0% 5.04% 19.17% 871$ 3.59% 17.71% 128$ 5.16% 19.28% 703$ 3.70% 13.57% 264$ 1% 8.97% 28.14% 6,972$ 8.07% 25.78% 6,806$ 9.08% 28.36% 7,581$ 7.62% 21.19% 7,598$ 2% 6.73% 34.87% 14,388$ 8.52% 34.30% 15,816$ 6.50% 34.87% 13,381$ 6.17% 27.35% 12,206$ 3% 9.87% 44.73% 29,551$ 8.86% 43.16% 33,568$ 10.09% 44.96% 30,471$ 7.40% 34.75% 20,279$ 4% 10.99% 55.72% 47,999$ 9.30% 52.47% 37,940$ 10.76% 55.72% 46,342$ 8.30% 43.05% 45,546$ 5% 8.30% 64.01% 42,785$ 8.86% 61.32% 45,439$ 8.52% 64.24% 44,725$ 7.51% 50.56% 47,841$ 6% 11.10% 75.11% 45,236$ 8.30% 69.62% 45,420$ 11.32% 75.56% 44,284$ 6.61% 57.17% 44,541$ 7% 13.00% 88.12% 60,967$ 13.57% 83.18% 60,717$ 12.89% 88.45% 60,211$ 8.52% 65.70% 48,320$ 8% 8.86% 96.97% 29,423$ 9.42% 92.60% 29,430$ 8.63% 97.09% 28,276$ 12.44% 78.14% 78,499$ 9% 2.47% 99.44% 9,541$ 5.16% 97.76% 14,071$ 2.35% 99.44% 9,411$ 10.65% 88.79% 41,020$

10% 0.56% 100.00% 4,197$ 1.46% 99.22% 5,690$ 0.56% 100.00% 4,181$ 6.39% 95.18% 14,552$ 11% 0.45% 99.66% 468$ 2.35% 97.53% 4,266$ 12% 0.22% 99.89% 141$ 1.35% 98.88% 1,671$ 13% 0.11% 100.00% 80$ 0.67% 99.55% 882$ 14% 0.11% 99.66% 99$ 15% 0.00% 99.66% -$ 16% 0.34% 100.00% 333$

92,056$ 87,228$ 88,165$ 208,453$
















-31% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -30% 0.11% 0.11% (762)$ 0.00% 0.00% -$ 0.11% 0.11% (762)$ 0.00% 0.00% -$ -29% 0.00% 0.11% -$ 0.11% 0.11% (756)$ 0.00% 0.11% -$ 0.00% 0.00% -$ -28% 0.00% 0.11% -$ 0.00% 0.11% -$ 0.00% 0.11% -$ 0.00% 0.00% -$ -27% 0.00% 0.11% -$ 0.00% 0.11% -$ 0.00% 0.11% -$ 0.00% 0.00% -$ -26% 0.11% 0.22% (342)$ 0.11% 0.22% (10,714)$ 0.11% 0.22% (342)$ 0.11% 0.11% (10,793)$ -25% 0.22% 0.45% (30,726)$ 0.22% 0.45% (8,372)$ 0.22% 0.45% (30,866)$ 0.22% 0.34% (21,342)$ -24% 0.11% 0.56% (7,925)$ 0.00% 0.45% -$ 0.11% 0.56% (7,956)$ 0.22% 0.56% (8,345)$ -23% 0.00% 0.56% -$ 0.00% 0.45% -$ 0.00% 0.56% -$ 0.00% 0.56% -$ -22% 0.11% 0.67% (347)$ 0.11% 0.56% (338)$ 0.11% 0.67% (347)$ 0.00% 0.56% -$ -21% 0.11% 0.78% (896)$ 0.22% 0.79% (3,562)$ 0.11% 0.78% (897)$ 0.11% 0.67% (325)$ -20% 0.11% 0.90% (2,642)$ 0.00% 0.79% -$ 0.11% 0.90% (2,642)$ 0.22% 0.90% (3,460)$ -19% 0.22% 1.12% (12,622)$ 0.22% 1.01% (12,792)$ 0.34% 1.23% (12,878)$ 0.22% 1.12% (12,736)$ -18% 0.45% 1.57% (14,974)$ 0.22% 1.23% (827)$ 0.22% 1.46% (14,542)$ 0.22% 1.35% (14,517)$ -17% 0.11% 1.68% (766)$ 0.11% 1.35% (765)$ 0.34% 1.79% (1,189)$ 0.11% 1.46% (208)$ -16% 0.45% 2.13% (18,126)$ 0.45% 1.80% (1,059)$ 0.34% 2.13% (18,017)$ 0.22% 1.68% (18,301)$ -15% 0.45% 2.58% (6,054)$ 0.34% 2.13% (5,437)$ 0.34% 2.47% (5,405)$ 0.22% 1.91% (2,412)$ -14% 0.11% 2.69% (410)$ 0.22% 2.36% (1,049)$ 0.22% 2.69% (1,063)$ 0.67% 2.58% (4,109)$ -13% 0.34% 3.03% (14,268)$ 0.11% 2.47% (866)$ 0.34% 3.03% (14,294)$ 0.34% 2.92% (14,939)$ -12% 0.78% 3.81% (16,213)$ 0.67% 3.14% (13,333)$ 0.78% 3.81% (16,258)$ 0.34% 3.25% (10,934)$ -11% 0.90% 4.71% (19,742)$ 1.01% 4.15% (16,997)$ 0.90% 4.71% (19,785)$ 0.79% 4.04% (23,657)$ -10% 1.46% 6.17% (52,587)$ 1.01% 5.16% (11,468)$ 1.57% 6.28% (56,846)$ 1.35% 5.39% (49,307)$ -9% 1.12% 7.29% (21,599)$ 0.90% 6.06% (16,978)$ 1.01% 7.29% (17,552)$ 1.35% 6.73% (22,059)$ -8% 0.67% 7.96% (13,953)$ 0.45% 6.51% (3,515)$ 0.78% 8.07% (15,555)$ 1.01% 7.74% (18,036)$ -7% 1.35% 9.30% (13,142)$ 1.12% 7.63% (8,147)$ 1.23% 9.30% (11,578)$ 0.56% 8.31% (3,288)$ -6% 1.46% 10.76% (20,111)$ 1.46% 9.09% (12,440)$ 1.46% 10.76% (20,100)$ 1.35% 9.65% (16,365)$ -5% 1.91% 12.67% (17,471)$ 1.68% 10.77% (13,266)$ 1.91% 12.67% (17,584)$ 2.24% 11.90% (20,931)$ -4% 2.35% 15.02% (20,045)$ 2.24% 13.02% (16,500)$ 2.58% 15.25% (20,225)$ 2.13% 14.03% (21,946)$ -3% 2.02% 17.04% (9,733)$ 1.68% 14.70% (4,066)$ 1.79% 17.04% (9,605)$ 2.36% 16.39% (14,869)$ -2% 2.58% 19.62% (8,122)$ 2.58% 17.28% (6,813)$ 2.58% 19.62% (9,042)$ 2.02% 18.41% (5,677)$ -1% 3.48% 23.09% (5,989)$ 3.03% 20.31% (3,745)$ 3.48% 23.09% (5,049)$ 2.81% 21.21% (6,133)$ 0% 6.95% 30.04% (468)$ 5.72% 26.04% 333$ 6.61% 29.71% (464)$ 4.26% 25.48% 258$ 1% 10.20% 40.25% 9,464$ 10.33% 36.36% 8,668$ 10.20% 39.91% 9,451$ 8.08% 33.56% 9,120$ 2% 10.65% 50.90% 19,658$ 9.76% 46.13% 14,977$ 10.65% 50.56% 19,670$ 9.20% 42.76% 18,593$ 3% 9.98% 60.87% 22,216$ 11.00% 57.13% 23,030$ 10.20% 60.76% 22,306$ 8.64% 51.40% 22,171$ 4% 8.41% 69.28% 28,627$ 8.42% 65.54% 23,661$ 8.41% 69.17% 28,589$ 9.88% 61.28% 25,863$ 5% 9.98% 79.26% 39,479$ 10.44% 75.98% 29,372$ 9.64% 78.81% 38,773$ 10.10% 71.38% 41,360$ 6% 8.18% 87.44% 24,647$ 7.41% 83.39% 23,871$ 8.41% 87.22% 25,641$ 7.63% 79.01% 21,553$ 7% 7.40% 94.84% 24,153$ 8.64% 92.03% 29,152$ 7.96% 95.18% 26,150$ 7.74% 86.76% 29,385$ 8% 3.81% 98.65% 31,960$ 5.16% 97.19% 31,852$ 3.59% 98.77% 30,023$ 8.19% 94.95% 40,184$ 9% 1.12% 99.78% 9,355$ 2.36% 99.55% 12,189$ 1.01% 99.78% 9,335$ 2.36% 97.31% 9,862$

10% 0.22% 100.00% 8,032$ 0.45% 100.00% 1,198$ 0.22% 100.00% 8,037$ 1.35% 98.65% 9,641$ 11% 0.56% 99.21% 323$ 12% 0.56% 99.78% 390$ 13% 0.11% 99.89% 70$ 14% 0.00% 99.89% -$ 15% 0.11% 100.00% 140$

(112,443)$ 24,501$ (112,868)$ (95,775)$
















-31% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -30% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -29% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -28% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -27% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -26% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -25% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -24% 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ 0.00% 0.00% -$ -23% 0.11% 0.11% (266)$ 0.22% 0.22% (25,551)$ 0.00% 0.00% -$ 0.22% 0.22% (25,917)$ -22% 0.22% 0.32% (24,931)$ 0.11% 0.32% (262)$ 0.00% 0.00% -$ 0.22% 0.43% (6,473)$ -21% 0.22% 0.54% (6,343)$ 0.11% 0.43% (6,128)$ 0.00% 0.00% -$ 0.00% 0.43% -$ -20% 0.00% 0.54% -$ 0.11% 0.54% (313)$ 0.00% 0.00% -$ 0.11% 0.54% (315)$ -19% 0.00% 0.54% -$ 0.00% 0.54% -$ 0.00% 0.00% -$ 0.00% 0.54% -$ -18% 0.00% 0.54% -$ 0.00% 0.54% -$ 0.00% 0.00% (20,427)$ 0.00% 0.54% -$ -17% 0.22% 0.75% (2,193)$ 0.11% 0.65% (1,989)$ 0.00% 0.00% (5,160)$ 0.11% 0.65% (1,958)$ -16% 0.11% 0.86% (176)$ 0.22% 0.86% (5,737)$ 0.00% 0.00% -$ 0.11% 0.75% (5,683)$ -15% 0.32% 1.18% (9,237)$ 0.32% 1.18% (4,032)$ 0.00% 0.00% -$ 0.32% 1.08% (3,724)$ -14% 0.22% 1.40% (9,596)$ 0.11% 1.29% (9,494)$ 0.00% 0.00% -$ 0.32% 1.40% (24,126)$ -13% 0.43% 1.83% (14,486)$ 0.43% 1.72% (14,551)$ 0.00% 0.00% (2,005)$ 0.22% 1.61% (653)$ -12% 0.43% 2.26% (5,018)$ 0.54% 2.26% (5,418)$ 0.00% 0.00% (4,815)$ 0.32% 1.94% (3,510)$ -11% 0.32% 2.58% (832)$ 0.11% 2.37% (439)$ 0.00% 0.00% (20,837)$ 0.32% 2.26% (1,850)$ -10% 0.11% 2.69% (288)$ 0.11% 2.47% (255)$ 0.00% 0.00% (1,396)$ 0.22% 2.47% (665)$ -9% 0.54% 3.23% (9,074)$ 0.65% 3.12% (12,778)$ 0.00% 0.00% (3,191)$ 0.43% 2.90% (8,933)$ -8% 0.86% 4.09% (11,296)$ 0.86% 3.98% (10,260)$ 0.00% 0.00% (1,936)$ 0.97% 3.87% (16,565)$ -7% 0.97% 5.05% (18,755)$ 1.18% 5.16% (17,424)$ 0.00% 0.00% (9,741)$ 0.65% 4.52% (15,084)$ -6% 1.51% 6.56% (24,144)$ 1.29% 6.45% (24,094)$ 0.00% 0.00% (18,858)$ 1.51% 6.02% (22,921)$ -5% 0.54% 7.10% (6,085)$ 0.75% 7.20% (7,329)$ 0.00% 0.00% (9,955)$ 1.08% 7.10% (12,271)$ -4% 1.18% 8.28% (11,123)$ 0.86% 8.06% (8,957)$ 0.00% 0.00% (17,728)$ 0.86% 7.96% (5,331)$ -3% 1.18% 9.46% (2,828)$ 1.18% 9.25% (4,571)$ 0.00% 0.00% (8,856)$ 0.43% 8.39% (3,622)$ -2% 1.51% 10.97% (6,930)$ 1.51% 10.75% (6,811)$ 0.00% 0.00% (2,265)$ 1.83% 10.22% (4,431)$ -1% 2.04% 13.01% (2,621)$ 1.83% 12.58% (3,067)$ 0.00% 0.00% (3,665)$ 2.04% 12.26% (4,926)$ 0% 5.81% 18.82% 104$ 4.73% 17.31% 115$ 0.00% 0.00% (118)$ 4.41% 16.67% 243$ 1% 9.35% 28.17% 8,127$ 8.28% 25.59% 7,603$ 0.00% 0.00% 10,588$ 8.17% 24.84% 8,493$ 2% 8.49% 36.67% 16,706$ 9.89% 35.48% 17,776$ 0.00% 0.00% 20,687$ 7.10% 31.94% 15,827$ 3% 6.45% 43.12% 25,442$ 6.02% 41.51% 26,035$ 0.00% 0.00% 42,122$ 7.42% 39.35% 28,977$ 4% 8.28% 51.40% 44,190$ 7.74% 49.25% 40,907$ 0.00% 0.00% 41,817$ 7.74% 47.10% 40,359$ 5% 9.35% 60.75% 40,035$ 8.39% 57.63% 38,185$ 0.00% 0.00% 93,551$ 8.17% 55.27% 36,979$ 6% 13.55% 74.30% 70,813$ 12.15% 69.78% 66,417$ 0.00% 0.00% 44,078$ 10.22% 65.48% 59,880$ 7% 15.48% 89.78% 71,447$ 15.38% 85.16% 71,289$ 0.00% 0.00% 11,327$ 15.70% 81.18% 80,195$ 8% 8.17% 97.96% 46,468$ 10.32% 95.48% 54,607$ 0.00% 0.00% -$ 11.83% 93.01% 53,651$ 9% 1.61% 99.57% 15,061$ 3.55% 99.03% 15,721$ 0.00% 0.00% -$ 4.41% 97.42% 14,638$

10% 0.43% 100.00% 7,805$ 0.86% 99.89% 10,660$ 0.00% 0.00% -$ 1.72% 99.14% 8,938$ 11% 0.11% 100.00% 75$ 0.65% 99.78% 469$ 12% 0.22% 100.00% 165$

179,974$ 179,928$ 133,220$ 179,690$



Pepco - District of ColumbiaDistribution Demand Rate StructureMMA Bill Impact Frequency Distribution - 201610% Demand Rate Recovery with Existing Block Relationship

Distribution Bill Impact (%)

Average Monthly Usage per Unit




-2% 2,100 0.22% 0.22% (43)$ -1% 1,417 1.61% 1.83% (3,642)$ 0% 322 28.60% 30.43% 4,864$ 1% 387 68.71% 99.14% 64,394$ 2% 449 0.86% 100.00% 495$

66,068$


Pepco - District of ColumbiaDistribution Demand Rate StructureMMA Bill Impact Frequency Distribution - 201610% Demand Rate Recovery with Alternative Block Relationship

Distribution Bill Impact (%)

Average Monthly Usage per Unit




-18% 2,300 0.32% 0.32% (20,427)$ -17% 2,060 0.22% 0.54% (5,160)$ -13% 1,427 0.32% 0.86% (2,005)$ -12% 1,343 0.32% 1.18% (4,815)$ -11% 1,198 0.43% 1.61% (20,837)$ -10% 1,110 0.32% 1.94% (1,396)$ -9% 1,078 0.43% 2.37% (3,191)$ -8% 985 0.43% 2.80% (1,936)$ -7% 953 0.65% 3.44% (9,741)$ -6% 865 1.18% 4.62% (18,858)$ -5% 819 1.08% 5.70% (9,955)$ -4% 705 1.61% 7.31% (17,728)$ -3% 716 1.18% 8.49% (8,856)$ -2% 663 0.97% 9.46% (2,265)$ -1% 575 3.23% 12.69% (3,665)$ 0% 314 7.20% 19.89% (118)$ 1% 197 13.01% 32.90% 10,588$ 2% 304 8.39% 41.29% 20,687$ 3% 381 10.22% 51.51% 42,122$ 4% 359 14.30% 65.81% 41,817$ 5% 343 22.90% 88.71% 93,551$ 6% 337 10.00% 98.71% 44,078$ 7% 376 1.29% 100.00% 11,327$

133,220$


Pepco ‐ District of Columbia

GT‐LV and GT‐3A Load Factor Analysis Billing Data for 12 Months Actual Ending December 2016

GT‐3A GT‐LV

Cumulative CumulativeAnnual LF % of Customers % of Customers Annual LF % of Customers % of Customers

7.0% 0.6% 0.6% 0.0% 1.41% 1.41%9.0% 0.6% 1.3% 1.0% 0.34% 1.75%

13.0% 0.6% 1.9% 2.0% 0.17% 1.92%15.0% 0.6% 2.5% 3.0% 0.32% 2.24%16.0% 0.6% 3.2% 4.0% 0.20% 2.44%18.0% 1.3% 4.5% 5.0% 0.37% 2.82%20.0% 0.6% 5.1% 6.0% 0.23% 3.05%22.0% 1.3% 6.4% 7.0% 0.14% 3.19%23.0% 1.3% 7.6% 8.0% 0.26% 3.45%25.0% 0.6% 8.3% 9.0% 0.23% 3.68%27.0% 1.9% 10.2% 10.0% 0.43% 4.11%29.0% 1.3% 11.5% 11.0% 0.60% 4.71%30.0% 0.6% 12.1% 12.0% 0.49% 5.20%31.0% 1.9% 14.0% 13.0% 0.37% 5.57%32.0% 0.6% 14.6% 14.0% 0.66% 6.23%34.0% 1.3% 15.9% 15.0% 0.66% 6.89%35.0% 0.6% 16.6% 16.0% 0.46% 7.35%36.0% 0.6% 17.2% 17.0% 0.75% 8.10%37.0% 1.3% 18.5% 18.0% 0.86% 8.96%38.0% 2.5% 21.0% 19.0% 0.78% 9.74%39.0% 0.6% 21.7% 20.0% 0.92% 10.66%40.0% 2.5% 24.2% 21.0% 1.15% 11.81%41.0% 1.9% 26.1% 22.0% 1.38% 13.19%42.0% 1.3% 27.4% 23.0% 1.32% 14.51%43.0% 0.6% 28.0% 24.0% 1.03% 15.54%44.0% 0.6% 28.7% 25.0% 1.12% 16.66%45.0% 1.3% 29.9% 26.0% 1.41% 18.07%46.0% 0.6% 30.6% 27.0% 1.49% 19.56%47.0% 1.3% 31.8% 28.0% 1.90% 21.46%48.0% 1.9% 33.8% 29.0% 1.32% 22.78%49.0% 3.2% 36.9% 30.0% 2.24% 25.02%50.0% 2.5% 39.5% 31.0% 1.72% 26.75%51.0% 3.8% 43.3% 32.0% 2.04% 28.78%52.0% 1.3% 44.6% 33.0% 2.01% 30.80%53.0% 1.3% 45.9% 34.0% 2.21% 33.01%54.0% 1.9% 47.8% 35.0% 2.44% 35.45%55.0% 2.5% 50.3% 36.0% 2.38% 37.83%56.0% 4.5% 54.8% 37.0% 2.56% 40.39%




GT‐3A GT‐LV


57.0% 3.2% 58.0% 38.0% 2.38% 42.78%58.0% 8.3% 66.2% 39.0% 2.30% 45.07%59.0% 1.9% 68.2% 40.0% 2.07% 47.14%60.0% 2.5% 70.7% 41.0% 2.38% 49.53%61.0% 4.5% 75.2% 42.0% 1.98% 51.51%62.0% 3.2% 78.3% 43.0% 2.73% 54.24%63.0% 2.5% 80.9% 44.0% 2.90% 57.14%64.0% 2.5% 83.4% 45.0% 2.47% 59.61%65.0% 0.6% 84.1% 46.0% 2.70% 62.31%66.0% 1.3% 85.4% 47.0% 2.36% 64.67%67.0% 2.5% 87.9% 48.0% 2.10% 66.76%68.0% 1.9% 89.8% 49.0% 1.69% 68.46%69.0% 2.5% 92.4% 50.0% 1.87% 70.32%70.0% 0.6% 93.0% 51.0% 2.07% 72.39%71.0% 0.6% 93.6% 52.0% 2.07% 74.46%72.0% 1.3% 94.9% 53.0% 1.81% 76.27%73.0% 1.9% 96.8% 54.0% 1.75% 78.02%74.0% 0.6% 97.5% 55.0% 1.81% 79.83%75.0% 1.3% 98.7% 56.0% 1.72% 81.56%76.0% 0.6% 99.4% 57.0% 1.38% 82.94%78.0% 0.6% 100.0% 58.0% 0.95% 83.88%

59.0% 1.44% 85.32%60.0% 1.26% 86.58%61.0% 1.09% 87.68%62.0% 1.15% 88.83%63.0% 1.21% 90.03%64.0% 0.80% 90.84%65.0% 0.89% 91.73%66.0% 0.86% 92.59%67.0% 0.55% 93.13%68.0% 0.78% 93.91%69.0% 0.75% 94.66%70.0% 0.75% 95.40%71.0% 0.49% 95.89%72.0% 0.37% 96.27%73.0% 0.37% 96.64%74.0% 0.57% 97.21%75.0% 0.23% 97.44%




GT‐3A GT‐LV


76.0% 0.23% 97.67%77.0% 0.34% 98.02%78.0% 0.14% 98.16%79.0% 0.11% 98.28%80.0% 0.09% 98.36%81.0% 0.11% 98.48%82.0% 0.23% 98.71%83.0% 0.06% 98.76%84.0% 0.17% 98.94%85.0% 0.14% 99.08%86.0% 0.14% 99.22%87.0% 0.17% 99.40%88.0% 0.06% 99.45%89.0% 0.06% 99.51%90.0% 0.03% 99.54%91.0% 0.03% 99.57%92.0% 0.09% 99.66%93.0% 0.06% 99.71%94.0% 0.03% 99.74%95.0% 0.03% 99.77%96.0% 0.03% 99.80%>96% 0.20% 100.00%

PEPCO (E) - 7

- 1 -

Weather Normalization

How Are Sales (kWh) Weather Normalized?

The Company weather normalizes sales by making an additive weather

normalization adjustment to actual sales. The weather normalization adjustment is equal

to the amount of sales calculated to be above (or below) the sales that would have

occurred if the weather had been normal. The weather normalization adjustment is

estimated by multiplying the difference between actual weather and normal weather,

measured as degree days, by a weather normalization factor for each revenue class. For

example, if the observed weather during the month is 125 heating degree days and the

normal for the month is 100 heating degree days, then the difference of 25 heating degree

days will be multiplied times the class weather normalization factors for the different

classes to yield the class weather normalization adjustments.

Actual Weather

The weather parameter used in the Company’s monthly weather normalization is

degree days based on dry bulb temperatures recorded at the Reagan National Airport. The

calculation is illustrated in the simple example range of temperatures provided Table 1.

Degree days are calculated by averaging the hourly dry bulb temperature and calculating

the amount daily average dry bulb temperature in degrees Fahrenheit is over 65 for

Cooling Degree Days and under 65 for Heating Degree Days. For example, if the

average dry bulb temperature was 72, degree days for that day are 72- 65 or 7 cooling

degree days. This calculation is repeated for each day of the month and summed to

produce degrees days for the respective month. Table 2 presents actual degree days by

month used to weather normalize test-year period sales.

PEPCO (E) - 7

- 2 -

Normal Weather

Normal weather is defined as the average weather (heating degree days or cooling

degree days) over the most recent thirty year period prior to the period being weather

normalized. For each month, normal weather is calculated by taking the arithmetic

average of the most recent 30 years of heating degree days or cooling degree days for that

month. As an example, to calculate normal weather for a June 2017 weather

normalization adjustment, we would average the total monthly cooling degree days

observed in June over the period 1987-2016. Table 3 presents 30-year average degree

days by month used to weather normalize test-year period sales.

Weather Normalization Factor Estimation

Pepco’s weather normalization factors are prepared during the Company’s annual

weather normalization study covering data from the most recent heating and cooling

season. For example, in the 2017 study that was completed in December 2016, the

cooling period was defined as April 1, 2016 through September 30, 2016. The winter

period was defined as December 1, 2016 through March 31, 2017. Weather normalization

factors are estimated by regressing daily sales by class against daily heating or cooling

degrees. Each regression equation includes a constant term, weather variables measuring

heating and cooling degree days, and two dummy variables for Saturdays and Sundays.

Holidays are included as a separate dummy variable for each holiday.

Once the regression equation estimation step is complete, the coefficients

associated with the two heating (base 65 and base 35) degree day variables are

designated as the weather normalization factors for the heating season, by class.

Similarly, the coefficient in each equation for the cooling degrees term (base 65 ) is

designated as the weather normalization factor for the summer cooling season, by class.

PEPCO (E) - 7

- 3 -

Appendix A reports the weather normalized factors estimated for the use in 2017 and

2016.

PEPCO (E) - 7

- 4 -

Appendix

Table 1

Example of Cooling/Heating Degrees for a given Day

Observed Temperature Cooling Degrees (65) Heating Degrees (65)

55 0 10

65 0 0

72 7 0

PEPCO (E) - 7

- 5 -

Table 2

Observed Cooling/Heating Degrees (October 2016 – September 2017)

Oct‐16 Nov‐16 Dec‐16 Jan‐17 Feb‐17 Mar‐17 Apr‐17 May‐17 Jun‐17 Jul‐17 Aug‐17 Sep‐17

HDD 65 48 233 559 746 616 507 328 112 24 ‐ ‐ 5

HDD 35 ‐ ‐ 9 48 17 15 5 ‐ ‐ ‐ ‐ ‐

CDD 65 162 40 1 ‐ ‐ 2 34 89 227 458 445 286

PEPCO (E) - 7

- 6 -

Table 3

30-Year Average Cooling/Heating Degrees (October 2016 – September 2017)

Oct‐16 Nov‐16 Dec‐16 Jan‐17 Feb‐17 Mar‐17 Apr‐17 May‐17 Jun‐17 Jul‐17 Aug‐17 Sep‐17

HDD 65 96 338 608 812 845 637 411 157 35 1 ‐ 5

HDD 35 ‐ 1 18 62 81 31 3 ‐ ‐ ‐ ‐ ‐

CDD 65 112 13 1 0 0 2 12 61 220 404 460 335

PEPCO (E) - 7

- 7 -

Table 4

2017 & 2016 Weather Normalization Factors

PEPCO DC CDD 65 HDD 65 HDD 35 PEPCO DC CDD 65 HDD 65 HDD 35RES 244,748 101,276 96,999 RES 228,116 126,901 48,240 RTM 1,824 666 494 RTM 1,712 788 291 MMA 22,216 3,114 2,615 MMA 24,711 4,365 ‐ GSND 11,927 7,173 5,222 GSND 13,372 9,935 2,753 GSD 32,039 9,876 11,514 GSD 33,331 12,050 6,650 GTLV 193,462 54,090 98,864 GTLV 169,695 68,802 43,194 3A 98,276 ‐ ‐ 3A 89,717 ‐ 10,376 3B 1,337 555 ‐ 3B 1,105 15 ‐ MET 7,445 1,061 ‐ MET 4,433 848 ‐

2017 Weather Normalization Factors 2016 Weather Normalization Factors

Copyright © 2017 The Brattle Group, Inc.

Pepco DC Conditional Demand Analysis Methodology and Results

Pepco

Ahmad Faruqui, Ph.D. Sanem Sergici, Ph.D. Kevin Arritt Matthew Witkin

De c ember 2 0 1 7

P RE S EN TED T O

P RE S EN TED BY

PEPCO (E)-8Page 1 of 19 PEPCO (E)-8

Page 1 of 19

| brattle.com 1

Agenda Objective

Replication of Pepco Analysis

Literature Review and Benchmarking

Methodology

Results

Conclusions


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Objective Pepco retained The Brattle Group to review, replicate, and improve upon their existing Conditional Demand Analysis (CDA)

CDA is a regression-based approach to estimate end-use electricity consumption for major residential appliances

As part of our engagement with Pepco, we reviewed the literature and built a model which is consistent with best practices in CDA and estimated Annual End Use (AEUs) for major appliances

This slide deck presents the details of our analysis


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Replication Overview As a first step, we reproduced Pepco’s original results which were filed with the DC Public Service Commission as part of FC 1139 ▀ Reviewed Pepco’s methodology for processing raw survey data − Survey data is inherently incomplete with inconsistencies, so Pepco

created criteria for correcting inconsistencies − We found that Pepco’s data processing steps were adequate and

reasonable ▀ Specified an Ordinary Least Squares (OLS) regression designed to match

Pepco’s model, which excluded a constant term and excluded robust standard errors


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Replication Methodology After creating a replication of Pepco’s base model, we conducted the following steps to recreate Pepco’s AEUs

1. Estimated the aforementioned model, which is a panel datasetcontaining 1,993 unique customers, each with 365 days of consumptiondata for year.

2. Set all control variables to zero, except the variables related to thespecific appliance in question.

3. Created appliance usage predictions with the model

4. Multiplied the predicted value by the customer weights (provided byBellomy Research)

5. Summed the predicted usage for each appliance by month, so dataset iscustomer-month level

6. Averaged all customer AEUs, leaving one observation for each appliancefor each month.


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Replication Results We were able to exactly replicate Pepco’s conditional demand model. With respect to appliance-specific AEUs, we were able to recreate Pepco’s results, allowing for some rounding. However, our analysis indicates that Pepco may have switched “toaster” and “microwave” AEUs.

Parameter Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Year

heat 563.9 602.0 389.3 108.8 10.8 4.2 0.0 0.0 0.0 125.8 218.8 275.5 2,299.0ac 0.0 0.0 0.0 14.6 228.8 349.3 454.9 390.6 257.0 7.3 4.6 0.9 1,707.9ewtrh 116.1 116.0 94.6 60.9 50.7 48.0 49.4 49.6 48.0 64.6 74.1 80.9 852.9frig 55.2 49.9 54.8 53.4 55.2 53.1 55.3 55.4 53.6 55.3 53.3 55.0 649.6freez 10.9 9.9 10.9 10.7 11.1 10.7 11.1 11.1 10.7 11.0 10.7 11.0 129.9toaster 3.8 3.5 3.8 3.7 3.8 3.7 3.8 3.9 3.7 3.8 3.7 3.8 45.1micro 39.4 35.6 39.1 38.1 39.5 38.1 39.5 39.5 38.2 39.4 37.9 39.3 463.6vacuum 36.2 32.7 35.9 35.0 36.1 34.6 35.9 36.2 35.0 36.1 34.7 36.0 424.3washdry 22.0 19.9 21.8 21.3 22.0 21.2 21.9 22.0 21.3 21.9 21.2 21.9 258.4cooking 3.8 3.4 3.7 3.7 3.8 3.6 3.8 3.8 3.7 3.8 3.6 3.8 44.5tv 25.4 23.0 25.2 24.5 25.3 24.4 25.4 25.4 24.6 25.4 24.4 25.3 298.2incan 43.5 39.3 43.2 42.1 43.5 42.0 43.7 43.7 42.3 43.6 42.1 43.4 512.4otherlamp 4.0 3.7 4.0 3.9 4.0 3.9 4.0 4.1 3.9 4.0 3.9 4.0 47.5

Household total 924.2 938.8 726.3 420.7 534.6 636.7 748.7 685.2 542.3 442.1 533.0 600.7 7,733.2

Brattle Recreation

Pepco Output


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Literature Consulted After replicating Pepco’s analysis, we conducted a rigorous literature review to understand best practices for Conditional Demand Analysis (CDA) ▀ Parti and Parti, 1980 ▀ Aigner, Soroohian, and Kerwin, 1984 ▀ LaFrance and Perron, 1994 ▀ Blaney, Inglis, and Janney, 1994 ▀ Bartels and Fiebig, 2000 ▀ Lins, Silva, and Rosa 2002 ▀ Swan and Ugursal, 2009 ▀ Tiedemann, 2007 ▀ KEMA, 2010 ▀ EIA RECS, 2013


other. This leads to unstable and unreliable parameter estimates for individual variables, which are important for CDA

| brattle.com 7

Key Takeaways from the literature ▀ Constant term: CDA requires the use of a constant term to account for

consumption from appliances which is not specifically parameterized. Without a constant term, other miscellaneous load is falsely distributed among modeled appliances, biasing results.

▀ Aggregate appliances: CDA often has significant collinearity (*) issues. Aggregating appliances into a group (e.g., miscellaneous kitchen) can help alleviate these concerns.

▀ Outliers and inconsistent data: Dropping some outliers and data with extreme inconsistency provides greater accuracy, a common practice in any data analysis

▀ Both art and science: There is no basic specification for a CDA. Each analysis is different due to survey structure and underlying population

(*) Collinearity occurs when the model includes variables that are correlated not just to the dependent variable, but also to each


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Model Changes Our analysis incorporates our key takeaways from the literature review and introduces a new specification for modeling appliance usage ▀ Omit refrigerator due to collinearity with the constant term; separately

back-out our refrigerator AEU from the constant term ▀ Combine electric water heat and electric cooking (all-electric households)

to account for collinearity issues ▀ Combine kitchen appliances (toaster, microwave, freezer) into a single term ▀ More granular approach to accounting for heat pumps in both heating and

cooling parameters ▀ Do not use logarithm of people in household


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Model Considerations Including a constant term is a necessity to conduct an unbiased CDA but does result in collinearity issues. We took a rigorous approach to trying ascertain AEUs for collinear appliances. For example, for estimating refrigerator usage, we considered the following: ▀ Include controls for the age of the fridge ▀ Make different assumptions for the "did not answer” responses ▀ Interact refrigerator with housing time ▀ Interact refrigerator with income ▀ Interact refrigerator with number of people ▀ Interact refrigerator with freezer ▀ Consider refrigerator as a binary instead of a "# of refrigerator" ▀ Many combinations and permutations of above

Regardless of how we have considered refrigerator usage, the implied AEU was negative, indicating bias. Therefore, we omitted refrigerator from the equation and included it as part of the constant term


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Parameter Estimates for CDA AvgHDD_EPrimHeat 0.491*** AvgCDD_sqft_HmInsl_HeatPump 5.94e-05***

(0.00902) (7.60e-06)AvgHDD_sqft_EPrimHeat 0.000410*** Ewtht_plus_cooking_HDD 0.0917***

(2.50e-05) (0.00318)AvgHDD_sqft_NumPeople_EPrimHeat 2.72e-05*** Ewtht_plus_cooking_CDD 0.174***

(2.56e-06) (0.00351)AvgHDD_sqft_Apartment_EPrimHeat -0.000550*** Ewtht_plus_cooking_HmInsl -1.050***

(2.35e-05) (0.0400)AvgHDD_sqft_townhouse_EPrimHeat -0.000484*** Vaccum_sqft 0.000881***

(2.40e-05) (5.45e-05)AvgHDD_sqft_SnglFamily_EPrimHeat -0.000400*** washdry_NumPeople 0.183***

(2.71e-05) (0.0110)AvgHDD_HeatPump 0.0189** TV_NumTV 0.280***

(0.00836) (0.0208)AvgHDD_sqft_HeatPump -2.50e-05*** NumIncandescent_Incandescent 0.0850***

(6.49e-06) (0.00611)AvgHDD_sqft_HmInsl_HeatPump 9.56e-05*** Incan_sqft 0.000714***

(5.45e-06) (5.60e-05)AvgHDD_sqft_ESecHeat 0.000117*** OtherLamps_NumOthrLamps 0.0360***

(3.56e-06) (0.00418)AvgCDD_WindowCentral 0.304*** OtherLamps_sqft -0.000645***

(0.00868) (4.53e-05)AvgCDD_sqft_WindowCentral 1.03e-05 Vaccum_NumPpl -0.242***

(8.04e-06) (0.0276)AvgCDD_sqft_HmIsl_WindowCentral 8.68e-05*** misc_kitchen 0.501***

(6.75e-06) (0.0351)AvgCDD_sqft_TownHouse_WindCent 3.76e-05***

(6.48e-06) Constant 10.71***AvgCDD_sqft_SnglFamily_WindCent 7.14e-05*** (0.0833)

(8.08e-06)AvgCDD_HeatPump 0.263*** Observations 693,806

(0.0102) Adjusted R-squared 0.117AvgCDD_sqft_HeatPump -1.01e-05 Robust standard errors in parentheses

(8.53e-06) *** p<0.01, ** p<0.05, * p<0.1

Note: Including a constant term reduces the R-squared value


| brattle.com 11

AEU Results

Primary heat; 14%

Secondary heat; 5%

Wtr ht/cooking; 10%

AC; 10%

Misc Kitchen; 3%Washer/Dryer; 2%

Vacuum; 2%Television; 2%Lights; 5%

Other; 47%

Brattle Model

Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Annual

Primary heat 283.7 303.7 194.3 55.9 5.6 2.1 0.0 0.0 0.0 64.8 112.8 135.3 1158.2Secondary heat 94.6 101.2 64.8 18.7 1.9 0.7 0.0 0.0 0.0 21.6 37.6 45.1 386.1Water heat/cooking 117.2 127.6 76.3 17.1 51.0 82.1 108.7 91.8 56.5 18.8 40.4 49.4 836.9AC 0.0 0.0 0.0 7.0 109.2 166.7 216.3 186.1 122.5 3.5 2.2 0.4 813.8Misc Kitchen 22.5 20.3 22.4 21.8 22.5 21.7 22.5 22.5 21.8 22.6 21.8 22.5 264.8Washer/Dryer 13.8 12.4 13.7 13.3 13.7 13.3 13.7 13.8 13.3 13.8 13.3 13.7 161.9Vacuum 12.7 11.5 12.7 12.3 12.8 12.3 12.7 12.8 12.3 12.7 12.3 12.7 149.9Television 13.6 12.3 13.5 13.1 13.5 13.0 13.5 13.6 13.1 13.5 13.1 13.5 159.3Lights 31.9 28.8 31.7 30.8 31.9 30.7 31.9 31.9 30.9 31.9 30.8 31.8 375.1Other 330.7 298.7 329.2 319.8 330.0 318.1 329.9 330.9 320.4 331.0 319.2 329.3 3887.1

Monthly total 920.6 916.5 758.6 509.8 592.0 660.8 749.1 703.4 590.9 534.2 603.6 653.7 8193.1

• Brattle model leads to reasonableAEUs for all appliances explicitlycaptured in the model

• It has a large “Other” categorythat includes the collinearappliances (such as refrigerator)

• We back out the refrigerator loadusing engineering data (next slide)


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Identifying Refrigerator Load To separate the refrigerator AEU from the “Other” category, we used estimates provided by EnergyStar ▀ EnergyStar has website that provides

estimates of refrigerator energy consumption based on age and style (we used an average style)

▀ We mapped the EnergyStar age categories to Pepco RASS refrigerator age categories

▀ We assigned the implied weighted average AEU of the refrigerators to households for which no refrigerator age was provided

▀ We gross-up the fridge consumption for multi-fridge households

Pepco RASS Category Percent of Total EnergyStar AEU(%) (kWh)

1 to 5 29.8% 5396 to 10 24.2% 76211 to 20 15.4% 1,11021 + 3.6% 2,070No Age Provided 27.0% 808

Weighted Average 808Multi-Fridge Households 5.80%

Total Fridge AEU 855

Refrigerator AEU Calculation

EnergyStar Source: https://www.energystar.gov/index.cfm?fuseaction=refrig.calculator


https://www.energystar.gov/index.cfm?fuseaction=refrig.calculator



| brattle.com 13

AEU Results—Refrigerator identified

Primary heat; 14%

Secondary heat; 5%

Wtr ht/cooking; 10%

AC; 10%

Misc Kitchen; 3%Washer/Dryer; 2%

Vacuum; 2%Television; 2%Lights; 5%

Other; 37%

Refrigerator; 10%

Brattle Model: Separate Refrigerator

Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec Annual

Primary heat 283.7 303.7 194.3 55.9 5.6 2.1 0.0 0.0 0.0 64.8 112.8 135.3 1158.2Secondary heat 94.6 101.2 64.8 18.7 1.9 0.7 0.0 0.0 0.0 21.6 37.6 45.1 386.1Water heat/cooking 117.2 127.6 76.3 17.1 51.0 82.1 108.7 91.8 56.5 18.8 40.4 49.4 836.9AC 0.0 0.0 0.0 7.0 109.2 166.7 216.3 186.1 122.5 3.5 2.2 0.4 813.8Misc Kitchen 22.5 20.3 22.4 21.8 22.5 21.7 22.5 22.5 21.8 22.6 21.8 22.5 264.8Washer/Dryer 13.8 12.4 13.7 13.3 13.7 13.3 13.7 13.8 13.3 13.8 13.3 13.7 161.9Vacuum 12.7 11.5 12.7 12.3 12.8 12.3 12.7 12.8 12.3 12.7 12.3 12.7 149.9Television 13.6 12.3 13.5 13.1 13.5 13.0 13.5 13.6 13.1 13.5 13.1 13.5 159.3Lights 31.9 28.8 31.7 30.8 31.9 30.7 31.9 31.9 30.9 31.9 30.8 31.8 375.1Other 258.0 233.1 256.5 249.5 257.4 247.8 257.3 258.3 250.1 258.3 248.9 256.7 3031.9Refrigerator 72.6 65.6 72.6 70.3 72.6 70.3 72.6 72.6 70.3 72.6 70.3 72.6 855.2

Monthly total 920.6 916.5 758.6 509.8 592.0 660.8 749.1 703.4 590.9 534.2 603.6 653.7 8193.1

• After identifying the refrigeratorload, the “Other” categoryrepresents 37% of the overallannual energy use


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“Other” Category The components in the “Other” group were not able to be modeled independently for this analysis, due to sample size, variation, data availability, or collinearity

The “Other” category inherently includes end-uses such as the following, many of which were not included in Pepco’s original analysis.

▀ Dishwasher ▀ Computer ▀ Smart tech ▀ Toaster oven ▀ Electric tea kettle ▀ Ceiling fan

▀ Box fan ▀ Dehumidifier ▀ Air purifier ▀ Exercise machines ▀ Home audio system ▀ Home security system


| brattle.com 15

Comparison of AEUs: Pepco vs. Brattle Models Saturation Pepco Brattle Pepco Brattle

Rate Base Base Base Base(kWh) (kWh) (% Share) (% Share)

Heat 92% 2,299 1,544 30% 19%

AC 95% 1,708 814 22% 10%

Water Heat 83% 853 na 11% naOven/Stove 70% 45 na 1% naWater Heat & Oven/Stove 90% na 837 na 10%

Incandescant 89% 512 na 7% naOther Light 63% 48 na 1% naLights 98% na 375 na 5%

Freezer 17% 130 na 2% naToaster 41% 464 na 6% naMicrowave 90% 45 na 1% naMisc Kitchen 94% na 265 na 3%

Vacuum 78% 424 150 5% 2%

Washer/Dryer 61% 258 162 3% 2%

TV 85% 298 159 4% 2%

Refrigerator 97% 650 855 8% 10%Other* 63% na 3,032 na 37%


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Using AEU Estimates to Inform “Baseline” Consumption

AEU estimates can inform what level of consumption constitutes “baseline usage”

For example, baseline usage is approximately 337 kWh/month if it includes the following parameters: ▀ Primary heat ▀ AC ▀ Electric water heating and cooking ▀ Refrigerator ▀ Lighting

Month Baseline(kWh)

January 505February 526March 375April 181May 270June 352July 429August 382September 280October 192November 257December 289

Average 337

Baseline Consumption


| brattle.com 17

Conclusions ▀ Several appliance AEUs from Pepco’s initial CDA were likely biased due to

the omission of a constant term

▀ Inclusion of a constant term results in the omission of some appliances from the model, but it leads to unbiased results for appliance parameters included in the model (for instance, the AEU for vacuum cleaners is much lower in the base Brattle specification)

▀ We implemented several other changes to the model that yielded more reliable AEUs (i.e., lower miscellaneous kitchen equipment load, lower heating and cooling load, lower TV load, a sizable other load category that captures various end uses)

− Because refrigerators generally run 24/7 with a low variability due to behavioral factors, we have not been able to separate the refrigerator AEU from the “other” category, but backed it out using Energy Star data


| brattle.com 18

Works Consulted Aigner, Dennis J., Cyrus Sorooshian, and Pamela Kerwin, 1984. Demand Analysis for Estimating Residential End-Use Load Profiles. The Energy Journal 5(3): 81-97. Bartels, Robert and Denzil G. Fiebig, 2000. Residential End-Use Electricity Demand: Results from a Designed Experiment. The Energy Journal 21(2): 51-81. Blaney, John C., Mark R. Inglis, and Asa M. Janney III, 1994. Hourly Conditional Demand Analysis of Residential Electricity Use. KEMA, Inc., 2010. 2009 California Residential Appliance Saturation Study. Prepared for the California Energy Commission. Lafrance F, and D. Perron, 1994. Evolution of Residential Electricity Demand by End-Use in Quebec 1979-1989: A Conditional Demand Analysis. Energy Studies Review 6(2): 164-173. Lins, Marcos Pereira Estellita, Angela Cristina Moreira Da Silva, and Luiz Pinguelli Rosa, 2002. Regional Variations in Energy Consumption of Appliances: Conditional Demand Analysis Applied to Brazilian Households. Annals of Operations Research 117: 235-246. Parti M., and C. Parti, 1980. The Total and Appliance-Specific Conditional Demand for Electricity in the Household Sector. Bell Journal of Economics 11: 81-97. Swan, Lukas G. and V. Ismet Ugursal, 2009. Modeling of End-Use Energy Consumption in the Residential Sector: A Review of Modeling Techniques. Renewable and Sustainable Energy Reviews 13: 1819-1835. Tiedemann, K.H., 2007. Using Conditional Demand Analysis to Estimate Residential Energy Use and Energy Savings. U.S. Energy Information Administration, 2013. Residential Energy Consumption Survey (RECS) End-Use Models FAQs.


1

POTOMAC ELECTRIC POWER COMPANY DISTRICT OF COLUMBIA

MARGINAL DISTRIBUTION COST STUDY

Introduction

The Potomac Electric Power Company (Pepco or the Company) performed a

distribution marginal cost study as part of its preparation for the Company’s distribution rate

case filing. Marginal distribution costs are defined as the additional costs associated with a

one unit increase in electricity demand or additional customers. Through this study, Pepco

developed new primary and secondary marginal capacity costs and new customer related

marginal costs. The marginal cost study was designed to reflect the restructured electric

utility market in the District of Columbia. Specifically, generation related marginal costs

were not calculated as part of this study because Pepco no longer owns and operates

generating facilities and prices for electric energy are determined by the competitive

wholesale market. Transmission related marginal costs were not calculated because these

activities are not a component of this rate case filing. Pepco conducted the marginal cost

study based upon previously established District of Columbia Public Service Commission

(Commission) guidelines for performing these studies and the Company’s most recent

method of developing distribution marginal costs.

Description of Marginal Cost Study

Marginal distribution costs were calculated using the planned investment approach,

which is similar to the method used by Pepco to develop previous distribution marginal costs.

The planned investment approach is forward looking and relies upon the Company’s most

recent five-year forecast of distribution plant expenditures, excluding contributions in aid of

PEPCO (E) - 9 Page 1 of 9

2

construction (CIAC). The study period for these expenditures is 2015 through 2019 and all

expenditures are expressed in year 2014 dollars. Pepco relied upon the planned investment

approach for three reasons: 1) the Commission has found the planned investment approach to

be reasonable for calculating marginal costs, 2) accurate marginal costs can be calculated in

this manner, and 3) this approach is one of the most frequently used methods to calculate

electric distribution marginal costs.

An overall cost of capital of 7.65 percent was used to calculate the carrying charge

rate for the marginal cost study. This is based upon the capital structure and the cost of

preferred stock, common stock, and debt authorized by the Commission in Order No. 17424,

Formal Case No. 1103. The overall carrying charge rate was determined to be 9.87 percent.

The forecast distribution plant additions were classified by the Company’s

distribution system planners as “distribution,” “services” or “miscellaneous.” The

distribution plant items are for facilities designed to serve a distribution function, including

distribution substations and overhead and underground circuits. Services items are the result

of customer service orders. The miscellaneous distribution items are for various projects

which result in improvements to the distribution systems and relocation/replacement of plant

due to street and highway construction or Metro transit construction activities. Pepco

distribution system planners assigned the projects to functional categories. The planners

identified specific projects attributable to the growth in electricity demand according to the

criteria established by the District of Columbia Public Service Commission in 1991 in Order

No. 9868, Formal Case No. 905. Expenditures are considered demand related if they are one

or more of the following:

1. Required to correct thermal overloads.


3

2. Required to correct voltage deficiencies – either high voltage or low voltage.

3. Required to maintain system reliability.

4. Required to improve system reliability.

5. Required to meet new safety requirements.

6. Upgrades to older equipment necessary to meet new environmental laws.

Projects were classified as not attributable to growth in demand if they are planned

repairs to old facilities, replacement of old facilities for reasons other than those items

identified above, or if they are required due to planned relocation of Pepco distribution

equipment.

Any project expenditures determined to be “inframarginal” were excluded according

to the treatment of these expenditures recommended in the Commission’s discussion of this

issue in Order No. 9868, Formal Case No. 905. Expenditures were identified as

“inframarginal” on the basis of Pepco studies that identified the proportions of planned

expenditures associated with the substation building itself, landscaping for the building,

paving, fencing, and sidewalks.

The forecast expenditures for the distribution projects classified as “distribution” or

“miscellaneous” which are partially attributable to growth in demand were divided into their

respective demand and non-demand portions. The allocation of demand versus non-demand

portions of expenditures for projects with both components was based upon recent studies

conducted by Pepco’s distribution system planners. Project expenditures identified under the

“services” classification were divided into demand and customer portions based upon the

most recent Company study of these components.


4

Total forecast expenditures attributable to growth in demand for primary distribution

projects were then developed by summing the demand portions of forecast expenditures for

projects classified as distribution, miscellaneous, and the primary demand portion of services.

This total was divided by total growth in Pepco forecast non-coincident area peak demand

(NCAP) over the planning period to obtain the primary distribution marginal capacity cost

per kW, as shown in Table 1. Also included in Table 1 is the distribution operations and

maintenance (O&M) cost associated with forecast expenditures for demand-related primary

distribution projects. The primary distribution O&M expense per kW of NCAP was derived

based on a study of primary and secondary O&M expenses for calendar 2009.

In a similar fashion, the demand portion of secondary services forecast project

expenditures was divided by the growth in NCAP at secondary to determine the secondary

distribution capacity marginal cost, as shown in Table 2. Also shown in Table 2 is the

secondary distribution O&M cost associated with forecast expenditures for demand-related

secondary distribution projects.

Table 3 contains the secondary distribution marginal customer cost. This was

calculated by dividing the customer portion of the forecast services expenditures by the

growth in customers (excluding those served at high voltage) over the five-year period. Also

shown in Table 3 is the secondary distribution O&M cost associated with forecast

expenditures for customer-related secondary distribution projects. The respective meter costs

associated with adding a customer for each of the major rate schedules are displayed on the

lower section of Table 3.

Total annual customer-related costs, including customer accounts expense, are

summarized in Table 4. Customer accounts expense was estimated based on a study of


5

customer accounts expense, customer service and information expense, and customer sales

expense over a five-year period.

In summary, Pepco’s primary distribution annual marginal cost per each kW of

NCAP demand growth is $352.57. Pepco’s secondary distribution annual marginal cost per

each kW of NCAP demand growth is $209.39. Pepco’s secondary distribution annual

marginal customer cost is $200.98, excluding metering costs. Total annual customer related

distribution costs vary by rate schedule and are displayed in Table 4.


POTOMAC ELECTRIC POWER COMPANYDISTRICT OF COLUMBIAPRIMARY DISTRIBUTION MARGINAL CAPACITY COST(2014 Dollars)

Total demand-caused primary distribution expenditures ($000; 2015-2019) $664,011

Contributions in Aid of Construction $0

Net demand-caused primary distribution expenditures ($000; 2015-2019) $664,011

Five-year growth in primary NCAP MW 224

Incremental cost ($/NCAP KW) $2,964.34

Real carrying charge rate 9.87%

Annualized cost ($/NCAP KW) $292.58

Distribution O&M ($/NCAP KW) 59.99$

Total annual cost ($/NCAP KW) $352.57


POTOMAC ELECTRIC POWER COMPANYDISTRICT OF COLUMBIASECONDARY DISTRIBUTION MARGINAL CAPACITY COST(2014 Dollars)

Total demand-caused secondary distribution expenditures ($000; 2015-2019) $189,473


Net demand-caused secondary distribution expenditures ($000; 2015-2019) $189,473

Five-year growth in secondary NCAP MW 177

Incremental cost ($/NCAP KW) $1,070.02


Annualized cost ($/NCAP KW) $105.61

Distribution O&M ($/NCAP KW) 103.78$

Total annual cost ($/NCAP KW) $209.39


POTOMAC ELECTRIC POWER COMPANYDISTRICT OF COLUMBIASECONDARY DISTRIBUTION MARGINAL CUSTOMER COST(2014 Dollars)

Total demand-caused secondary distribution expenditures ($000; 2015-2019) $44,444


Net demand-caused secondary distribution expenditures ($000; 2015-2019) $44,444

Five-year growth in customer excluding 31,112high voltage

Installed cost per customer $1,428.51


Annualized cost per customer $140.99

O&M expense per customer 59.99$

Annual customer cost $200.98

Meter Costs:Residential $202.78Residential-Time-Metered $232.63Master Metered Apartments $666.69GS-Non-demand $666.69GS-Low voltage $412.98GS-High voltage $4,757.80GT-Low voltage $412.98GT-High voltage $4,757.80Metro-RT $23,789.00

Annualized meter costs:Residential $20.01Residential-Time-Metered $22.96Master Metered Apartments $65.80GS-Non-demand $65.80GS-Low voltage $40.76GS-High voltage $469.59GT-Low voltage $40.76GT-High voltage $469.59Metro-RT $2,347.97


AnnualizedCustomer & Customer CustomerMeter Cost Accounts Total

Residential $221.00 $91.61 $312.61

Residential-TM $223.94 $98.95 $322.89

MMA $266.78 $127.04 $393.82

GS-Non-demand $266.78 $136.53 $403.31

GS-Low voltage $241.74 $136.53 $378.27

GS-High voltage $670.58 $319.58 $990.16

GT-Low voltage $241.74 $160.02 $401.76

GT-High voltage $670.58 $244.90 $915.48

Metro-RT $2,548.96 $4,145.75 $6,694.70

POTOMAC ELECTRIC POWER COMPANYDISTRICT OF COLUMBIA

TOTAL ANNUAL CUSTOMER COSTS(2014 Dollars)


1150 Pepco District of Columbia Application for Rate … P.S.C - - December, 2017 Introduced as:...

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