TITLE 20. PUBLIC UTILITIES AND TELECOMMUNICATIONS

STATE CORPORATION COMMISSION

Proposed Regulation

Title of Regulation: 20VAC5-204. Rules Governing Utility Rate Applications and Annual Informational Filings of Investor-Owned Electric Utilities (amending 20VAC5-204-10, 20VAC5-204-50, 20VAC5-204-90).

Statutory Authority: § 12.1-13 of the Code of Virginia.

Public Hearing Information: An opportunity to request a public hearing will not be offered.

Public Comment Deadline: July 30, 2025.

Agency Contact: Brian Pratt, Deputy Director, Public Utility Regulation, State Corporation Commission, P.O. Box 1197, Richmond, VA 23218, telephone (804) 371-9449, or email brian.pratt@scc.virginia.gov.

Summary:

Pursuant to Chapters 749, 757, 775, and 776 of the 2023 Acts of Assembly, the proposed amendments increase or decrease certain electric utilities' combined rate of return for generation and distribution services by up to 50 basis points, including potential increases or decreases in rates of return based on factors that include generating plant performance, customer service, and operating efficiency of a utility.

AT RICHMOND, MAY 30, 2025

COMMONWEALTH OF VIRGINIA, ex rel.

STATE CORPORATION COMMISSION

CASE NO. PUR-2023-00210

Ex Parte: In the matter concerning

implementing performance-based

adjustments to combined rates of return

under §§ 56-585.1 A 2 c and 56-585.8 E of the Code of Virginia

ORDER ESTABLISHING RULEMAKING

Chapters 749, 757, 775, and 776 of the 2023 Virginia Acts of Assembly (collectively "Enactment Clauses"), inter alia, amended § 56-585.1 A 2 c of the Code of Virginia ("Code"), which establishes a performance measure for investor-owned incumbent electric utilities, allowing the State Corporation Commission ("Commission") to increase or decrease a utility's authorized return on equity as follows:

The Commission may increase or decrease the utility's combined rate of return for generation and distribution services by up to 50 basis points based on factors that may include reliability, generating plant performance, customer service, and operating efficiency of a utility. Any such adjustment to the combined rate of return for generation and distribution services shall include consideration of nationally recognized standards determined by the Commission to be appropriate for such purposes.

Additionally, each Chapter includes an enactment clause that directs the Commission to initiate a proceeding by December 31, 2023, to review and determine the appropriate protocols and standards applicable to implementing performance-based adjustments to the respective utility's combined rate of return. These enactment clauses further direct that the protocols and standards established as a result of such a proceeding shall apply to biennial review filings occurring on or after January 1, 2025 for a Phase II Utility¹ and January 1, 2026 for a Phase I Utility,² unless the Commission determines that the public interest would be better served by implementing such protocols and standards for biennial review filings occurring on or after January 1, 2027. Finally, the enactment clauses establish that, beginning January 1, 2024, and until such standards and protocols are applicable, the Commission shall have and retain its authority, consistent with its precedent for incumbent electric utilities prior to the enactment of Chapters 888 and 933 of the 2007 Acts of Assembly, to increase or decrease the utility's combined rate of return based on the Commission's consideration of the utility's performance.

On December 12, 2023, the Commission issued an Order Establishing Proceeding that, among other things, docketed the matter; initiated a stakeholder process ("Stakeholder Process") to gather proposed standards and protocols; directed the Commission's Staff ("Staff") to conduct the Stakeholder Process; provided an opportunity for interested persons to submit standards and protocols for the Commission's consideration and to participate in a stakeholder meeting; and directed Staff to file a Staff Report ("Report") presenting, for the Commission's consideration, proposed standards and protocols to comply with the Enactment Clauses.

Proposed standards and protocols were submitted by numerous parties through comments filed by stakeholders and by the public, and through a virtual stakeholder meeting held on May 23, 2024, and attended by over 45 stakeholders.³ Staff filed its Report on August 1, 2024, including a summary of the proposed inputs received through the Stakeholder Process, as well as Staff's proposed recommendations and implementation process.⁴

On October 21, 2024, the Commission entered an Order ("Order") which found that further proceedings were needed to implement the to-be-developed protocols and standards for utility biennial reviews filed on or after January 1, 2027.⁵ Attached to the order were two appendices ("Appendices") containing performance metrics proposed by Staff. The Order provided an opportunity for any interested person or entity to submit comments on the Appendices and issues raised in the Report, and directed Staff to file proposed draft regulations utilizing input from the comments received.⁶

Pursuant to the Commission's Order, Staff reviewed the comments filed in this proceeding and filed proposed draft regulations on March 7, 2025 ("Draft Regulations").

NOW THE COMMISSION, upon consideration of this matter, is of the opinion and finds that the Draft Regulations, as appended hereto, should be considered for adoption. The Commission further finds that a copy of the Draft Regulations should be sent to the Office of the Registrar for publication in the Virginia Register of Regulations.

To promote administrative efficiency and timely service of filings upon participants, the Commission will, among other things, direct the electronic filing of comments unless they contain confidential information, and require electronic service on participants in this proceeding.

Accordingly, IT IS ORDERED THAT:

(1) All comments or other documents and pleadings filed in this matter shall be submitted electronically to the extent authorized by Rule 5VAC5-20-150, Copies and format, of the Commission's Rules of Practice and Procedure.⁷ Confidential and Extraordinarily Sensitive Information shall not be submitted electronically and shall comply with Rule 5VAC5-20-170, Confidential information, of the Rules of Practice. Any person seeking to hand deliver and physically file or submit any pleading or other document shall contact the Clerk's Office Document Control Center at (804) 371-9838 to arrange the delivery.

(2) Pursuant to 5VAC5-20-140, Filing and service, of the Rules of Practice, the Commission directs that service on participants and Staff in this matter shall be accomplished by electronic means. Concerning Confidential or Extraordinarily Sensitive Information, participants and Staff are instructed to work together to agree upon the manner in which documents containing such information shall be served upon one another, to the extent practicable, in an electronically protected manner, even if such information is unable to be filed in the Office of the Clerk, so that no participant or Staff is impeded from participating in this matter.

(3) On or before July 30, 2025, any interested person may file comments on the Draft Regulations by following the instructions found on the Commission's website: scc.virginia.gov/case-information/submit-public-comments. Those unable, as a practical manner, to file comments electronically may file such comments by U.S. mail to the Clerk of the State Corporation Commission, c/o Document Control Center, P.O. Box 2118, Richmond, Virginia 23218-2118. All comments shall refer to Case No. PUR-2023-00210. Individuals should be specific in their comments on the Draft Regulations and should address only those issues pertaining to the Enactment Clauses addressed herein. Issues outside the scope of these Enactment Clauses will not be open for consideration.

(4) An electronic copy of the Draft Regulations may be obtained by submitting a request to Brian Pratt, Deputy Director in the Commission's Division of Public Utility Regulation at the following email address: brian.pratt@scc.virginia.gov. An electronic copy of the Draft Regulations can also be found at the Division of Public Utility Regulation's website: scc.virginia.gov/regulated-industries/utility-regulation/pur-responsibilities/rulemaking. Interested persons may also download unofficial copies of the Order Establishing Rulemaking and the Draft Regulations from the Commission's website: scc.virginia.gov/case-information.

(5) Within 10 business days hereof, Staff shall provide copies of this Order Establishing Rulemaking by electronic transmission, or when electronic transmission is not possible, by mail, to individuals, organizations, and companies who have been identified by Staff as potentially being interested in this proceeding and the Draft Regulations, including all participants in the Stakeholder Process.

(6) The Commission's Office of General Counsel shall forward a copy of this Order Establishing Rulemaking and the Draft Regulations to the Registrar of Regulations for publication in the Virginia Register of Regulations.

(7) The Commission's Division of Public Utility Regulation shall promptly post a copy of this Order Establishing Rulemaking on the Commission's website.

(8) Any documents filed in paper form with the Office of the Clerk of the Commission in this docket may use both sides of the paper. In all other respects, except as modified herein, all filings shall comply fully with the requirements of 5VAC5-20-150, Copies and format, of the Commission's Rules of Practice.

(9) On or before October 1, 2025, the Staff may file with the Clerk of the Commission a report on or a response to any comments, or proposals, submitted to the Commission on the Draft Regulations.

(10) This matter is continued.

A COPY hereof shall be sent electronically by the Clerk of the Commission to all persons on the official Service List in this matter. The Service List is available from the Clerk of the Commission.

20VAC5-204-10. General filing instructions.

A. An applicant shall provide a notice of intent to file an application pursuant to 20VAC5-204-20, 20VAC5-204-40, and 20VAC5-204-60 to the commission 60 days prior to the application filing date. A notice of intent to file an application shall be provided for each 20VAC5-204-40 and 20VAC5-204-60 application, and such notice shall identify the specific section and subsection of the Code of Virginia pursuant to which the application will be filed. An applicant may include more than one application in a notice of intent to the extent the applicant intends to file multiple applications pursuant to 20VAC5-204-40 and 20VAC5-204-60 within the same timeframe but must list each intended application separately within the notice of intent. If the filing is for the continuation of a previously-approved rate adjustment clause, the notice shall identify the specific rate adjustment clause. If the application is for approval of a new rate adjustment clause or for a prudency determination, the notice shall include a narrative description of the associated project or program.

B. Applications pursuant to 20VAC5-204-20 through 20VAC5-204-80 shall include:

1. The name and post office address of the applicant and the name and post office address of the applicant's counsel.

2. A full clear statement of the facts that the applicant is prepared to prove by competent evidence.

3. A statement of details of the objectives sought and the legal basis therefore.

4. All direct testimony by which the applicant expects to support the objectives sought. Each testimony shall include a summary not to exceed one page for applications pursuant to 20VAC5-204-30, 20VAC5-204-40, or 20VAC5-204-60 through 20VAC5-204-80 and not to exceed two pages for applications pursuant to 20VAC5-204-20 or 20VAC5-204-50.

5. Information or documentation conforming to the following general instructions:

a. Attach a table of contents of the company's application, including exhibits.

b. Each exhibit shall be labeled with the name of the applicant and the initials of the sponsoring witness in the upper right-hand corner as follows:

Exhibit No. (Leave Blank)

Witness: (Initials)

Statement or

Schedule Number

c. The first page of all exhibits shall contain a caption that describes the subject matter of the exhibit.

d. If the accounting and statistical data submitted differ from the books of the applicant, then the applicant shall include in its filing a reconciliation schedule for each account or subaccount that differs, together with an explanation describing the nature of the difference.

e. The required accounting and statistical data shall include all work papers and other information necessary to ensure that the items, statements, and schedules are not misleading.

C. This chapter does not limit the commission staff or parties from raising issues for commission consideration that have not been addressed in the applicant's filing before the commission. Except for good cause shown, issues specifically decided by commission order entered in the applicant's most recent rate case may not be raised by staff or interested parties in earnings tests made pursuant to 20VAC5-204-20, 20VAC5-204-30, or 20VAC5-204-50.

D. An application filed pursuant to 20VAC5-204-20, 20VAC5-204-30, 20VAC5-204-40, 20VAC5-204-50, 20VAC5-204-60, 20VAC5-204-70, or 20VAC5-204-80 shall not be deemed filed pursuant to Chapter 10 (§ 56-232 et seq.) or Chapter 23 (§ 56-576 et seq.) of Title 56 of the Code of Virginia unless it is in full compliance with this chapter.

E. The commission may waive any part or all of this chapter for good cause shown.

F. Where a filing contains information that the applicant claims to be confidential, the filing may be made under seal provided it is simultaneously accompanied by both a motion for protective order or other confidential treatment and an original and one copy of a redacted version of the filing to be available for public disclosure. Unredacted filings containing the confidential information shall, however, be immediately available to the commission staff for internal use at the commission.

G. Filings containing confidential (or redacted) information shall so state on the cover of the filing, and the precise portions of the filing containing such confidential (or redacted) information, including supporting material, shall be clearly marked within the filing.

H. Applicants shall provide a searchable PDF version of the application and direct testimony electronically to the Divisions of Utility Accounting and Finance and Public Utility Regulation on the application filing date. Applicants must also provide a searchable PDF of the public version of the application and direct testimony electronically to the Division of Consumer Counsel of the Office of the Attorney General of Virginia on the application filing date.

Additionally, all schedules containing calculations derived from formulas shall be provided electronically to the Divisions of Utility Accounting and Finance and Public Utility Regulation in an electronic spreadsheet including all underlying formulas and assumptions on the application filing date. Such electronic spreadsheet shall be commercially available and have common use in the utility industry.

All schedules that do not contain calculations derived from formulas shall be provided electronically to the Divisions of Utility Accounting and Finance and Public Utility Regulation in a searchable PDF version within five business days of the application filing date. Additional versions of such schedules shall be made available to parties upon request.

I. All applications, including direct testimony and Schedules 1 through 28, 30 through 39, and 41 through 49 50, as applicable, shall be filed in an original and 12 copies with the Clerk of the Commission, c/o Document Control Center, P.O. Box 2118, Richmond, Virginia 23218. One copy of Schedules 29 and 40 shall be filed with the Clerk of the Commission. Applicants may omit filing Schedule 29 with the Clerk of the Commission in Annual Informational Filings. Additional copies of such schedules shall be made available to parties upon request.

One copy of Schedules 29 and 40 shall be submitted to the Division of Utility Accounting and Finance. Four copies of Schedule 40 shall be submitted to the Division of Public Utility Regulation.

J. 1. For any application made pursuant to 20VAC5-204-20, 20VAC5-204-40, or 20VAC5-204-60, the applicant shall serve a copy of the information required in subsection A of this section at the same time that it is filed with the commission upon: (i) the chairman of the board of supervisors of each county (or equivalent officials in the counties having alternate forms of government) in this Commonwealth affected by the proposed increase or, in the case of applications made pursuant to 20VAC5-204-40, the proposed project; (ii) the mayor or manager of every city and town (or equivalent officials in towns and cities having alternate forms of government) in this Commonwealth affected by the proposed increase or, in the case of applications made pursuant to 20VAC5-204-40, the proposed project; and (iii) the Division of Consumer Counsel of the Office of the Attorney General of Virginia. Such service shall be made electronically to the extent the applicant has official email addresses for such officials. If not, such service shall be made either by (i) personal delivery or (ii) first class mail to the customary place of business or to the residence of the person served.

2. For applications pursuant to 20VAC5-204-20 and 20VAC5-204-40 through 20VAC5-204-80, the applicant shall also serve each official listed in subdivision J 1 of this section with the following within five business days of the issuance of the commission's procedural order regarding the application: (i) the information required in subdivisions B 1, B 2, and B 3 of this section; (ii) a statement that a copy of the complete public version of the application may be obtained at no cost by making a request therefor in writing to a specified company official; and (iii) the commission's procedural order regarding the application. Such service shall be made electronically to the extent the applicant has official email addresses for such officials. If not, such service shall be made either by (i) personal delivery or (ii) first class mail to the customary place of business or to the residence of the person served.

3. In addition, the applicant shall serve a copy of the complete public version of its application upon the Division of Consumer Counsel of the Office of the Attorney General of Virginia at the same time it is filed with the commission. Such service shall be made either by personal delivery or first class mail to the customary place of business.

K. Nothing in this chapter shall be interpreted to apply to applications for temporary reductions of rates pursuant to § 56-242 of the Code of Virginia.

20VAC5-204-50. Base rate review applications pursuant to § 56-585.1 or 56-585.8 of the Code of Virginia.

A. A base rate review application filed pursuant to § 56-585.1 or 56-585.8 of the Code of Virginia shall include the following:

1. Exhibits consisting of Schedules 3; 6; 7; 9 through 18; 29 a, b, c, and f; 30, 31, 32, 34, 35, 36, 40a, 44, and 48 as identified in 20VAC5-204-90 shall be submitted with the utility's direct testimony for each of the successive 12-month test periods. Schedule 35 for the final 12-month test period shall be filed no later than April 30 of the application filing year.

2. Exhibits consisting of Schedules 1, 2, 4, 5, 8, 19 through 28, 29 d, 29 e, 33, 37, 38, 39, 40b, 40c, 41, 42, 43, 45, and 47 as identified in 20VAC5-204-90 shall be submitted with the utility's direct testimony for the final 12-month test period. An exhibit consisting of Schedule 49 as identified and described in 20VAC5-204-90 shall be submitted with the utility's direct testimony for the final 12-month test period.

3. An exhibit consisting of additional schedules may be submitted with the utility's direct testimony. Such exhibit shall be identified as Schedule 49 50 (this exhibit may include subschedules as needed labeled 49A 50A et seq.).

4. A reconciliation of the total company amounts in Schedules 19 and 22 to the statement of income and comparative balance sheet contained in Federal Energy Regulatory Commission Form No. 1 shall be filed with the commission no later than April 30 of the application filing year.

B. The assumed rate year for purposes of determining ratemaking adjustments in Schedules 21 and 24, as identified in 20VAC5-204-90, shall begin on January 1 following the application filing date.

20VAC5-204-90. Instructions for Schedules and exhibits for this chapter.

The following instructions for schedules and exhibits are to be used in conjunction with this chapter:

Schedule 49 - Data Pertaining to Nationally Recognized Standards for Reliability, Generating Plant Performance, Customer Service, and Operating Efficiency

Instructions: Provide the metrics identified in paragraphs (a) and (b) of the Schedule 49 filing requirements, if applicable, using the Schedule 49 definitions provided. Should the commission issue orders requiring metrics in addition to those identified in the Schedule 49 filing requirements and definitions, provide the metrics identified in paragraphs (a) and (b) in a manner that is in accordance with the Schedule 49 filing requirements and definitions and in compliance with any applicable commission order. Unless specified otherwise, metric data shall be provided by calendar year for each year of the biennial review period as well as the historical benchmark period that is specified for the particular performance metric.

Schedule 49 definitions:

When used in this schedule, the following terms shall have the following meanings, unless context clearly indicates otherwise:

"Advanced Metering Infrastructure" or "AMI" means a networked system of smart meters, communication technologies, and data management systems designed to enable automated, real-time, and two-way communication between utilities and customers.

"Average speed of answer" or "ASA" means the average time in seconds that callers experience in a queue to reach an agent or to initiate a transaction through an interactive voice response system.

"Btu" means British thermal unit.

"Capacity factor (renewables)" means the ratio of the actual energy produced by a renewable energy system (such as a wind or solar farm) to the maximum possible energy that could be generated if it operated at full capacity all the time.

"CH₄" means methane.

"CO" means carbon monoxide.

"CO₂" means carbon dioxide.

"CO₂e" means carbon dioxide equivalent, and is a standard unit used to measure and compare the emissions of different greenhouse gases based on their global warming potential.

"CO₂ intensity" means the amount of carbon dioxide (CO₂) emitted per unit of energy generated or consumed.

"Criteria Pollutants" means the set of air pollutants that are regulated by the U.S. Environmental Protection Agency, and includes PM2.5, PM10, O₃, CO, NO₂, SO₂, and Pb.

"Demand-side management" or "DSM" means the programs filed by the applicant before the commission, designed to control and reduce electricity consumption on the consumer side of the grid.

"Distributed Energy Resource" or "DER" means small-scale, decentralized energy systems that generate, store, or manage electricity close to where the electricity is used. DERs can be renewable (e.g., solar or wind), nonrenewable (e.g., natural gas microgrids), or include energy storage systems and demand-side management technologies.

"Distributed Energy Resource Management System" or "DERMS" means a system designed to manage and optimize distributed energy resources (DERs), such as solar panels, batteries, electric vehicles (EVs), and demand-side resources (e.g., smart appliances) that are connected to the grid.

"Equivalent forced outage rate on demand" or "EFORd" means a measure of the probability that a generating unit will not be available due to forced outages or forced deratings when there is demand on the unit to generate. When used as a measure of historical performance, EFORd is calculated as the percentage of total demand time that a unit was unavailable due to forced outages or deratings.

"EIA" means the U.S. Energy Information Administration.

"Equivalent availability factor" or "EAF" means the fraction of a given operating period in which a generating unit is available without any outages and equipment deratings or seasonal deratings.

"EV" means electric vehicle.

"EVSE" means electric vehicle supply equipment.

"FERC" means Federal Energy Regulatory Commission or its successor agency.

"Heat rate" or "HR" means how efficiently a generator converts heat energy from fuel into electrical energy. Heat rate is calculated by dividing the thermal energy consumption by the electric energy generated (Btu/kWh).

"kW" means kilowatt.

"kWh" means kilowatt-hour.

"Mt CO₂e" means metric tons of carbon dioxide equivalent.

"MW" means megawatt.

"MWh" means megawatt-hour.

"Net capacity factor (nuclear)" means the actual amount of electricity a nuclear plant generates over a period of time, compared to the maximum possible output it could produce if it were operating at full capacity for 24 hours per day, seven days a week, accounting for factors like planned maintenance, outages, and other operational considerations.

"Net Energy Metering" or "NEM" means the billing mechanism that allows customers with solar panels (or other distributed energy resources) to offset their own demand and receive credit for excess electricity generated and fed back into the grid.

"N₂O" means nitrous oxide.

"NO₂" means nitrogen dioxide.

"NO_x" means nitrogen oxides.

"O₃" means ground-level ozone.

"O&M" means operations and maintenance.

"Off-peak charging" means charging an EV or EVSE during periods of lower electricity demand, typically when the grid is under less strain.

"Pb" means lead.

"Plant production cost" means the total production expense per MWh of net output.

"PM" means the mixture of tiny particles and liquid droplets that are suspended in the air, and includes two main types, PM 2.5 and PM 10.

"PM 2.5" means particles with a diameter of 2.5 micrometers or smaller.

"PM 10" means particles with a diameter of 10 micrometers or smaller.

"PPA" means power purchase agreement.

"PTO" means permission to operate.

"PWR" means pressurized water reactor.

"Resource economic efficiency" means the annual net operating profits for each owned generating unit and purchased power resource, expressed in dollars per year and dollars per MWh produced by the electric generating unit or purchased power agreement. In terms of dollars per year, it is calculated by subtracting total annual operating costs, including incremental capital additions, non-fuel O&M, and fuel costs, from total annual capacity, energy, and ancillary service revenues produced by the electric generating unit or from a purchased power agreement.

"RTO" means the regional transmission organization in which the applicant is a member.

"System average service reliability" or "SASR" means the measure of the reliability of the applicant's service; specifically, the average number of service interruptions experienced by customers within a year.

"SEC" means the U.S. Securities and Exchange Commission.

"SLR Program" means subsequent license renewal program.

"SO₂" means sulfur dioxide.

"System Average Interruption Duration Index" or "SAIDI," excluding or including major events, means the total duration of interruption for the average customer on an annual basis. SAIDI equals the sum of all customer interruption durations divided by the total number of customers served.

"System Average Interruption Frequency Index" or "SAIFI," excluding or including major events, means the average number of interruptions that a customer would experience on an annual basis, expressed as a number. SAIFI equals the sum of all customer interruptions divided by the total number of customers served.

"XEFORd" means a measure of the probability that a generating until will not be available due to forced outages or forced deratings when there is demand on the unit to generate. It is similar to EFORd but excludes events that are designated as outside management's control.

Schedule 49 filing requirements:

(a) Provide the metric data listed for the applicant and any specified industry benchmark for the biennial review period and, separately, for each specified historical benchmark period. The historical benchmark period for the SAIDI and SAIFI metrics is the 10-year period immediately preceding the biennial review period. The historical benchmark period for all other metrics listed, if applicable, is the three-year period immediately preceding the biennial review period. In addition, provide workpapers in executable Excel format supporting the calculations of the metrics as identified and defined in this schedule or supplemented by commission order. Where metric data for the historic benchmark period is not available upon filing, the reason shall be stated, and the data shall be provided as soon as it becomes available. To the extent practicable, data should be obtained from publicly available sources such as the SEC, FERC, EIA, and RTO.

Reliability:

1. SAIDI, excluding major events.

2. SAFI, excluding major events.

Generating Plant Performance:

3. XEFORd (non-nuclear) for the applicant and RTO benchmark group.

4. Net capacity factor (nuclear) for the applicant and U.S. Nuclear Industry (800-999 MW PWRs), excluding outages associated with the SLR Program.

5. Capacity factor (renewables).

Customer service:

6. Billing invoice accuracy percentage.

7. Average number of days to receive PTO for NEM interconnections.

8. Number and percentage of NEM waivers filed with commission staff.

9. Average number of days for non-NEM DER interconnection processing.

10. Customer satisfaction survey results.

Operating efficiency:

11. Resource economic efficiency for each of the applicant's owned generating units and purchased power resources, by year, expressed in dollars per year and dollars per MWh, produced by the generating unit or from a purchased power resource.

(b) In addition to the information required in paragraph (a), provide the metric data listed below for the applicant and any specified industry benchmark for the biennial review period and, separately, for each specified historical benchmark period. The historical benchmark period for the SAIDI, SAIFI, and emissions metrics (i.e., paragraph (b) subdivisions 1, 2, and 10 through 17) is the 10-year period immediately preceding the biennial review period. The historical benchmark period for all other metrics listed, if applicable, is the three-year period immediately preceding the biennial review period. In addition, provide workpapers in executable Excel format supporting the calculations of the metrics as identified and defined in this schedule or supplemented by commission order. Where metric data for the historic benchmark period is not available upon filing, the reason shall be stated, and the data shall be provided as soon as it becomes available. To the extent practicable, data should be obtained from publicly available sources such as SEC, FERC, EIA, and RTO.

Reliability:

1. SAIDI, including major events.

2. SAIFI, including major events.

3. Number of customers experiencing n sustained interruptions per year for each year of the historical benchmark period and biennial review period, where the variable n separately corresponds to the following categories: 0, 1 to 3, 4 to 6, 7 to 10, and more than 10 sustained interruptions.

4. Number of customers experiencing long interruption durations of n hours per year for each year of the historical benchmark period and biennial review period, where the variable n separately corresponds to the following intervals: more than three and less than or equal to six hours; more than six and less than or equal to 12 hours; more than 12 and less than or equal to 24 hours; more than 24 and less than or equal to 48 hours; and more than 48 hours.

5. SASR.

6. Increase in on-site energy storage of net metered customers, measured by the year-over-year increase in kW capacity of on-site energy storage of customers participating in the applicant's NEM program.

7. Increase in third-party PPA enrollment, measured by the year-over-year increase in MW capacity and MWh sales contracted for through third-party PPA enrollment.

Generating plant performance:

8. EAF (fossil fuel units only) for the applicant and RTO benchmark group.

9. Heat rates (coal and combined cycle units only) for the applicant and the national average U.S. Coal and U.S. Combined Cycle benchmark.

10. CO₂e, CO₂, CH₄, N₂O, NO_x, and SO₂ emissions from applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

11. CO₂ intensity, measured as a 12-month-by-24-hour profile for total CO₂ emissions, for applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

12. Mt CO₂e for applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

13. Mt CO₂e per MWh for applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

14. PM (PM 10 and PM 2.5) emissions per MWh for applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

15. Mercury emissions per MWh for applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

16. Lead emissions per MWh for applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

17. Criteria pollutants emissions per MWh for applicant-owned, Virginia jurisdictional, fossil-fuel generation units with a nameplate capacity over 25 MW and producing energy for sale.

18. MWh of curtailed DER generation per year.

19. MWh of curtailed non-DER renewable generation per year.

20. Percentage of energy delivered annually by storage systems (e.g., battery or pumped hydro) compared to the energy initially supplied to the storage system.

Customer Service:

21. Average speed of answer.

Operating Efficiency:

22. Annual large coal plant production costs.

23. Annual combined cycle plant production costs.

24. Number of hours managed EV charging was completed during off-peak hours compared to overall charging hours.

25. Identification of federal programs for technical assistance or funding for EV/EVSE and clean energy technology deployment for which the applicant has applied during the biennial review period.

26. Identification of grants or other awards the applicant has obtained through applications submitted during the biennial review period to federal programs for technical assistance or funding for EV/EVSE and clean energy technology deployment.

27. Available dispatchable demand response or DERMS capacity (MW) by delivery year.

28. MW of demand response dispatched per delivery year.

29. MW of peak load reduced during the delivery year.

30. Dollar savings from active DSM programs by DSM program year.

31. Incremental demand response capacity (MW) by DSM program year.

32. MW reduction in peak demand attributable to load management through AMI.

33. Percentage of new incremental customer-owned clean energy capacity added annually that is enrolled in applicant-sponsored DSM programs for each year of the biennial review period and the historical benchmark period.

34. Distribution system losses, in dollars per MWh, resulting from technical issues (e.g., the energy lost from the system as current moves over it), non-technical losses (e.g., losses from incorrect billing and theft), and contact voltage losses.

35. Increased system capacity (MW) gained through installation of grid-enhancing technologies per year for each year of the biennial review period and the historical benchmark period.

36. Average monthly bills by residential and commercial classes by year for each year of the biennial review period and the historical benchmark period.

37. Percentage of customers enrolled in time varying rates by customer class.

38. Total cost or balance, cost or balance per customer, cost or balance per MWh, and cost or balance per line mile for the following items:

a. Net rate base.

b. Non-fuel O&M cost.

c. Annual revenue growth.

d. Annual fuel costs.

e. Sum of all non-fuel cost tracker revenues.

f. Annual capital expenditure.

g. Annual capital cost, measured by annual depreciation expense plus the total return paid by customers.

Schedule 50 - Additional Schedules

Reserved for additional exhibits presented by the applicant to be labeled Schedule 50 et seq.