ATTACHMENT A - force.com

fl0718-1-223

€ A CMS Energy Company July 13, 2018 Ms. Kavita Kale Executive Secretary Michigan Public Service Commission 7109 West Saginaw Highway Post Office Box 30221 Lansing, MI 48909 Re: MPSC Case No. U-18322 – In the matter of the application of CONSUMERS

ENERGY COMPANY for authority to increase its rates for the generation and distribution of electricity and for other relief.

Dear Ms. Kale: Please find enclosed consistent with the Commission’s June 28, 2018 Order on Rehearing in the above captioned docket Consumers Energy Company’s revised tariff sheets (Attachment A), along with supporting workpapers in the form of a revised rate design (Attachment B). Also enclosed is a proof of service showing electronic service upon the parties to the proceeding. Please feel free to contact me should you have any questions, comments or concerns. Sincerely, Michael C. Rampe cc: Hon. Sharon L. Feldman, Administrative Law Judge Parties per Attachment 1 to Proof of Service

General Offices: LEGAL DEPARTMENT One Energy Plaza Tel: (517) 788-0550 CATHERINE M REYNOLDS

Senior Vice President and General Counsel

Ashley L Bancroft Robert W Beach Don A D’Amato Robert A. Farr Gary A Gensch, Jr. Gary L Kelterborn Chantez P Knowles Mary Jo Lawrie Jason M Milstone Rhonda M Morris Deborah A Moss* Mirče Michael Nestor Michael C. Rampe James D W Roush Scott J Sinkwitts Adam C Smith Theresa A G Staley Janae M Thayer Anne M Uitvlugt Aaron L Vorce

Attorney

Jackson, MI 49201 Fax: (517) 768-3644 *Washington Office: 1730 Rhode Island Ave. N.W. Suite 1007

Tel: (202) 778-3340 MELISSA M GLEESPEN Vice President, Corporate Secretary and Chief Compliance Officer

SHAUN M JOHNSON Vice President and Deputy General Counsel

Bret A Totoraitis Kelly M Hall Eric V Luoma Assistant General Counsel

Washington, DC 20036 Fax: (202) 778-3355 Writer’s Direct Dial Number: (517) 788-2194 Writer’s E-mail Address: [email protected]

ATTACHMENT A

M.P.S.C. No. 13 - Electric Consumers Energy Company Sheet No. C-24.00

(Continued From Sheet No. C-23.00)

C4. APPLICATION OF RATES (Contd) C4.3 Application of Residential Usage and Non-Residential Usage (Contd)

D. Rate Application for Seasonal Condominium Campgrounds (Contd)

(5) The customer must notify individuals and/or co-owners utilizing the customer's property that the customer's facilities may not be able to be located by Miss Dig.

(6) The customer must notify individuals and co-owners utilizing the customer's property that requests and concerns regarding electric service will be addressed between the single legal entity and ownership and primary operating authority, not with individuals.

(7) The customer shall be responsible for ensuring that the electrical facilities are adequate to meet the needs of the units placed within the Seasonal Condominium Campground in their entirety and shall pay the Company for any charges incurred for modifications necessary to accommodate load according to other portions of this Electric Rate Book.

C4.4 Resale

This provision is closed to resale for general unmetered service, unmetered or metered lighting service and new or expanded service for resale for residential use.

No customer shall resell electric service to others except when the customer is served under a Company rate expressly made available for resale purposes, and then only as permitted under such rate and under this rule.

Where, in the Company's opinion, the temporary or transient nature of the proposed ultimate use, physical limitation upon extensions, or other circumstances, make it impractical for the Company to extend or render service directly to the ultimate user, the Company may allow a customer to resell electric service to others.

For the purposes of this tariff, the provision of electric vehicle charging service for which there is no direct per kWh charge shall not be considered resale of service.

A resale customer is required to take service under the resale provision of one of the following rates for which they qualify: General Service Secondary Rate GS, General Service Secondary Demand Rate GSD, General Service Primary Rate GP, or Large General Service Primary Demand Rate GPD. Resale Service is provided pursuant to a service contract providing for such resale privilege. Service to each ultimate user shall be separately metered.

A. If the resale customer elects to take service under a Company Full Service resale rate, the ultimate user shall be served and charged for such service under standard Rate RS for residential use or under the appropriate standard General Service Rate applicable in the Company's Electric Rate Book available for similar service under like conditions. Reselling customers are not required to offer or administer any additional service provisions or nonstandard rates contained in the Electric Rate Book, such as the Income Assistance Service Provision, Residential Service Time-of-Day Secondary Rate RT or the Educational Institution Service Provision.

B. If the resale customer elects to take service under a Company Retail Open Access Service rate, the ultimate user shall be served and charged for such service under Rate ROA-R for residential use or under Rate ROA-S or ROA-P applicable in the Company's Electric Rate Book available for similar service under like conditions.

C. If the ultimate user is a campground lot or boat harbor slip, the resale customer has the option to charge a maximum of the following all inclusive rate per kWh in place of billing the ultimate customer on the appropriate standard Company tariff rate:

$0.153099 per kWh for all kWh during the months of June-September

$0.149178 per kWh for all kWh during the months of October-May

The Company shall be under no obligation to furnish or maintain meters or other facilities for the resale of service by the reselling customer to the ultimate user.

The service contract shall provide that the reselling customer's billings to the ultimate user shall be audited each year by February's month end, for the previous calendar year. The audit shall be conducted either by the Company, if the Company elects to conduct such audit, or by an independent auditing firm approved by the Company. The reselling customer shall be assessed a reasonable fee for an audit conducted by the Company. If the audit is conducted by an independent auditing firm, the customer shall submit a copy of the results of such audit to the Company in a form approved by the Company.

(Continued on Sheet No. C-25.00)

Attachment A Page 1 of 27

M.P.S.C. No. 13 - Electric Consumers Energy Company Sheet No. D-9.00

RESIDENTIAL SERVICE SECONDARY RATE RS Availability: Subject to any restrictions, this rate is available to any customer desiring electric service for any usual residential use in:

(i) private family dwellings; (ii) tourist homes, rooming houses, dormitories, nursing homes and other similarly occupied buildings containing sleeping accommodations for up to six persons; or (iii) existing multifamily dwellings containing up to four households served through a single meter. Service for single-phase or three-phase equipment may be included under this rate, provided the individual capacity of such equipment does not exceed 3 hp or 3 kW, nor does the total connected load of the home exceed 10 kW, without the specific consent of the Company.

This rate is not available for: (i) resale purposes; (ii) multifamily dwellings containing more than four living units served

through a single meter; (iii) tourist homes, rooming houses, dormitories, nursing homes and similarly occupied buildings containing sleeping accommodations for more than six persons; or (iv) any other Non-Residential usage.

Residences in conjunction with commercial or industrial enterprises and mobile home parks may take service on this rate

only under the Rules and Regulations contained in the Company's Electric Rate Book. Nature of Service: Service under this rate shall be alternating current, 60-Hertz, single-phase or three-phase (at the Company's option)

Secondary Voltage service. The Company will determine the particular nature of the voltage in each case. The Company will schedule meter readings on a monthly basis and attempt to obtain an actual meter reading for all tourist

and/or occasional residence customers at intervals of not more than six months. Monthly Rate:

(Continued on Sheet No. D-10.00)

Power Supply Charges: These charges are applicable to Full Service customers.

Energy Charge:

Non-Capacity Capacity Total

$ 0.061459 $ 0.033144 $0.094603 per kWh for the first 600 kWh per month during the billing months of June - September

$ 0.082726 $ 0.044613 $0.127339 per kWh for all kWh over 600 kWh per month during the billing months of June - September

$ 0.061459 $ 0.033144 $0.094603 per kWh for all kWh during the billing months of October-May

This rate is subject to the Power Supply Cost Recovery (PSCR) Factor shown on Sheet No. D-4.00.

Delivery Charges: These charges are applicable to Full Service and Retail Open Access customers.

System Access Charge: $7.00 per customer per month

Distribution Charge: $0.050510 per kWh for all kWh

This rate is subject to the Surcharges shown on Sheet Nos. D-2.00 through D-3.10 and the Power Plant Securitization Charges shown on Sheet No. D-5.10.



RESIDENTIAL DYNAMIC PRICING PROGRAM (Continued From Sheet No. D-13.00)

Monthly Rate: Option 1 – Peak Power Savers - Critical Peak Time of Use Rate (RDP):

Delivery Charges: These charges are applicable to Full Service Customers.


Distribution Charge: $ 0.050510 per kWh for all kWh for a Full Service Customer


Option 2 – Peak Power Savers – Peak Rewards Time-of-Use Rate (RDPR):


Power Supply Charges: These charges are applicable to Full Service customers. Energy Charge:


Off-Peak – Summer $0.041772 $0.017709 $0.059481 per kWh for all Off-Peak kWh during the billing

months of June-September

Mid-Peak – Summer $0.058218 $0.024681 $0.082899 per kWh for all Mid-Peak kWh during the billing


On-Peak – Summer $0.072892 $0.030902 $0.103794 per kWh for all On-Peak kWh during the billing


Off-Peak – Winter $0.057140 $0.030815 $0.087955 per kWh for all Off-Peak kWh during the billing months of October-May

On-Peak – Winter $0.065872 $0.035524 $0.101396 per kWh for all On-Peak kWh during the billing

months of October-May

Critical Peak Event $0.611119 $0.338881 $0.950000 per kWh during a critical peak event between June 1 and September 30


Power Supply Charges: These charges are applicable to Full Service Customers. Energy Charge:

Non-Capacity Capacity Total Off-Peak-Summer $0.050506 $0.027125 $0.077631 per kWh for all Off-Peak kWh during the billing


Mid-Peak-Summer $0.070391 $0.037804 $0.108195 per kWh for all Mid-Peak kWh during the billing months of June-September

On-Peak-Summer $0.088134 $0.047333 $0.135467 per kWh for all On-Peak kWh during the billing months of June-September

Off-Peak-Winter $0.057140 $0.030815 $0.087955 per kWh for all Off-Peak kWh during the billing months of October-May

On-Peak -Winter $0.065872 $0.035524 $0.101396 per kWh for all On-Peak kWh during the billing months of October-May

Critical Peak Reward $(0.611119) $(0.338881) $(0.950000) per kWh during a critical peak event between June 1 and September 30




RESIDENTIAL DYNAMIC PRICING PROGRAM (Continued From Sheet No. D-13.01)

Monthly Rate: (Contd) Option 2 – Peak Power Savers – Peak Rewards Time-of-Use Rate (RDPR): (Contd) Delivery Charges: These charges are applicable to Full Service Customers. System Access Charge $7.00 per customer per month Distribution Charge: $0.050510 per kWh for all kWh for a Full Service Customer


Income Assistance Service Provision (RIA):

When service is supplied to a Principal Residence Customer, where the household receives a Home Heating Credit (HHC) in the State of Michigan, a credit shall be applied during all billing months. For an income assistance customer to qualify for this credit the Company shall require annual evidence of the HHC energy draft or warrant. The customer may also qualify for this credit by meeting the requirements under Rule B2, Consumer Standards and Billing Practices for Electric and Gas Residential Customers, R 460.102, Definitions. Confirmation shall be required by an authorized State or Federal agency to verify that the customer’s total household income does not exceed 150% of the Federal poverty level. The monthly credit for the residential Income Assistance Service Provision shall be applied as follows :

Delivery Charges: These charges are applicable to Full Service and Retail Open Access Customers. Income Assistance Credit: $(7.00) per customer per month This credit shall not be taken in conjunction with a credit for the Senior Citizen Service Provision (RSC).

Senior Citizen Service Provision (RSC):

When service is supplied to the Principal Residence Customer who is 65 years of age or older and head of household, a credit shall be applied during all billing months. The monthly credit for the residential Senior Citizen Service Provision shall be applied as follows:

Delivery Charges: These charges are applicable to Full Service and Retail Open Access customers. Senior Citizen Credit: $(3.50) per customer per month This credit shall not be taken in conjunction with a credit for the Income Assistance Service Provision (RIA).



M.P.S.C. No. 13 – Electric Consumers Energy Company Sheet No. D-13.10 EXPERIMENTAL RESIDENTIAL PLUG-IN ELECTRIC VEHICLE CHARGING PROGRAM

Availability:

The Experimental Residential Plug-In Electric Vehicle Charging Program is a voluntary pilot available to Full Service residential customers. Upon enrollment of the customer in the program, the customer may take service under one of the following options as applicable:

Option 1 - Residential Home and Plug-in Electric Vehicle Time-of-Day Rate (REV-1) – Level 1 or Level 2 Charging of an electric vehicle combined with household electric usage such as space conditioning , cooking, water heating, refrigeration, clothes drying, incineration or lighting based upon on-peak, mid-peak and off-peak periods and through a single meter.

Option 2 - Residential Plug-In Electric Vehicle Only Time-of-Day Rate (REV-2) – Level 2 Charging of the electric vehicle based upon on-peak, mid-peak and off-peak periods through a separate meter. Electric usage for the household will be billed under the RS or RT Rate Schedule.

“Level 1 Charging” is defined as voltage connection of 120 volts and a maximum load of 12 amperes or 1.4 kVA.

“Level 2 Charging” is defined as voltage connection of either 240 volts or 208 volts and a maximum load of 32 amperes or 7.7 kVA at 240 volts or 6.7 kVA at 208 volts.

"Electric Vehicle Supply Equipment (EVSE)" is defined as the conductors, including the ungrounded, grounded and equipment grounding conductors, the electric vehicle connectors, attachment plugs, and all other fittings, devices, power outlets, or apparatus installed specifically for the purpose of delivering energy from the premise wiring to the electric vehicle.

Vehicles shall be registered and operable on public highways in the State of Michigan to qualify for this rate. Low-speed electric vehicles including golf carts are not eligible to take service under this rate even if licensed to operate on public streets. The customer may be required to provide proof of registration of the electric vehicle to qualify for program.

The total connected load of the home including the electric vehicle charging shall not exceed 10 kW, without the specific consent of the Company.

Customers shall not back-feed or transmit stored energy from the electric vehicle’s battery to the Company’s distribution system.

Nature of Service:

Service under this rate shall be alternating current, 60-Hertz, single-phase or three-phase (at the Company's option) Secondary Voltage service.

Monthly Rate:

Option 1 – REV-1:



Energy Charge:


Off-Peak – Summer $0.054616 $0.029411 $0.084027 per kWh for all Off-Peak kWh during the

billing months of June-September

Mid-Peak – Summer $0.076120 $0.040991 $0.117111 per kWh for all Mid-Peak kWh during the


On-Peak – Summer $0.095305 $0.051322 $0.146627 per kWh for all On-Peak kWh during the billing months of June-September

Off-Peak – Winter $0.054616 $0.029411 $0.084027 per kWh for all Off-Peak kWh during the

billing months of October-May

On-Peak – Winter $0.062963 $0.033906 $0.096869 per kWh for all On-Peak kWh during the





EXPERIMENTAL RESIDENTIAL PLUG-IN ELECTRIC VEHICLE CHARGING PROGRAM (Continued From Sheet No. D-13.10)

Monthly Rate (Contd)

Option 1 – REV – 1 (Contd) Delivery Charges: These charges are applicable to Full Service and Retail Open Access customers. System Access Charge: $7.00 per customer per month Distribution Charge: $0.050510 per kWh for all kWh for a Full Service customer


General Terms:

These rates are subject to all general terms and conditions shown on Sheet No . D-1.00.

Self-Generation Provision (SG):

As of June 8, 2012, this provision may be required for any Full Service Customer with a generating installation less than 550 kW operating in parallel with the Company’s system, which may employ cogeneration or small power production technology. All facilities must meet the Parallel Operation Requirements set forth in Rule C 1.6 B. The Company shall own, operate and maintain all metering and auxiliary devices (including telecommunication links) at the customer's expense. Meters furnished, installed and maintained by the Company shall meter generation equipment for customers that sell energy to the Company. No refund shall be made for any customer contribution required. Energy delivered to the Company shall be alternating current, 60-hertz, single-phase or three-phase (as governed by Rule B8., Electric Interconnection and Net Metering Standards) Secondary Voltage or Primary Voltage service. The Company will determine the particular nature of the voltage in each case .

Self-generation customers requiring Company delivery service for any portion of the load that has been self-generated will be charged as described in the Delivery Charges section of this Rate Schedule . Sales of Self-Generated Energy to the Company:

A customer who meets the Federal Energy Regulatory Commission’s (FERC) criteria for a Qualifying Facility may elect to sell energy to the Company. The Company has the right to refuse to contract for the purchase of energy. Sales of energy to the Company under this provision shall require a written contract with a minimum term of one year. Where the customer elects to sell energy to the Company, an Interval Data Meter (IDM) or other applicable meter is required for their generator. Meter reading will be accomplished electronically through telecommunication links or other electronic data methods able to provide the Company with the metering data / billing determinants necessary for billing purposes.

Administrative Cost Charge:

$0.0010 per kWh purchased for generation installations with a capacity of 100 kW or less. Energy Purchase:

An energy purchase by the Company shall be bought at the Midcontinent Independent System Operator’s, Inc. (MISO) real-time Locational Marginal Price (LMP) for the Company's load node (designated as "CONS.CETR" as of the date of this Rate Schedule). The Company may discontinue purchases during system emergencies, maintenance and other operational circumstance.




EXPERIMENTAL RESIDENTIAL PLUG-IN ELECTRIC VEHICLE CHARGING PROGRAM (Continued From Sheet No. D-13.20)

Monthly Rate (Contd) Option 2 - REV-2:

This rate is subject to the Surcharges shown on Sheet Nos. D-2.00 through D-3.10 and the Power Plant Securitization Charges shown on Sheet No. D-5.10. The REP Surcharge shown on Sheet No. D-2.10 shall not apply.

General Terms:

These rates are subject to all general terms and conditions shown on Sheet No . D-1.00. (Continued on Sheet No. D-13.30)


Energy Charge:


Off-Peak – Summer $0.054616 $0.029411 $0.084027 per kWh for all Off-Peak kWh during the


Mid-Peak – Summer $0.076120 $0.040991 $0.117111 per kWh for all Mid-Peak kWh during the


On-Peak – Summer $0.095305 $0.051322 $0.146627 per kWh for all On-Peak kWh during the billing months of June-September

Off-Peak – Winter $0.054616 $0.029411 $0.084027 per kWh for all Off-Peak kWh during the


On-Peak – Winter $0.062963 $0.033906 $0.096869 per kWh for all On-Peak kWh during the



Delivery Charges: These charges are applicable to Full Service and Retail Open Access customers

Distribution Charge: $0.050510 for all kWh



RESIDENTIAL SERVICE TIME-OF-DAY SECONDARY RATE RT

Availability:

Subject to any restrictions, this rate is available to any residential customer desiring electric service who chooses to have their electric consumption metered based upon on-peak and off-peak periods. In addition, this rate is available to customers desiring electric service for electric vehicle battery charging where such service is in addition to all other household requirements. Battery charging service is limited to four-wheel vehicles licensed for operation on public streets and highways. Service for single-phase or three-phase equipment may be included under this rate, provided the individual capacity of such equipment does not exceed 3 hp or 3 kW, nor does the total connected load of the home exceed 10 kW, without the specific consent of the Company. Service under this rate is limited to 10,000 customers. This rate is not available for resale purposes or for any Non -Residential usage.

Nature of Service:

Service under this rate shall be alternating current, 60-Hertz, single-phase or three-phase (at the Company's option) Secondary Voltage service. The Company will determine the particular nature of the voltage in each case.

Monthly Rate:

Income Assistance Service Provision (RIA): When service is supplied to a Principal Residence Customer, where the household receives a Home Heating Credit

(HHC) in the State of Michigan, a credit shall be applied during all billing months. For an income assistance customer to qualify for this credit the Company shall require annual evidence of the HHC energy draft or warrant. The customer may also qualify for this credit by meeting the requirements under Rule B2, Consumer Standards and Billing Practices for Electric and Gas Residential Customers,

R460.102, Definitions. Confirmation shall be required by an authorized State or Federal agency to verify that the customer’s total household income does not exceed 150% of the Federal poverty level.

The monthly credit for the residential Income Assistance Service Provision shall be applied as follows:

Delivery Charges: These charges are applicable to Full Service and Retail Open Access Customers.

Income Assistance Credit: $(7.00) per customer per month This credit shall not be taken in conjunction with a credit for the Senior Citizen Service Provision (RSC). (Continued on Sheet No. D-15.00)

Power Supply Charges: These charges are applicable to Full Service Customers. Energy Charge: Non-Capacity Capacity Total On-Peak-Summer $0.080976 $0.032182 $0.113158 per kWh for all On-Peak kWh during the billing

months of June-September Off-Peak-Summer $0.056108 $0.022299 $0.078407 per kWh for all Off-Peak kWh during the billing

months of June-September On-Peak-Winter $0.065314 $0.025958 $0.091272 per kWh for all On-Peak kWh during the billing

months of October-May Off-Peak -Winter $0.058042 $0.023068 $0.081110 per kWh for all Off-Peak kWh during the billing





Distribution Charge: $0.050510 per kWh for all kWh for a Full Service Customer




GENERAL SERVICE SECONDARY RATE GS Availability:

Subject to any restrictions, this rate is available to any general use customer, political subdivision or agency of the State of Michigan, either acting separately or in combinations permitted under the laws of this state, desiring Secondary Voltage service for any of the following: (i) standard secondary service, (ii) public potable water pumping and/or waste water system(s), or (iii) resale purposes. This rate is also available for service to any Primary Rate Customer where the Company elects to provide one transformation from the available Primary Voltage to another available Primary Voltage desired by the customer.

This rate is not available for: (i) private family dwellings, (ii) lighting service except for private streets, mobile home parks or service to temporary lighting installations, (iii) heating water for industrial processing, (iv) resale for lighting service, or (v) new or expanded service for resale to residential customers. Unmetered Billboard Service is not available to Retail Open Access service.

Nature of Service:


Three-phase, 3-wire service requires that the customer furnishes all transformation facilities required for single-phase load and so arranges the load as to avoid excessive unbalance of the three-phase load. When the service is single-phase, or 4-wire, three-phase, the single-phase individual motor capacity shall not exceed 3 hp, nor the total single-phase motor capacity of 10 hp, without the specific consent of the Company.

Where the Company elects to measure the service on the Primary side of the transformers, 3% shall be deducted for billing purposes from the energy measurements thus made. Where the Company elected to provide a Primary Rate Customer one transformation from the available Primary Voltage to another available Primary Voltage desired by the customer, 3% shall not be deducted for billing purposes from the energy measurements thus made.

Monthly Rate:

Billboard Service Provision: Monthly kWh shall be determined by multiplying the total connected load in kW (including the lamps, ballasts,

transformers, amplifiers, and control devices) times 730 hours. The kWh for cyclical devices shall be adjusted for the average number of hours used.


Power Supply Charges: These charges are applicable to Full Service customers. Energy Charge:


$0.064518 $0.032361 $0.096879 per kWh for all kWh during the billing months of June-September $0.061907 $0.031051 $0.092958 per kWh for all kWh during the billing months of October-May


Delivery Charges: These charges are applicable to Full Service and Retail Open Access customers.






GENERAL SERVICE SECONDARY TIME-OF-USE RATE GSTU Availability

Subject to any restrictions, General Service Secondary Time-of-Use Rate GSTU is available to any Full Service Customer taking service at the Company’s Secondary Voltage level with advanced metering infrastructure and supporting critical systems.

This rate is not available for: (i) private family dwellings, (ii) lighting service except for private streets, mobile home parks or service to temporary lighting installations, (iii) heating water for industrial processing, (iv) resale for lighting service, or (v) new or expanded service for resale to residential customers.

This rate shall not be taken in conjunction with any other Demand Response Program or Net Metering.

Nature of Service


Three-phase, 3-wire service requires that the customer furnishes all transformation facilities required for single-phase load and so arranges the load as to avoid excessive unbalance of the three-phase load. When the service is single-phase, or 4-wire, three-phase, the single-phase individual motor capacity shall not exceed 3 hp, nor the total single-phase motor capacity of 10 hp, without the specific consent of the Company.

Where the Company elects to measure the service on the Primary side of the transformers, 3% shall be deducted for billing purposes from the energy measurements thus made. Where the Company elected to provide a Primary Rate Customer one transformation from the available Primary Voltage to another available Primary Voltage desired by the customer, 3% shall not be deducted for billing purposes from the energy measurements thus made.

Monthly Rate


Power Supply Charges: These charges are applicable to Full Service Customers. Energy Charge: Non-Capacity Capacity Total Off-Peak-Summer $0.059509 $0.029848 $0.089357 per kWh for all Off-Peak kWh during the billing

months of June-September Mid-Peak-Summer $0.090026 $0.045155 $0.135181 per kWh for all Mid-Peak kWh during the billing

months of June-September On-Peak-Summer $0.112717 $0.056536 $0.169253 per kWh for all On-Peak kWh during the billing

months of June-September Off-Peak-Winter $0.050823 $0.025492 $0.076315 per kWh for all Off-Peak kWh during the billing

months of October-May On-Peak -Winter $0.057191 $0.028686 $0.085877 per kWh for all On-Peak kWh during the billing



Delivery Charges: These charges are applicable to Full Service Customers.


Distribution Charge: $0.042765 per kWh for all kWh for a Full Service Customer




GENERAL SERVICE SECONDARY DEMAND RATE GSD Availability: Subject to any restrictions, this rate is available to any customer desiring Secondary Voltage service, either for general use

or resale purposes, where the Peak Demand is 5 kW or more. This rate is also available for service to any Primary Rate Customer where the Company elects to provide one transformation from the available Primary Voltage to another available Primary Voltage desired by the customer.

This rate is not available for: (i) private family dwellings, (ii) lighting service, (iii) resale for lighting service, or (iv) new or expanded service for resale to residential customers.

Nature of Service: Service under this rate shall be alternating current, 60-Hertz, single-phase or three-phase (at the Company's option)

Secondary Voltage service. The Company will determine the particular nature of the voltage in each case. Three-phase, 3-wire service requires that the customer furnishes all transformation facilities required for single-phase

load and so arranges the load as to avoid excessive unbalance of the three-phase load. When the service is single-phase, or 4-wire, three-phase, the single-phase individual motor capacity shall not exceed 3 hp, nor the total single-phase motor capacity of 10 hp, without the specific consent of the Company.

Where the Company elects to measure the service on the Primary side of the transformers, 3% shall be deducted for billing purposes from the demand and energy measurements thus made. Where the Company elected to provide a Primary Rate Customer one transformation from the available Primary Voltage to another available Primary Voltage desired by the customer, 3% shall not be deducted for billing purposes from the energy measurements thus made.

Monthly Rate:


Power Supply Charges: These charges are applicable to Full Service Customers.

Capacity Charge:

$12.30 per kW for all kW of Peak Demand during the billing months of June-September $10.30 per kW for all kW of Peak Demand during the billing months of October-May Energy Charge: Non-Capacity $0.066286 per kWh for all kWh during the billing months of June-September $0.061142 per kWh for all kWh during the billing months of October-May.


Delivery Charges: These charges are applicable to Full Service and Retail Open Access (ROA) customers.


Capacity Charge: $1.15 per kW for all kW of Peak Demand





GENERAL SERVICE SECONDARY DEMAND RATE GSD (Continued From Sheet No. D-23.00)

Monthly Rate: (Contd)

Educational Institution Service Provision (GEI):

When service is supplied to a school, college or university, a credit shall be applied during all billing months. As used in this provision, “school” shall mean buildings, facilities, playing fields, or property directly or indirectly used for school purposes for children in grades kindergarten through twelve, when provided by a public or nonpublic school. School does not include instruction provided in a private residence or proprietary trade, vocational, training, or occupational school. “College” or “University” shall mean buildings located on the same campus and used to impart instruction, including all adjacent and appurtenant buildings owned by the same customer which are located on the same campus and which constitute an integral part of such college or university facilities.

The monthly credit for the Educational Institution Service Provision shall be applied as follows:


Education Institution Credit: $ (0.000618) per kWh for all kWh

Customers on this provision shall require a written contract, with a minimum term of one year, and shall be evaluated annually to determine whether or not the accounts shall remain on the service provision.

Self-Generation Provision (SG):

Subject to any restrictions, as of June 8, 2012, this provision may be required for any Full Service Customer with a

generating installation less than 550 kW operating in parallel with the Company’s system, which may employ cogeneration or small power production technology.

All facilities operated in parallel with the Company’s system must meet the Parallel Operation Requirements set forth

in Rule C1.6 B. The Company shall own, operate and maintain all metering and auxiliary devices (including telecommunication links) at the customer's expense. Meters furnished, installed and maintained by the Company shall meter generation equipment for customers that sell energy to the Company. No refund shall be made for any customer contribution required.

Energy delivered to the Company shall be alternating current, 60-hertz, single-phase or three-phase (as governed by

Rule B8., Electric Interconnection and Net Metering Standards) Secondary Voltage or Primary Voltage service. The Company will determine the particular nature of the voltage in each case.

Self-generation customers requiring Company delivery service for any portion of the load that has been self-generated

will be charged as described in the Delivery Charges section of this Rate Schedule.

There shall be no double billing of demand under the base rate and the Self-Generation Provision.

Sales of Self-Generated Energy to the Company:

A customer who meets the Federal Energy Regulatory Commission’s (FERC) criteria for a Qualifying Facility may elect to sell energy to the Company. The Company has the right to refuse to contract for the purchase of energy. Sales of energy to the Company under this provision shall require a written contract with a minimum term of one year.

Where the customer elects to sell energy to the Company, an Interval Data Meter (IDM) or other applicable meter is

required for their generator. Meter reading will be accomplished electronically through telecommunication links or other electronic data methods able to provide the Company with the metering data / billing determinants necessary for billing purposes.

Administrative Cost Charge: $0.0010 per kWh purchased for generation installations with a capacity of 100 kW or less (Continued on Sheet No. D-24.10)



GENERAL SERVICE PRIMARY RATE GP Availability: Subject to any restrictions, this rate is available to any customer, political subdivision or agency of the State of Michigan,

either acting separately or in combinations permitted under the laws of this state, desiring Primary Voltage service for general use or for public potable water pumping and/or waste water system(s).

This rate is available to existing Full Service Customers with an electric generating facility interconnected at a primary

voltage level utilizing General Service Primary Rate GP for standby service on or before June 7, 2012. The amount of retail usage shall be determined on an hourly basis. Customers with a generating installation are required to have an Interval Data Meter.

This rate is not available to a Primary Rate Customer where the Company elects to provide one transformation from the

available Primary Voltage to another available Primary Voltage desired by the customer. This rate is not available for lighting service, except for temporary service for lighting installations. Nature of Service: Service under this rate shall be alternating current, 60-Hertz, single-phase or three-phase (at the Company's option)

Primary Voltage service. The Company will determine the particular nature of the voltage in each case. Where service is supplied at a nominal voltage of 25,000 Volts or less, the customer shall furnish, install and maintain all

necessary transforming, controlling and protective equipment. Where the Company elects to measure the service at a nominal voltage above 25,000 Volts, 1% shall be deducted for

billing purposes, from the energy measurements thus made. Where the Company elects to measure the service at a nominal voltage of less than 2,400 Volts, 3% shall be added for

billing purposes, to the energy measurements thus made. Monthly Rate:


Power Supply Charges: These charges are applicable to Full Service customers. Charges for Customer Voltage Level 3 (CVL3) Energy Charge: Non-Capacity Capacity Total $0.059274 $0.041771 $0.101045 per kWh for all kWh during the billing months of June-September $0.057187 $0.040392 $0.097579 per kWh for all kWh during the billing months of October-May

Charges for Customer Voltage Level 2 (CVL2) Energy Charge: Non-Capacity Capacity Total $0.053574 $0.036071 $0.089645 per kWh for all kWh during the billing months of June-September $0.051487 $0.034692 $0.086179 per kWh for all kWh during the billing months of October-May

Charges for Customer Voltage Level 1 (CVL1) Energy Charge: Non-Capacity Capacity Total $0.051574 $0.034071 $0.085645 per kWh for all kWh during the billing months of June-September $0.049487 $0.032692 $0.082179 per kWh for all kWh during the billing months of October-May This rate is subject to the Power Supply Cost Recovery (PSCR) Factor shown on Sheet No. D-4.00.



GENERAL SERVICE PRIMARY RATE GP (Continued From Sheet No. D-27.00)

Monthly Rate (Contd)

Delivery Charges: These charges are applicable to Full Service and Retail Open Access (ROA) customers.


Charges for Customer Voltage Level 3 (CVL3) Distribution Charge: $0.017248 per kWh for all kWh




Adjustment for Power Factor This rate requires a determination of the average Power Factor maintained by the customer during the billing period . Such

average Power Factor shall be determined through metering of lagging Kilovar-hours and Kilowatt-hours during the billing period. The calculated ratio of lagging Kilovar-hours to Kilowatt-hours shall then be converted to the average Power Factor for the billing period by using the appropriate conversion factor. Whenever the average Power Factor during the billing period is above .899 or below .850, the customer bill shall be adjusted as follows:

(a) If the average Power Factor during the billing period is .900 or higher, a 0.50% credit will be applied to all metered-

based charges, excluding surcharges. This credit shall not in any case be used to reduce the prescribed Minimum Charge.

(b) If the average Power Factor during the billing period is less than .850, a penalty will be applied to all metered-based

charges, excluding surcharges, in accordance with the following table:

Power Factor Penalty 0.800 to 0.849 0.50% 0.750 to 0.799 1.00% 0.700 to 0.749 2.00% Below 0.700 3% first 2 months

(c) A Power Factor less than 0.700 is not permitted and necessary corrective equipment must be installed by the

customer. A 15% penalty will be applied to any metered-based charges, excluding surcharges, after two consecutive months below 0.700 Power Factor and will continue as long as the Power Factor remains below 0.700. Once the customer's Power Factor exceeds 0.700, it is necessary to complete two consecutive months below 0.700 before the 15% penalty applies again.

Resale Service Provision Subject to any restrictions, this provision is available to customers desiring Primary Voltage service for resale purposes in

accordance with Rule C4.4, Resale. (Continued on Sheet No. D-28.00)



GENERAL SERVICE PRIMARY RATE GP (Continued From Sheet No. D-27.10)

Monthly Rate (Contd) Substation Ownership Credit Where service is supplied at a nominal voltage of more than 25,000 volts, and the customer provides all of the

necessary transforming, controlling and protective equipment for all of the service there shall be deducted from the bill a monthly credit.

The monthly credit for the substation ownership shall be applied as follows:

Delivery Charges - These charges are applicable to Full Service and Retail Open Access customers.

Substation Ownership Credit: $ (0.000394) per kWh for all kWh For those customers served by more than one substation where one or more of the substations is owned by the

customer, the credit will be applied to the customer's coincident Maximum Demand for those substations owned by the customer. This credit shall not operate to reduce the customer’s billing below the prescribed minimum charges included in the rate. The credit shall be based on the kW after the 1% deduction or 3% addition has been applied to the metered kWh.

Educational Institution Service Provision (GEI) When service is supplied to a school, college or university, a credit shall be applied during all billing months. As used in

this provision, “school” shall mean buildings, facilities, playing fields, or property directly or indirectly used for school purposes for children in grades kindergarten through twelve, when provided by a public or nonpublic school. School does not include instruction provided in a private residence or proprietary trade, vocational, training, or occupational school. “College” or “University” shall mean buildings located on the same campus and used to impart instruction, including all adjacent and appurtenant buildings owned by the same customer which are located on the same campus and which constitute an integral part of such college or university facilities.

The monthly credit for the Educational Institution Service Provision shall be applied as follows:

Delivery Charges - These charges are applicable to Full Service and Retail Open Access Customers.

Educational Institution Credit: $(0.000530) per kWh for all kWh Customers on this provision shall require a written contract, with a minimum term of one year, and shall be

evaluated annually to determine whether or not the accounts shall remain on the service provision. Self-Generation Provision (SG): As of June 8, 2012, this provision may be required for any Full Service Customer with a generating installation less than

550 kW operating in parallel with the Company's system, which may employ cogeneration or small power production technology.

All facilities operated in parallel with the Company's system must meet the Parallel Operation Requirements set forth in

Rule C1.6B. The Company shall own, operate and maintain all metering and auxiliary devices (including telecommunication links) at the customer's expense. Meters furnished, installed and maintained by the Company shall meter generation equipment for customers that sell energy to the Company. No refund shall be made for any customer contribution required.

Energy delivered to the Company shall be alternating current, 60-hertz, single-phase or three-phase (as governed by Rule

B8., Electric Interconnection and Net Metering Standards) Secondary Voltage or Primary Voltage service. The Company will determine the particular nature of the voltage in each case.

Self-generation customers requiring Company delivery service for any portion of the load that has been self-generated will

be charged as described in the Delivery Charges section of this Rate Schedule. (Continued on Sheet No. D-29.00)



LARGE GENERAL SERVICE PRIMARY DEMAND RATE GPD Availability Subject to any restrictions, this rate is available to any customer desiring Primary Voltage service, either for general use or

resale purposes, where the On-Peak Billing Demand is 25 kW or more. This rate is also available to any political subdivision or agency of the State of Michigan, either acting separately or in combinations permitted under the laws of this state, for Primary Voltage service for potable water pumping and/or waste water system(s).

This rate is not available to a Primary Rate Customer where the Company elects to provide one transformation from the

available Primary Voltage to another available Primary Voltage desired by the customer. This rate is also not available for lighting service, for resale for lighting service, or for new or expanded service for resale to

residential customers. Nature of Service Service under this rate shall be alternating current, 60-Hertz, single-phase or three-phase (at the Company's option) Primary

Voltage service. The Company will determine the particular nature of the voltage in each case. Where service is supplied at a nominal voltage of 25,000 Volts or less, the customer shall furnish, install and maintain all

necessary transforming, controlling and protective equipment. Where the Company elects to measure the service at a nominal voltage above 25,000 Volts, 1% shall be deducted for billing

purposes, from the demand and energy measurements thus made. Where the Company elects to measure the service at a nominal voltage of less than 2,400 Volts, 3% shall be added for

billing purposes, to the demand and energy measurements thus made. Interval Data Meters are required for service under this rate. Meter reading will be accomplished electronically through

telecommunication links or other electronic data methods able to provide the Company with the metering data / billing determinants necessary for billing purposes.

Monthly Rate:


Power Supply Charges: These charges are applicable to Full Service customers. Charges for Customer Voltage Level 3 (CVL3)

Demand Charge:

Capacity Non-Capacity Total $12.66 $7.74 $20.40 per kW of On-Peak Billing Demand during the billing

months of June-September $11.66 $7.74 $19.40 per kW of On-Peak Billing Demand during the billing

months of October-May Transmission Charge: Capacity $1.84 per kW of On-Peak Billing Demand during the billing months of June-September $1.84 per kW of On-Peak Billing Demand during the billing months of October-May Energy Charge: Non-Capacity $0.053971 per kWh for all On-Peak kWh during the billing months of

June-September $0.038070 per kWh for all Off-Peak kWh during the billing months of

June-September $0.044018 per kWh for all On-Peak kWh during the billing months of

October-May $0.039974 per kWh for all Off-Peak kWh during the billing months of

October-May



LARGE GENERAL SERVICE PRIMARY DEMAND RATE GPD (Continued From Sheet No. D-31.00)


Charges for Customer Voltage Level 1 (CVL1)

Demand Charge: Capacity Non-Capacity Total $10.66 $7.74 $18.40 per kW of On-Peak Billing Demand during the billing


months of October-May Transmission Charge:

Capacity $1.84 per kW of On-Peak Billing Demand during the billing months of June-September $1.84 per kW of On-Peak Billing Demand during the billing months of October-May Energy Charge: Non-Capacity $0.046271 per kWh for all On-Peak kWh during the billing months of




October-May

This rate is subject to the Power Supply Cost Recovery (PSCR) Factor shown on Sheet No. D-4.00. (Continued on Sheet No. D-31.10)

Power Supply Charges: These charges are applicable to Full Service customers. (Contd)


Demand Charge: Capacity Non-Capacity Total $11.66 $7.74 $19.40 per kW of On-Peak Billing Demand during the billing


months of October-May Transmission Charge: Capacity $1.84 per kW of On-Peak Billing Demand during the billing months of June-September $1.84 per kW of On-Peak Billing Demand during the billing months of October-May Energy Charge: Non-Capacity $0.048271 per kWh for all On-Peak kWh during the billing months of




October-May



LARGE GENERAL SERVICE PRIMARY DEMAND RATE GPD (Continued From Sheet No. D-31.05)


Delivery Charges: These charges are applicable to Full Service and Retail Open Access (ROA) customers. System Access Charge: $200.00 per customer per month Charges for Customer Voltage Level 3 (CVL3) Capacity Charge: $4.20 per kW of Maximum Demand Charges for Customer Voltage Level 2 (CVL2) Capacity Charge: $1.85 per kW of Maximum Demand Charges for Customer Voltage Level 1 (CVL1) Capacity Charge: $0.96 per kW of Maximum Demand


Adjustment for Power Factor: This rate requires a determination of the average Power Factor maintained by the customer during the billing period. Such

average Power Factor shall be determined through metering of lagging Kilovar-hours and Kilowatt-hours during the billing period. The calculated ratio of lagging Kilovar-hours to Kilowatt-hours shall then be converted to the average Power Factor for the billing period by using the appropriate conversion factor. Whenever the average Power Factor during the billing period is above .899 or below .850, the customer bill shall be adjusted as follows:

(a) If the average Power Factor during the billing period is .900 or higher, a 0.50% credit will be applied to all metered-

based charges, excluding surcharges. This credit shall not in any case be used to reduce the prescribed Minimum Charge.

(b) If the average Power Factor during the billing period is less than .850, a penalty will be applied to all metered-based

charges, excluding surcharges, in accordance with the following table: Power Factor Penalty 0.800 to 0.849 0.50% 0.750 to 0.799 1.00% 0.700 to 0.749 2.00% Below 0.700 3% first 2 months Adjustment for Power Factor shall not be applied when the On-Peak Billing Demand is based on 60% of the highest

On-Peak Billing Demand created during the preceding bill months of June through September or on a Minimum On-Peak Billing Demand.

(c) A Power Factor less than 0.700 is not permitted and necessary corrective equipment must be installed by the customer.

A 15% penalty will be applied to any metered-based charges, excluding surcharges, after two consecutive months below 0.700 Power Factor and will continue as long as the Power Factor remains below 0.700. Once the customer's Power Factor exceeds 0.700, it is necessary to complete two consecutive months below 0.700 before the 15% penalty applies again.




GENERAL SERVICE PRIMARY TIME-OF-USE RATE GPTU (Continued from Sheet No. D-36.10)

Monthly Rate:

Delivery Charges:



Capacity Charge: $4.20 per kW of Maximum Demand





Adjustment for Power Factor This rate requires a determination of the average Power Factor maintained by the customer during the billing period.

Such average Power Factor shall be determined through metering of lagging Kilovar-hours and Kilowatt-hours during the billing period. The calculated ratio of lagging Kilovar-hours to Kilowatt-hours shall then be converted to the average Power Factor for the billing period by using the appropriate conversion factor. Whenever the average Power Factor during the billing period is above .899 or below .850, the customer bill shall be adjusted as follows:


Power Supply Charges: Charges for Customer Voltage Level 3 (CVL3) Energy Charge: Non-Capacity Capacity Total Off-Peak-Summer $0.055489 $0.020130 $0.075619 per kWh during the calendar months of June-September Low-Peak-Summer $0.072903 $0.024660 $0.097563 per kWh during the calendar months of June-September Mid-Peak-Summer $0.087210 $0.028381 $0.115591 per kWh during the calendar months of June-September High-Peak-Summer $0.093275 $0.029959 $0.123234 per kWh during the calendar months of June-September

Off-Peak -Winter $0.054854 $0.019965 $0.074819 per kWh during the calendar months of October-May Mid-Peak -Winter $0.061668 $0.021737 $0.083405 per kWh during the calendar months of October-May High-Peak -Winter $0.064524 $0.022480 $0.087004 per kWh during the calendar months of October-May Charges for Customer Voltage Level 2 (CVL2) Energy Charge: Non-Capacity Capacity Total Off-Peak-Summer $0.049789 $0.014430 $0.064219 per kWh during the calendar months of June-September Low-Peak-Summer $0.067203 $0.018960 $0.086163 per kWh during the calendar months of June-September Mid-Peak-Summer $0.081510 $0.022681 $0.104191 per kWh during the calendar months of June-September High-Peak-Summer $0.087575 $0.024259 $0.111834 per kWh during the calendar months of June-September

Off-Peak - Winter $0.049154 $0.014265 $0.063419 per kWh during the calendar months of October-May Mid-Peak - Winter $0.055968 $0.016037 $0.072005 per kWh during the calendar months of October-May High-Peak - Winter $0.058824 $0.016780 $0.075604 per kWh during the calendar months of October-May Charges for Customer Voltage Level 1 (CVL1) Energy Charge: Non-Capacity Capacity Total Off-Peak-Summer $0.047789 $0.012430 $0.060219 per kWh during the calendar months of June-September Low-Peak-Summer $0.065203 $0.016960 $0.082163 per kWh during the calendar months of June-September Mid-Peak-Summer $0.079510 $0.020681 $0.100191 per kWh during the calendar months of June-September High-Peak-Summer $0.085575 $0.022259 $0.107834 per kWh during the calendar months of June-September

Off-Peak - Winter $0.047154 $0.012265 $0.059419 per kWh during the calendar months of October-May Mid-Peak - Winter $0.053968 $0.014037 $0.068005 per kWh during the calendar months of October-May High-Peak - Winter $0.056824 $0.014780 $0.071604 per kWh during the calendar months of October-May



ENERGY INTENSIVE PRIMARY RATE EIP (Continued from Sheet No. D-37.00)

Schedule of Hours: The following schedule shall apply Monday through Friday (except holidays designated by the Company): Summer: Off-Peak Hours: 12:00 AM to 6:00 AM and 11:00 PM to 12:00 AM Low-Peak Hours: 6:00 AM to 2:00 PM and 6:00 PM to 11:00 PM Mid-Peak Hours: 2:00 PM to 3:00 PM and 5:00 PM to 6:00 PM High-Peak Hours: 3:00 PM to 5:00 PM Critical Peak Hours: 3:00 PM to 5:00 PM during a Critical Peak Event Winter: Off-Peak Hours: 12:00 AM to 4:00 PM and 8:00 PM to 12:00 AM Mid-Peak Hours: 4:00 PM to 5:00 PM and 7:00 PM to 8:00 PM High-Peak Hours: 5:00 PM to 7:00 PM Critical Peak Hours: 5:00 PM to 7:00 PM during a Critical Peak Event Weekends and holidays are off-peak. Designated Company holidays are: New Year's Day - January 1; Memorial Day - Last Monday in May; Independence Day - July 4; Labor Day - First Monday in September; Thanksgiving Day - Fourth Thursday in November; and Christmas Day - December 25. Whenever January 1, July 4, or December 25 fall on Sunday, extended holiday periods such as Monday, January 2, Monday, July 5 and Monday, December 26 shall not be considered as holidays for application of off-peak hours. Monthly Rate:


Power Supply Charges: Charges for Customer Voltage Level 3 (CVL3) Energy Charge: Non-Capacity Capacity Total Off-Peak-Summer $0.038938 $0.008254 $0.047192 per kWh during the calendar months of June-September Low-Peak-Summer $0.050262 $0.014146 $0.064408 per kWh during the calendar months of June-September Mid-Peak-Summer $0.059566 $0.018987 $0.078553 per kWh during the calendar months of June-September High-Peak-Summer $0.063349 $0.020955 $0.084304 per kWh during the calendar months of June-September Critical Peak-Summer the greater of either 150% of the High-Peak - Summer

Energy Charge or the average Market price per kWh for a Critical Peak Event during the calendar months of June - September

Off-Peak - Winter $0.040001 $0.008807 $0.048808 per kWh during the calendar months of October-May Mid-Peak - Winter $0.049433 $0.013715 $0.063148 per kWh during the calendar months of October-May High-Peak - Winter $0.059791 $0.019104 $0.078895 per kWh during the calendar months of October-May Critical Peak-Winter the greater of either 150% of the High-Peak Winter

Energy Charge or the average Market price per kWh for a Critical Peak Event during the calendar months of October - May



ENERGY INTENSIVE PRIMARY RATE EIP (Continued from Sheet No. D-37.10)

Monthly Rate (Contd):


Power Supply Charges: (Contd) Charges for Customer Voltage Level 2 (CVL2) Energy Charge: Non-Capacity Capacity Total Off-Peak-Summer $0.033238 $0.019254 $0.052492 per kWh during the calendar months of June-September Low-Peak-Summer $0.044562 $0.025146 $0.069708 per kWh during the calendar months of June-September Mid-Peak-Summer $0.053866 $0.029987 $0.083853 per kWh during the calendar months of June-September High-Peak-Summer $0.057649 $0.031955 $0.089604 per kWh during the calendar months of June-September Critical Peak-Summer the greater of either 150% of the High-Peak-Summer

Energy Charge or the average Market price per kWh for a Critical Peak Event during the calendar months of June-September

Off-Peak - Winter $0.034301 $0.019807 $0.054108 per kWh during the calendar months of October - May Mid-Peak - Winter $0.043733 $0.024715 $0.068448 per kWh during the calendar months of October - May High-Peak - Winter $0.054091 $0.030104 $0.084195 per kWh during the calendar months of October - May Critical Peak-Winter the greater of either 150% of the High-Peak Winter


Charges for Customer Voltage Level 1(CVL1) Energy Charge: Non-Capacity Capacity Total Off-Peak-Summer $0.031238 $0.016254 $0.047492 per kWh during the calendar months of June-September Low-Peak-Summer $0.042562 $0.022146 $0.064708 per kWh during the calendar months of June-September Mid-Peak-Summer $0.051866 $0.026987 $0.078853 per kWh during the calendar months of June-September High-Peak-Summer $0.055649 $0.028955 $0.084604 per kWh during the calendar months of June-September Critical Peak-Summer the greater of either 150% of the High-Peak-Summer

Energy Charge or the average Market price per kWh for a Critical Peak Event during the calendar months of June-September

Off-Peak - Winter $0.032301 $0.016807 $0.049108 per kWh during the calendar months of October - May Mid-Peak - Winter $0.041733 $0.021715 $0.063448 per kWh during the calendar months of October - May High-Peak - Winter $0.052091 $0.027104 $0.079195 per kWh during the calendar months of October - May Critical Peak-Winter the greater of either 150% of the High-Peak Winter


Delivery Charges: System Access Charge: $200.00 per customer per month Charges for Customer Voltage Level 3 (CVL3) Capacity Charge: $4.20 per kW of Maximum Demand Charges for Customer Voltage Level 2 (CVL2) Capacity Charge: $1.85 per kW of Maximum Demand Charges for Customer Voltage Level 1 (CVL1) Capacity Charge: $0.96 per kW of Maximum Demand This rate is subject to the Surcharges shown on Sheet Nos. D-2.00 through D-3.10 and the Power Plant Securitization

Charges shown on Sheet No. D-5.10.



GENERAL SERVICE SELF GENERATION RATE GSG-2 (Continued From Sheet No. D-42.00)

Nature of Service (Contd)

Where service is supplied at a nominal voltage equal to or greater than 2,400 volts and the Company elects to measure the service at a nominal voltage above 25,000 volts, 1% shall be deducted for billing purposes, from the demand and energy measurements thus made.

Where service is supplied at a nominal voltage equal to or greater than 2,400 volts and the Company elects to measure the service at a nominal voltage of less than 2,400 volts, 3% shall be added for billing purposes, to the demand and energy measurements thus made.

Where service is supplied at a nominal voltage less than 2,400 volts and the Company elects to measure the service at a nominal voltage equal to or greater than 2,400 volts, 3% shall be deducted for billing purposes from the energy measurements thus made.

There shall be no double billing of demand under the base rate and Rate GSG-2.

Monthly Rate Standby Charges Power Supply Standby Charges

For all standby energy supplied by the Company, the customer shall be responsible for the MISO Real-Time Locational Market Price (LMP) for the Company's load node (designated as "CONS.CETR" as of the date of this Rate Schedule), multiplied by the customer’s consumption (kWh), plus the Market Settlement Fee of $0.002/kWh. In addition capacity charges will be assessed monthly, calculated using the highest 15 minute kW demand associated with Standby Service occurring during the Company's On-Peak billing hours will be multiplied by the highest contracted capacity purchased by the Company in that month, plus allocated transmission and ancillaries. The capacity charges will be prorated based on the number of On-Peak days that Standby Service was used during the billing month. A customer with a generator(s) nameplate rating more than 550 kW must provide written notice to the Company by December 1 if they desire standby service in the succeeding calendar months of June through September. Written notice shall be submitted on Company Form 500. If the customer fails to meet this written notice requirement, the LMP shall be increased by applying a 10% adder.

Delivery Standby Charges System Access Charge: Generator that does not meet or exceed load: $100.00 per generator installation per month Generator that meets or exceeds load: $200.00 per generator installation per month

Charges for Customer Voltage Level 3 (CVL 3)

Capacity Charge: $4.20 per kW of Standby Demand









GENERAL SERVICE METERED LIGHTING RATE GML Availability Subject to any restrictions, this rate is available to any political subdivision or agency of the State of Michigan having

jurisdiction over public streets or roadways, for Primary or Secondary Voltage energy-only metered lighting service where the Company has existing distribution lines available for supplying energy for such service. Luminaires which are served under the Company's unmetered lighting rates shall not be intermixed with luminaires served under this metered lighting rate. Luminaire types in addition to those served on Rate Schedule GUL, such as light-emitting diode (LED) streetlights, may receive service under this Rate Schedule.

This rate is not available for resale purposes or for Retail Open Access Service. Nature of Service Secondary Voltage Service under this rate shall be alternating current, 60-hertz, single-phase or three-phase (at the Company's option),

120/240 nominal Volt service for a minimum of ten luminaires located within a clearly defined area. Control equipment shall be furnished, owned and maintained by the Company. The customer shall furnish, install, own and maintain the rest of the equipment comprising the metered lighting system including, but not limited to, the overhead wires or underground cables between the luminaires, protective equipment, and the supply circuits extending to the point of attachment with the Company's distribution system. The Company shall connect the customer's equipment to the Company's lines and supply the energy for its operation. All of the customer's equipment shall be subject to the Company's approval. The customer shall not change the capacity requirements of the equipment owned by it without first notifying the Company in writing of such changes and the date that they shall be made.

Dusk to Midnight Service Dusk to midnight service shall be the same as Secondary service except: The customer shall pay the difference between the cost of the control equipment necessary for dusk to midnight

service and control equipment normally installed for Secondary service. Circuits shall be arranged approximating minimum loads of 3 kW.

Primary Voltage Service under this rate shall be alternating current, 60-hertz, single-phase or three-phase (at the Company's option),

Primary Voltage service for actual kW demands of not less than 100 kW for each point of delivery and where the customer guarantees a minimum of 4,000 annual hours' use of the actual demand. The Company will determine the particular nature of the voltage in each case. The customer shall furnish, install, own and maintain all equipment comprising the metered lighting system including, but not limited to, controls, protective equipment, transformers and overhead or underground metered lighting circuits extending to the point of attachment with the Company's distribution system. The Company shall furnish, install, own and maintain the metering equipment and connect the customer's metered lighting circuit to its distribution system and supply the energy for operation of the customer's metered lighting system.

Monthly Rate Secondary Power Supply Charge

This rate is subject to the Power Supply Cost Recovery (PSCR) Factor shown on Sheet No. D-4.00. (Continued on Sheet No. D-47.00)

Energy Charge:


$0.051003 $0.000000 $0.051003 per kWh for all kWh



GENERAL SERVICE METERED LIGHTING RATE GML (Continued From Sheet No. D-46.00)

Monthly Rate (Contd) Secondary Delivery Charge System Access Charge: $10.00 per customer per month Distribution Charge: $0.065287 per kWh for all kWh This rate is subject to the Surcharges shown on Sheet Nos. D-2.00 through D-3.10 and the Power Plant Securitization

Charges shown on Sheet No. D-5.10. Primary Power Supply Charge

This rate is subject to the Power Supply Cost Recovery (PSCR) Factor shown on Sheet No. D-4.00. Primary Delivery Charge System Access Charge: $20.00 per customer per month Distribution Charge: $0.049394 per kWh for all kWh This rate is subject to the Surcharges shown on Sheet Nos. D-2.00 through D-3.10 and the Power Plant Securitization

Charges shown on Sheet No. D-5.10. Net Metering Program The Net Metering Program is available to any eligible customer as described in Rule C11., Net Metering Program, who

desires to generate a portion or all of their own retail electricity requirements using a Renewable Energy Resource as defined in Rule C11.B, Net Metering Program.

A customer who participates in the Net Metering Program is subject to the provisions contained in Rule C11., Net

Metering Program. Green Generation Program Customer contracts for participation in the Green Generation Program shall be available to any eligible customer as

described in Rule C10.2, Green Generation Program. A customer who participates in the Green Generation Program is subject to the provisions contained in Rule C10.2,

Green Generation Program. (Continued on Sheet No. D-48.00)

Energy Charge:





GENERAL SERVICE UNMETERED LIGHTING RATE GUL (Continued From Sheet No. D-50.10)

Monthly Rate The charge per luminaire per month shall be:

Nominal Rating of Lamps (One Lamp per Luminaire) (1)

Type of Luminaire Watts

Watts Including Ballast (2) Lumens

Service Charge per Luminaire (4) Fixture Charge

per Luminaire (4) Non Capacity Capacity Total

Mercury Vapor (3) 100 128 3,500 $ 7.76 $0.00 $ 7.76 $6.00 Mercury Vapor (3) 175 209 7,500 12.67 0.00 12.67 $6.00 Mercury Vapor (3) 250 281 10,000 17.03 0.00 17.03 $6.00 Mercury Vapor (3) 400 458 20,000 27.76 0.00 27.76 $6.00 Mercury Vapor (3) 700 770 35,000 46.67 0.00 46.67 $6.00 Mercury Vapor (3) 1,000 1,080 50,000 65.45 0.00 65.45 $6.00

High-Pressure Sodium (3) 70 83 5,000 5.03 0.00 5.03 $6.00

High-Pressure Sodium 100 117 8,500 7.09 0.00 7.09 $6.00 High-Pressure Sodium 150 171 14,000 10.36 0.00 10.36 $6.00 High-Pressure Sodium (3) 200 247 20,000 14.97 0.00 14.97 $6.00 High-Pressure Sodium 250 318 24,000 19.27 0.00 19.27 $6.00 High-Pressure Sodium 400 480 45,000 29.09 0.00 29.09 $6.00

Fluorescent (3) 380 470 20,000 28.48 0.00 28.48 $6.00

Incandescent (3) 202 202 2,500 12.24 0.00 12.24 $6.00 Incandescent (3) 305 305 4,000 18.48 0.00 18.48 $6.00 Incandescent (3) 405 405 6,000 24.55 0.00 24.55 $6.00 Incandescent (3) 690 690 10,000 41.82 0.00 41.82 $6.00

Metal Halide 150 170 9,750 10.30 0.00 10.30 $6.00 Metal Halide (3) 175 210 10,500 12.73 0.00 12.73 $6.00 Metal Halide 250 290 15,500 17.58 0.00 17.58 $6.00 Metal Halide 400 460 24,000 27.88 0.00 27.88 $6.00 (1) Ratings for fluorescent lighting apply to all lamps in one luminaire. (2) Watts including ballast used for monthly billing of the Power Supply Cost Recovery (PSCR) Factor, Securitization and

Securitization Tax Charges, Power Plant Securitization Charges and surcharges. (3) Rates apply to existing luminaires only and are not open to new business. (4) For customers who own their lighting fixtures and are assessed a Service Charge (but not a Fixture Charge), the charge per

luminaire represents a 29.5% Power Supply Charge and a 70.5% Distribution Charge. For customers who do not own their lighting fixtures and are assessed both a Service Charge and a Fixture Charge, the charge per luminaire represents a

17.9% Power Supply Charge and a 82.1% Distribution Charge. For energy conservation purposes, customers may, at their option, elect to have any or all luminaires served under this rate

disconnected for a period of six months or more. The charge per luminaire per month, for each disconnected luminaire, shall be 40% of the monthly rate set forth above. However, should any such disconnected luminaire be reconnected at the customer's request after having been disconnected for less than six months, the monthly rate set forth above shall apply to the period of disconnection. An $8.00 per luminaire disconnect/reconnect charge shall be made at the time of disconnection except that when the estimated disconnect/reconnect cost is significantly higher than $8.00, the estimated cost per luminaire shall be charged.

For 24-hour mercury-vapor service, the charge per luminaire shall be 125% of the foregoing rates. (Continued on Sheet No. D-52.00)



GENERAL UNMETERED EXPERIMENTAL LIGHTING RATE GU-XL (Continued From Sheet No. D-54.01)

Facilities Policy (Contd)

Company-Owned Option (Contd)

D. The Company will determine the type and size of all experimental lighting fixtures to be offered under this rate. The list of approved fixtures is subject to modification at the sole discretion of the Company to accommodate new product development and advances in technology. Upon customer request, the Company shall provide a list of experimental lighting available under this rate.

E. The Company shall determine all associated equipment necessary to provide service under the Company-Owned Unmetered Experimental Lighting option.

F. Any charges, deposits or contributions may be required in advance of commencement of construction.

G. At the Company’s discretion, any failed lighting fixtures may be converted to an equivalent LED at no cost to the customer if the customer agrees to the conversion. The replaced fixture will then be moved to General Unmetered Experimental Lighting Rate GU-XL upon completion of the installation.

Customer-Owned Option

If it is necessary for the Company to install distribution facilities to serve a customer-owned system, contributions and/or deposits for such additional facilities shall be calculated in accordance with the Company’s general service line extension policy. Any charges, deposits or contributions may be required in advance of commencement of construction.

Monthly Rate Power Supply Charges

This rate is subject to the Power Supply Cost Recovery (PSCR) Factor shown on Sheet No. D-4.00. Delivery Charges Customer-Owned Option

Distribution Charge: $ 0.026842 per kWh for all kWh Delivery Charges Company-Owned Option

Distribution Charge: $ 0.032923 per kWh for all kWh Fixture Charge per Luminaire: $6.00 per month This rate is subject to the Surcharges shown on Sheet Nos. D-2.00 through D-3.10 and the Power Plant Securitization Charges shown on Sheet No. D-5.10.

General Terms:

This rate is subject to all general terms and conditions shown on Sheet No. D-1.00.

Due Date and Late Payment Charge:

The due date of the customer bill shall be 21 days from the date of mailing. A late payment charge of 2% of the unpaid balance, net of taxes, shall be assessed to any bill which is not paid on or before the due date shown thereon.

Determination of Monthly Kilowatt-Hours and Burning Hours per Month Based on 4,200 Burning Hours per Year:

The monthly kilowatt-hours shall be determined by multiplying the total capacity requirements in watts (including the lamps, ballasts, drivers, and control devices) times the monthly Burning Hours as defined below divided by 1,000. The customer shall not change the capacity requirements of the equipment owned by it without first notifying the Company in writing of such changes and the date that they shall be made, and modifying the lighting contract with the Company accordingly.

Jan Feb Mar April May June July Aug Sept Oct Nov Dec Total 457.8 382.2 369.6 306.6 264.6 226.8 252.0 298.2 336.0 399.0 432.6 474.6 4,200

Hours of Lighting:

Unmetered Experimental Lighting shall be burning at all times when the natural general level of illumination is lower than about 3/4 footcandle, and under normal conditions this is approximately one-half hour after sunset until approximately one-half hour before sunrise. Lighting service will be supplied from dusk to dawn every night and all night on an operating schedule of approximately 4,200 hours per year.


Energy Charge:





GENERAL SERVICE UNMETERED RATE GU Availability:

Subject to any restrictions, this rate is available to the US Government, any political subdivision or agency of the State of Michigan, and any public or private school district for filament and/or gaseous discharge lamp installations maintained for traffic regulation or guidance, as distinguished from street illumination and police signal systems. Lighting for traffic regulation may use experimental lighting technology including light-emitting diode (LED). This rate is also available to Community Antenna Television Service Companies (CATV), Wireless Access Companies or Security Camera Companies for unmetered Power Supply Units. Where the Company's total investment to serve an individual location exceeds three times the annual revenue to be derived from such location, a contribution to the Company shall be required for the excess. This rate is not available for resale purposes, new roadway lighting or for Retail Open Access Service.

Nature of Service:

Customer furnishes and installs all fixtures, lamps, ballasts, controls, amplifiers and other equipment, including wiring to point of connection with Company's overhead or underground system, as directed by the Company. Company furnishes and installs, where required for center suspended overhead traffic light signals, messenger cable and supporting wood poles and also makes final connections to its lines. If, in the Company's opinion, the installation of wood poles for traffic lights is not practical, the customer shall furnish, install and maintain suitable supports other than wood poles. The customer shall maintain the equipment, including lamp renewals, and the Company shall supply the energy for the operation of the equipment. Conversion and/or relocation costs of existing facilities shall be paid for by the customer except when initiated by the Company.

The capacity requirements of the lamp(s), associated ballast(s) and control equipment for each luminaire shall be determined by the Company from the specifications furnished by the manufacturers of such equipment, provided that the Company shall have the right to test such capacity requirements from time to time. In the event that said tests shall show capacity requirements different from those indicated by the manufacturers' specifications, the capacity requirements shown by said tests shall control. The customer shall not change the capacity requirements of the equipment owned by it without first notifying the Company in writing of such changes and the date that they shall be made.

Monthly Rate: Power Supply Charges:


Delivery Charges: System Access Charge: $2.00 per customer per month Distribution Charge: $0.017046 per kWh for all kWh This rate is subject to the Surcharges shown on Sheet Nos. D-2.00 through D-3.10 and the Power Plant

Securitization Charges shown on Sheet No. D-5.10. (Continued on Sheet No. D-55.00)

Energy Charge:




ATTACHMENT B

MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-18322Schedule F-2 Rehearing Rate Design

Consumers Energy Company Attachment BSummary of Present and Proposed Revenues by Rate Schedule Page 1 of 30

Total Revenues

( a ) ( b ) ( c ) ( d ) ( e )Line Present ProposedNo. Sales Revenue Revenue Revenue Percent

MWh $000 $000 $000 %

Bundled ServiceResidential Class

1 Residential Service RS 12,053,207 1,885,690$ 1,933,569$ 47,879$ 2.5 2 Residential Time-of-Day RT 55,778 7,508 7,787 279 3.7 3 Residential Electric Vehicle REV 10,001 1,448 1,484 36 2.5 4 Res. Dynamic Price RSDP - - - - NA5 Res. Dynamic Price Rebate RSDPR - - - - NA6 Total Residential Class 12,118,986 1,894,646 1,942,840 48,194 2.5

Secondary Class7 Secondary Energy-only GS 3,602,549 539,921 548,216 8,295 1.5 8 Sec. Energy Dynamic Price GSDP - - - - NA9 Secondary Demand GSD 3,551,171 461,254 490,770 29,516 6.4 10 Secondary Energy-only GS TOU - - - - NA11 Total Secondary Class 7,153,720 1,001,175 1,038,986 37,811 3.8

Primary Class12 Primary Energy-only GP 1,356,398 156,743 160,750 4,007 2.6 13 Primary Demand GPD 11,497,488 968,432 951,903 (16,529) (1.7) 14 Primary Energy Intensive Rate EIP 255,121 16,719 16,441 (278) (1.7) 15 Primary Time of Use Pilot GPTU 303,937 29,609 29,123 (487) (1.6) 16 Total Primary Class 13,412,943 1,171,503 1,158,217 (13,286) (1.1)

Lighting & Unmetered Class17 Metered Lighting Service GML 18,204 2,024 2,159 136 6.7 18 Unmetered Lighting Service GUL 123,389 29,750 31,647 1,897 6.4 19 Unmetered Exp. Lighting GU-XL 14 2 1,427 1,425 NA20 Unmetered Service GU 85,150 7,729 7,990 262 3.4 21 Total Lighting & Unmetered Class 226,757 39,504 43,223 3,719 9.4

Self-generation Class22 Small Self-generation GSG-1 27,481 - - - NA23 Large Self-generation GSG-2 33,144 5,047 1,783 (3,264) NA24 Total Self-Generation Class 60,624 5,047 1,783 (3,264) NA

25 Total Bundled Service 32,973,030 4,111,875$ 4,185,049$ 73,173$ 1.8

ROA ServiceResidential Class

26 Residential Service RS - -$ -$ -$ NA27 Residential Time-of-Day RT - - - - NA28 Total Residential Class - - - - NA

Secondary Class29 Secondary Energy-only GS 23,636 1,015 1,030 15 1.5 30 Secondary Demand GSD 213,651 6,998 8,104 1,106 15.8 31 Total Secondary Class 237,287 8,014 9,135 1,121 14.0

Primary Class32 Primary Energy-only GP 67,215 1,315 1,176 (139) (10.6) 33 Primary Demand GPD 3,855,694 24,325 21,099 (3,226) (13.3) 34 Total Primary Class 3,922,909 25,640 22,275 (3,365) (13.1)

35 Total ROA Service 4,160,196 33,654$ 31,410$ (2,245)$ (6.7)

36 Total Bundled and ROA Service 37,133,226 4,145,529$ 4,216,458$ 70,929$ 1.7

DifferenceDescription

MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-18322Rehearing Rate Design


Power Supply Revenues


MWh $000 $000 $000 %


1 Residential Service RS 12,053,207 1,203,479$ 1,211,954$ 8,475$ 0.7 2 Residential Time-of-Day RT 55,778 4,732 4,827 95 2.0 3 Residential Electric Vehicle REV 10,001 909 912 3 0.3 4 Res. Dynamic Price RSDP - - - - NA5 Res. Dynamic Price Rebate RSDPR - - - - NA6 Total Residential Class 12,118,986 1,209,120 1,217,693 8,573 0.7

Secondary Class7 Secondary Energy-only GS 3,602,549 341,944 348,034 6,090 1.8 8 Sec. Energy Dynamic Price GSDP - - - - NA9 Secondary Demand GSD 3,551,171 335,092 346,225 11,133 3.3 10 Sec. Demand Dynamic Price GSDDP - - - - NA11 Total Secondary Class 7,153,720 677,037 694,259 17,223 2.5

Primary Class12 Primary Energy-only GP 1,356,398 129,128 135,925 6,797 5.3 13 Primary Demand GPD 11,497,488 884,469 879,282 (5,187) (0.6) 14 Primary Energy Intensive Rate EIP 255,121 14,653 14,674 21 0.1 15 Primary Time of Use Pilot GPTU 303,937 25,478 25,563 85 0.3 16 Total Primary Class 13,412,943 1,053,728 1,055,444 1,716 0.2

Lighting & Unmetered Class17 Metered Lighting Service GML 18,204 982 948 (33) (3.4) 18 Unmetered Lighting Service GUL 123,403 6,485 5,620 (865) (13.3) 19 Unmetered Exp. Lighting GU-XL 14 1 274 273 36,817.3 20 Unmetered Service GU 85,150 6,443 6,528 85 1.3 21 Total Lighting & Unmetered Class 226,771 13,911 13,370 (540) (3.9)

Self-generation Class22 Small Self-generation GSG-1 - - - - NA23 Large Self-generation GSG-2 33,144 2,982 - (2,982) (100.0) 24 Total Self-Generation Class 33,144 2,982 - (2,982) (100.0)




Secondary Class29 Secondary Energy-only GS 23,636 - - - NA30 Secondary Demand GSD 213,651 - - - NA31 Total Secondary Class 237,287 - - - NA

Primary Class32 Primary Energy-only GP 67,215 - - - NA33 Primary Demand GPD 3,855,694 - - - NA34 Total Primary Class 3,922,909 - - - NA

35 Total ROA Service 4,160,196 -$ -$ -$ NA



MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-18322 Rehearing Rate Design


Delivery Revenues


MWh $000 $000 $000 %


1 Residential Service RS 12,053,207 682,210$ 721,614$ 39,404$ 5.8 2 Residential Time-of-Day RT 55,778 2,777 2,960 184 6.6 3 Residential Electric Vehicle REV 10,001 539 572 33 6.1 4 Res. Dynamic Price RSDP - - - - NA5 Res. Dynamic Price Rebate RSDPR - - - - NA6 Total Residential Class 12,118,986 685,526$ 725,146 39,620 5.8

Secondary Class7 Secondary Energy-only GS 3,602,549 197,977 200,182 2,205 1.1 8 Sec. Energy Dynamic Price GSDP - - - - NA9 Secondary Demand GSD 3,551,171 126,162 144,545 18,384 14.6 10 Sec. Demand Dynamic Price GSDDP - - - - NA11 Total Secondary Class 7,153,720 324,139 344,727 20,588 6.4

Primary Class12 Primary Energy-only GP 1,356,398 27,615 24,825 (2,790) (10.1) 13 Primary Demand GPD 11,497,488 83,963 72,621 (11,342) (13.5) 14 Primary Energy Intensive Rate EIP 255,121 2,066 1,767 (299) (14.5) 15 Primary Time of Use Pilot GPTU 303,937 4,131 3,559 (572) (13.8) 16 Total Primary Class 13,412,943 117,775 102,773 (15,002) (12.7)

Lighting & Unmetered Class17 Metered Lighting Service GML 18,204 1,042 1,211 169 16.2 18 Unmetered Lighting Service GUL 123,389 23,264 26,027 2,762 11.9 19 Unmetered Exp. Lighting GU-XL 14 1 1,153 1,152 86,383.0 20 Unmetered Service GU 85,150 1,286 1,462 176 13.7 21 Total Lighting & Unmetered Class 226,757 25,593 29,853 4,260 16.6

Self-generation Class22 Small Self-generation GSG-1 - - - - NA23 Large Self-generation GSG-2 33,144 2,065 1,783 (282) (13.7) 24 Total Self-Generation Class 33,144 2,065 1,783 (282) (13.7)




Secondary Class29 Secondary Energy-only GS 23,636 1,015 1,030 15 1.5 30 Secondary Demand GSD 213,651 6,998 8,104 1,106 15.8 31 Total Secondary Class 237,287 8,014 9,135 1,121 14.0

Primary Class32 Primary Energy-only GP 67,215 1,315 1,176 (139) (10.6) 33 Primary Demand GPD 3,855,694 24,325 21,099 (3,226) (13.3) 34 Total Primary Class 3,922,909 25,640 22,275 (3,365) (13.1)

35 Total ROA Service 4,160,196 33,654$ 31,410$ (2,245)$ (6.7)



MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-18322Schedule F-2.1 Rehearing Rate Design

Consumers Energy Company Attachment BTest-Year Calculation of Rate Design Targets Page 4 of 30 ($000)

( a ) ( b ) ( c ) ( d ) ( e) ( f ) ( g ) ( h ) ( j ) ( k ) ( l ) ( m ) ( n )Line

No. Jurisdictional RS RT GS GS GEI GSD GSD GEI GP GP GEI GPD (3) GPD GEI EIP GML GUL GU-XL GU GSG-1 GSG-2

Cost-of-Service StudyPower Supply (1)

1 Capacity 933,251$ 415,886$ 1,337$ 110,829$ 2,742$ 108,461$ 6,326$ 50,070$ 4,821$ 216,486$ 9,940$ 4,800$ -$ -$ -$ 1,552$ -$ -$ 2 COSS Capacity 933,251 410,571 1,317 109,125 2,700 106,794 6,229 33,054 4,747 247,326 9,787 - - - - 1,528 - 73 3 Interruptible - 7,394 27 2,257 56 2,209 129 684 98 (13,087) 202 - - - - 32 - - 4 EIP Capacity - (2,112) (7) (561) (14) (549) (32) (170) (24) (1,272) (50) 4,800 - - - (8) 5 Interclass Cross Pt Adj - 16,500 (16,500) 6 Self-Generation - 32 0 9 0 8 0 3 0 19 1 - - - - 0 - (73) 7 Energy 1,974,386 770,080 3,365 221,012 5,417 211,269 12,249 67,553 10,456 631,979 20,123 9,305 908 5,620 264 4,786 - - 8 COSS Energy 1,974,386 769,640 3,363 220,885 5,413 211,148 12,242 67,514 10,450 631,618 20,111 9,300 907 5,617 264 4,784 - 1,128 9 Self-Generation - 440 2 126 3 121 7 39 6 361 11 5 1 3 0 3 - (1,128)

10 Total Power Supply 2,907,637 1,185,966 4,703 331,841 8,159 319,731 18,575 117,623 15,277 848,465 30,063 14,105 908 5,620 264 6,338 - - Delivery

11 Distribution 1,039,315 586,550 2,227 159,110 6,111 128,127 15,488 18,485 4,037 80,164 7,808 586 1,186 25,241 1,150 1,433 - 1,613 12 Customer 196,135 146,340 395 33,124 298 6,419 289 2,454 273 5,458 408 67 24 531 4 29 - 23 13 Total Delivery 1,235,450 732,890 2,622 192,234 6,410 134,546 15,777 20,938 4,309 85,622 8,215 652 1,211 25,771 1,153 1,462 - 1,637

14 Total Cost-of-Service 4,143,088$ 1,918,856$ 7,325$ 524,075$ 14,568$ 454,277$ 34,353$ 138,561$ 19,587$ 934,087$ 38,278$ 14,758$ 2,119$ 31,391$ 1,417$ 7,801$ -$ 1,637$

Skewing and Discounts (2)15 Senior Citizen (5) (8,221) 1 2,037 1,848 598 3,677 56 - - - - - - 16 Income Assistance (1) (2,143) 4 530 481 156 957 15 - - - - - - 17 Total Skewing and Discounts (6) (10,364) 5 2,567 2,328 754 4,633 70 - - - - - -

18 Total Rate Design Target 4,143,082$ 1,908,492$ 7,330$ 526,641$ 14,568$ 456,605$ 34,353$ 139,315$ 19,587$ 938,720$ 38,278$ 14,828$ 2,119$ 31,391$ 1,417$ 7,801$ -$ 1,637$ 541,210$ 490,958$ 158,902$ 976,998$ 978,635$

Notes(1) Capacity and energy costs adjusted to capture elements occurring outside the Cost-of-Service Study.(2) Skewing and Discount Allocation Factors

Jurisdictional RS RT GS GSD GP GPD MMPP GML GUL GU-XL GU GSG-1 GSG-20.9998 - - 0.1995 0.1985 0.0780 0.5155 0.0083 - - - - - -

0.9997 0.4680 0.0018 0.1314 0.1192 0.0386 0.2372 0.0036 - - - - - -

(3) Voltage Levels combined when entering from COSS.

Self Gen. Class

Description

Lighting & Unmetered ClassResidential Class Secondary Class Primary Class

MICHIGAN PUBLIC SERVICE COMMISSION Case No.: U-18322Schedule F-3 Rehearing Rate Design

Consumers Energy Company Attachment BTest-Year Present and Proposed Revenue Detail Page 5 of 30

Residential Service RS

( a ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i )LineNo. Quantity Units Rates Revenue Rates Revenue Revenue Percent

$/unit $000 $/unit $000 $000 %Bundled Service

Power SupplySummer (June - Sept.)

Non Capacity1 First 600 kWh/mth 2,879,840 MWh 0.093884 270,371$ 0.061459 176,992$ (93,379)$ (34.5) 2 Excess kWh/mth 1,402,214 MWh 0.126757 177,740 0.082726 116,000 (61,741) (34.7) 3 Capacity4 First 600 kWh/mth 2,879,840 MWh - 0.033144 95,450 95,450 NA5 Excess kWh/mth 1,402,214 MWh - 0.044613 62,557 62,557 NA6 Total Summer Power Supply 4,282,053 448,111 450,998 2,887 0.6

7 Peak Saver 140,000 Bills (7.84) (847) (7.84) (1,098) (251) (29.6) 8 Winter (Oct. - May)9 Non Capacity

10 All kWh/mth 7,771,153 MWh 0.093884 729,587 0.061459 477,607 (251,980) (34.5) 11 Capacity12 All kWh/mth 7,771,153 MWh - 0.033144 257,568 257,568 NA13 Annual PSCR Factor kWh/mth 12,053,207 MWh 0.002230 26,879 0.002230 26,879 - - 14 Total Power Supply 1,203,730$ 1,211,954$ 8,224$ 0.7

15 Delivery16 Distribution kWh/mth 12,053,207 MWh 0.047220 569,152$ 0.050510 608,807$ 39,655$ 7.0 17 Skewing (0.000855) 18 System Access 18,902,052 Bills 7.00 132,314 7.00 132,314 - - 19 Provisions20 Senior Citizen RSC 4,421,775 Bills (3.50) (15,476) (3.50) (15,476) - - 21 Income Assistance RIA 575,877 Bills (7.00) (4,031) (7.00) (4,031) - - 22 Total Delivery 681,959$ 721,614$ 39,655$ 5.8

23 ROA Service24 Delivery25 Distribution kWh/mth - MWh 0.047220 -$ 0.050510 -$ -$ NA26 System Access - Bills 7.00 - 7.00 - - NA27 Provisions28 Senior Citizen RSC - Bills (3.50) - (3.50) - - NA29 Income Assistance RIA - Bills (7.00) - (7.00) - - NA30 Total Delivery -$ -$ -$ NA

31 Total Residential RS 1,885,690$ 1,933,569$ 47,879$ 2.5

DifferenceBilling Determinants Present ProposedDescription



Residential Time-of-Day RT

( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h )LineNo. Quantity Units Rates Revenue Rates Revenue Revenue Percent



Non Capacity1 On-peak kWh/mth 4,088 MWh 0.111706 457$ 0.080976 331$ (126)$ (27.5) 2 Off-peak kWh/mth 13,694 MWh 0.075406 1,033 0.056108 768 (264) (25.6) 3 Capacity4 On-peak kWh/mth 4,088 MWh 0.032182 132$ 132$ NA5 Off-peak kWh/mth 13,694 MWh 0.022299 305 305 NA6 Total Summer Power Supply 17,782 1,489 1,536 47 3.2 7 Winter (Oct. - May)8 Non Capacity9 On-peak kWh/mth 8,318 MWh 0.091696 763 0.065314 543 (219) (28.8) 10 Off-peak kWh/mth 29,679 MWh 0.079368 2,356 0.058042 1,723 (633) (26.9) 11 Capacity12 On-peak kWh/mth 8,318 MWh 0.025958 216 216 NA13 Off-peak kWh/mth 29,679 MWh 0.023068 685 685 NA14 Total Winter Power Supply 37,996 3,118 3,166 48 1.5 15 Annual PSCR Factor kWh/mth 55,778 MWh 0.002230 124 0.002230 124 - - 16 Total Power Supply 4,732$ 4,827$ 95$ 2.0

17 Delivery18 Distribution kWh/mth 55,778 MWh 0.047220 2,634$ 0.050510 2,817$ 184$ 7.0 19 System Access 24,672 Bills 7.00 173 7.00 173 - - 20 Provisions21 Senior Citizen RSC 7,644 Bills (3.50) (27) (3.50) (27) - - 22 Income Assistance RIA 468 Bills (7.00) (3) (7.00) (3) - - 23 Total Delivery 2,777$ 2,960$ 184$ 6.6

24 ROA Service25 Delivery26 Distribution kWh/mth - MWh 0.047220 -$ 0.050510 -$ -$ NA27 System Access - Bills 7.00 - 7.00 - - NA28 Provisions29 Senior Citizen RSC - Bills (3.50) - (3.50) - - NA30 Income Assistance RIA - Bills (7.00) - (7.00) - - NA31 Total Delivery -$ -$ -$ NA

32 Total Residential RT 7,508$ 7,787$ 279$ 3.7

Billing Determinants Present Proposed DifferenceDescription



Residential Electric Vehicle REV-1 (Home & Vehicle)




Non Capacity1 On-peak kWh/mth 25 MWh 0.152931 4$ 0.095305 2$ (1)$ (37.7) 2 Mid-peak kWh/mth 816 MWh 0.112809 92 0.076120 62 (30) (32.5) 3 Off-peak kWh/mth 2,706 MWh 0.082808 224 0.054616 148 (76) (34.0) 4 Capacity5 On-peak kWh/mth 25 MWh -$ 0.051322 1$ 1$ NA6 Mid-peak kWh/mth 816 MWh - 0.040991 33 33 NA7 Off-peak kWh/mth 2,706 MWh - 0.029411 80 80 NA8 Total Summer Power Supply 3,547 320 327 (108) (33.7) 9 Winter (Oct. - May)10 Non Capacity11 On-peak kWh/mth 1,518 MWh 0.103071 156 0.062963 96 (61) (38.9) 12 Off-peak kWh/mth 4,806 MWh 0.082808 398 0.054616 263 (135) (34.0) 13 Capacity14 On-peak kWh/mth 1,518 MWh - 0.033906 51 51 NA15 Off-peak kWh/mth 4,806 MWh - 0.029411 141 141 NA16 Total Winter Power Supply 6,324 554 551 (196) (35.4) 17 Annual PSCR Factor kWh/mth 9,871 MWh 0.002230 22 0.002230 22 - - 18 Total Power Supply 896$ 899$ 3$ 0.3

19 Delivery20 Distribution kWh/mth 9,871 MWh 0.047220 466$ 0.050510 499$ 32$ 7.0 21 System Access 9,540 Bills 7.00 67 7.00 67 - - 22 Total Delivery 533$ 565$ 32$ 6.1

23 Total Residential REV-1 1,429$ 1,465$ 36$ 2.5




Residential Electric Vehicle REV-2 (Vehicle Only Time-of-Day)




Non Capacity1 On-peak kWh/mth 8 MWh 0.152931 1$ 0.095305 1$ (0)$ (37.7) 2 Mid-peak kWh/mth 11 MWh 0.112809 1 0.076120 1 (0) (32.5) 3 Off-peak kWh/mth 61 MWh 0.082808 5 0.054616 3 (2) (34.0) 4 Capacity5 On-peak kWh/mth 8 MWh -$ 0.051322 0$ 0$ NA6 Mid-peak kWh/mth 11 MWh - 0.040991 0 0 NA7 Off-peak kWh/mth 61 MWh - 0.029411 2 2 NA8 Total Summer Power Supply 81 8 8 0 1.0 9 Winter (Oct. - May)

10 Non Capacity11 On-peak kWh/mth 12 MWh 0.103071 1 0.062963 1 (0) (38.9) 12 Off-peak kWh/mth 38 MWh 0.082808 3 0.054616 2 (1) (34.0) 13 Capacity14 On-peak kWh/mth 12 MWh - 0.033906 0 0 NA15 Off-peak kWh/mth 38 MWh - 0.029411 1 1 NA16 Total Winter Power Supply 49 4 4 (0) (0.6) 17 Annual PSCR Factor kWh/mth 130 MWh 0.002230 0 0.002230 0 - - 18 Total Power Supply 12$ 12$ 0$ 0.4

19 Delivery20 Distribution kWh/mth 130 MWh 0.047220 6$ 0.050510 7$ 0$ 7.0

21 Total Residential REV-2 18$ 19$ 0$ 2.6




Residential Dynamic Pricing RDP




Non Capacity1 Off-peak kWh/mth - MWh 0.077645 -$ 0.041772 -$ -$ NA2 Mid-peak kWh/mth - MWh 0.105776 - 0.058218 - - NA3 On-peak kWh/mth - MWh 0.143396 - 0.072892 - - NA4 Critical-peak kWh/mth - MWh 0.950000 - 0.611119 - - NA5 Capacity6 Off-peak kWh/mth - MWh -$ 0.017709 -$ -$ NA7 Mid-peak kWh/mth - MWh - 0.024681 - - NA8 On-peak kWh/mth - MWh - 0.030902 - - NA9 Critical-peak kWh/mth - MWh - 0.338881 - - NA

10 Total Summer Power Supply - - - - NA11 Winter (Oct. - May)12 Non Capacity13 Off-peak kWh/mth MWh 0.077645 0.057140 - - NA14 On-peak kWh/mth MWh 0.096645 - 0.065872 - - NA15 Capacity16 Off-peak kWh/mth MWh 0.030815 16 On-peak kWh/mth MWh - 0.035524 - - NA17 Total Winter Power Supply - - - NA18 Annual PSCR Factor kWh/mth - MWh 0.002230 - 0.002230 - - NA19 Total Power Supply -$ -$ -$ NA

20 Delivery21 Distribution kWh/mth - MWh 0.047220 -$ 0.050510 -$ -$ NA22 System Access - Bills 7.00 - 7.00 - - NA23 Provisions24 Senior Citizen RSC - Bills (3.50) - (3.50) - - NA25 Income Assistance RIA - Bills (7.00) - (7.00) - - NA26 Total Delivery -$ -$ -$ NA

27 Total Residential RDP -$ -$ -$ NA




Residential Dynamic Pricing Rewards RDPR




Non Capacity1 Off-peak kWh/mth - MWh 0.082808 -$ 0.050506 -$ -$ NA2 Mid-peak kWh/mth - MWh 0.112809 - 0.070391 - - NA3 On-peak kWh/mth - MWh 0.152931 - 0.088134 - - NA4 Critical-peak kWh/mth - MWh (0.950000) - (0.611119) - - NA5 Capacity6 Off-peak kWh/mth - MWh -$ 0.027125 -$ -$ NA7 Mid-peak kWh/mth - MWh - 0.037804 - - NA8 On-peak kWh/mth - MWh - 0.047333 - - NA9 Critical-peak kWh/mth - MWh - (0.338881) - - NA10 Total Summer Power Supply - - - - NA11 Winter (Oct. - May)12 Non Capacity13 Off-peak kWh/mth MWh 0.082808 0.057140 - - NA14 On-peak kWh/mth MWh 0.103071 - 0.065872 - - NA15 Capacity16 Off-peak kWh/mth MWh 0.030815 17 On-peak kWh/mth MWh - 0.035524 - - NA18 Total Winter Power Supply - - - NA19 Annual PSCR Factor kWh/mth - MWh 0.002230 - 0.002230 - - NA20 Total Power Supply -$ -$ -$ NA

21 Delivery22 Distribution kWh/mth - MWh 0.047220 -$ 0.050510 -$ -$ NA23 System Access - Bills 7.00 - 7.00 - - NA24 Provisions25 Senior Citizen RSC - Bills (3.50) - (3.50) - - NA26 Income Assistance RIA - Bills (7.00) - (7.00) - - NA27 Total Delivery -$ -$ -$ NA

28 Total Residential RDPR -$ -$ -$ NA




Secondary Energy-only GS




Non Capacity1 All kWh/mth 1,304,437 MWh 0.093995 122,611$ 0.064518 84,160$ (38,451)$ (31.4) 2 Capacity3 All kWh/mth 1,304,437 MWh 0.032361 42,213$ 42,213$ NA4 Provisions5 Education GEI 21,494 MWh - - - - NA6 Total Summer Power Supply 122,611 126,373 3,762 3.1 7 Winter (Oct. - May)8 Non Capacity9 All kWh/mth 2,298,112 MWh 0.091945 211,300 0.061907 142,269 (69,031) (32.7)

10 Capacity11 All kWh/mth 2,298,112 MWh 0.031051 71,359 71,359 NA12 Provisions13 Education GEI 61,038 MWh - - - - NA14 Total Winter Power Supply 211,300 213,628 2,328 1.1

- 15 Annual PSCR Factor kWh/mth 3,602,549 MWh 0.002230 8,034 0.002230 8,034 - - 16 Total Power Supply 341,944$ 348,034$ 6,090$ 1.8 1718 Delivery19 Distribution kWh/mth 3,602,549 MWh 0.042154 151,862$ 0.042765 154,063$ 2,201$ 1.4 20 Skewing 0.000708 21 System Access 2,308,850 Bills 20.00 46,177 20.00 46,177 - - 22 Provisions23 Education GEI 82,531 MWh (0.000751) (62) (0.000708) (58) 4 5.7 24 Total Delivery 197,977$ 200,182$ 2,205 1.1

25 ROA Service26 Delivery27 Distribution kWh/mth 23,636 MWh 0.042154 996$ 0.042765 1,011$ 14$ 1.4 28 System Access 1,500 Bills 20.00 30 20.00 30 - - 29 Provisions30 Education GEI 14,577 MWh (0.000751) (11) (0.000708) (10) 1 5.7

31 Total Delivery 1,015$ 1,030$ 15$ 1.5

32 Total Secondary GS 540,936$ 549,246$ 8,310$ 1.5




Secondary Time of Use GSTU




Non Capacity1 Off-peak kWh/mth - MWh 0.084091 -$ 0.059509 -$ -$ NA2 Mid-peak kWh/mth - MWh 0.120119 - 0.090026 - - NA3 On-peak kWh/mth - MWh 0.162840 - 0.112717 - - NA4 Capacity5 Off-peak kWh/mth - MWh -$ 0.029848 -$ -$ NA6 Mid-peak kWh/mth - MWh - 0.045155 - - NA7 On-peak kWh/mth - MWh - 0.056536 - - NA8 Provisions9 Education GEI - MWh - - - - NA10 Total Summer Power Supply - - - - NA11 Winter (Oct. - May)12 Non Capacity13 Off-peak kWh/mth - MWh 0.076648 - 0.050823 - - NA14 On-peak kWh/mth - MWh 0.088553 - 0.057191 - - NA15 Capacity16 Off-peak kWh/mth - MWh - 0.025492 - - NA17 On-peak kWh/mth - MWh 0.028686 18 Provisions19 Education GEI - MWh - - - - NA20 Total Winter Power Supply - - - NA

21 Annual PSCR Factor kWh/mth - MWh 0.002230 - 0.002230 - - NA

22 Total Power Supply -$ -$ -$ NA

23 Delivery24 Distribution kWh/mth - MWh 0.042154 -$ 0.042765 -$ -$ NA25 Skewing 0.000708 26 System Access - Bills 20.00 - 20.00 - - NA27 Provisions28 Education GEI - MWh (0.000751) - (0.000708) - - NA29 Total Delivery -$ -$ -$ NA

30 Total GSTU -$ -$ -$ NA




Secondary Demand GSD




Non Capacity1 Peak kW/mth 3,753 MW 10.00 37,529$ -$ (37,529)$ (100.0) 2 All kWh/mth 1,242,626 MWh 0.067209 83,516 0.066286 82,369 (1,147) (1.4) 3 Capacity4 Peak kW/mth 3,753 MW - -$ 12.30 46,160$ 46,160$ NA5 All kWh/mth 1,242,626 MWh - - - - NA6 Provisions7 Education GEI 55,557 MWh - - - - NA8 Total Summer Power Supply 121,045 128,529 7,484 6.2 9 Winter (Oct. - May)

10 Non Capacity11 Peak kW/mth 6,663 MW 8.00 53,304 - (53,304) (100.0) 12 All kWh/mth 2,308,544 MWh 0.065743 151,771 0.061142 141,149 (10,622) (7.0) 13 Capacity14 Peak kW/mth 6,663 MW - - 10.30 68,628 68,628 NA15 All kWh/mth 2,308,544 MWh - - - - NA16 Provisions17 Education GEI 133,140 MWh - - - - NA18 Total Winter Power Supply 205,074 209,777 4,702 2.3 19 Annual PSCR Factor kWh/mth 3,551,171 MWh 0.002230 7,919 0.002230 7,919 - - 20 Annual Power Factor Adjustment 1,054 - (1,054) (100.0) 21 Total Power Supply 335,092$ 346,225$ 11,133$ 3.3

22 Delivery23 Peak kW/mth 10,416 MW 1.15 11,978$ 1.15 11,978$ -$ - 24 Distribution kWh/mth 3,551,171 MWh 0.030042 106,684 0.035219 125,069 18,384 17.2 25 Skewing 0.000618 26 System Access 249,276 Bills 30.00 7,478 30.00 7,478 - - 27 Provisions28 Education GEI 188,697 MWh (0.000614) (116) (0.000618) (117) (1) (0.7) 29 Annual Power Factor Adjustment 137 137 - - 30 Total Delivery 126,162$ 144,545$ 18,384 14.6

31 ROA Service32 Delivery33 Peak kW/mth 379 MW 1.15 436$ 1.15 436$ -$ - 34 Distribution kWh/mth 213,651 MWh 0.030042 6,419 0.035219 7,525 1,106 17.2 35 System Access 6,156 Bills 30.00 185 30.00 185 - - 36 Provisions37 Education GEI 66,756 MWh (0.000614) (41)$ (0.000618) (41) (0) (0.7) 38 Total Delivery 6,998$ 8,104$ 1,106$ 15.8

39 Total Secondary GSD 468,252$ 498,875$ 30,622$ 6.5




Primary Energy-only GP (Voltage Level 1)




Non Capacity1 All kWh/mth 6,762 MWh 0.090996 615$ 0.051574 349$ (267)$ (43.3) 2 Capacity3 All kWh/mth 6,762 MWh -$ 0.034071 230$ 230$ NA4 Provisions5 Education GEI - MWh - - - - NA6 Total Summer Power Supply 615 579 (36) (5.9) 7 Winter (Oct. - May)8 Non Capacity9 All kWh/mth 9,958 MWh 0.089011 886 0.049487 493 (394) (44.4) 10 Capacity11 All kWh/mth 9,958 MWh - 0.032692 326 326 NA12 Provisions13 Education GEI - MWh - - - - NA14 Total Winter Power Supply 886 818 (68) (7.7) 15 Annual PSCR Factor kWh/mth 16,720 MWh 0.002230 37 0.002230 37 - - 16 Total Power Supply 1,539$ 1,435$ (104)$ (6.8)

17 Delivery18 Distribution kWh/mth 16,720 MWh 0.009347 156$ 0.007882 132$ (24)$ (15.7) 19 Skewing 0.000530 20 Substation Ownership 22,480 MWh (0.000467) (10) (0.000394) (9) 2 15.6 21 System Access 101 Bills 100.00 10 100.00 10 - - 22 Provisions23 Education GEI - MWh (0.000557) - (0.000530) - - NA24 Total Delivery 156$ 133$ (23) (14.7)

25 ROA Service26 Delivery27 Distribution kWh/mth - MWh 0.009347 -$ 0.007882 -$ -$ NA28 Substation Ownership - MWh (0.000467) - (0.000394) - - NA29 System Access - Bills 100.00 - 100.00 - - NA30 Provisions31 Education GEI - MWh (0.000557) - (0.000530) - - NA32 Total Delivery -$ -$ -$ NA

33 Total Primary GP (Voltage Level 1) 1,695$ 1,568$ (127)$ (7.5)








Non Capacity1 All kWh/mth 26,622 MWh 0.095996 2,556$ 0.053574 1,426$ (1,129)$ (44.2) 2 Capacity3 All kWh/mth 26,622 MWh -$ 0.036071 960$ 960$ NA4 Provisions5 Education GEI - MWh - - - - NA6 Total Summer Power Supply 2,556 2,387 (169) (6.6) 7 Winter (Oct. - May)8 Non Capacity9 All kWh/mth 48,126 MWh 0.094011 4,524 0.051487 2,478 (2,046) (45.2) 10 Capacity11 All kWh/mth 48,126 MWh - 0.034692 1,670 1,670 NA12 Provisions13 Education GEI - MWh - - - - NA14 Total Winter Power Supply 4,524 4,147 (377) (8.3) 15 Annual PSCR Factor kWh/mth 74,748 MWh 0.002230 167 0.002230 167 - - 16 Total Power Supply 7,247$ 6,701$ (546)$ (7.5)

17 Delivery18 Distribution kWh/mth 74,748 MWh 0.012222 914$ 0.010773 805$ (108)$ (11.9) 19 Substation Ownership 8,181 MWh (0.000467) (4) (0.000394) (3) 1 15.6 20 System Access 707 Bills 100.00 71 100.00 71 - - 21 Provisions22 Education GEI - MWh (0.000557) - (0.000530) - - NA23 Total Delivery 980$ 873$ (108) (11.0)

24 ROA Service25 Delivery26 Distribution kWh/mth 2,834 MWh 0.012222 35$ 0.010773 31$ (4)$ (11.9) 27 Substation Ownership - MWh (0.000467) - (0.000394) - - NA28 System Access 25 Bills 100.00 3 100.00 3 - - 29 Provisions30 Education GEI - MWh (0.000557) - (0.000530) - - NA31 Total Delivery 37$ 33$ (4)$ (11.1)

32 Total Primary GP (Voltage Level 2) 8,264$ 7,606$ (658)$ (8.0)








Non Capacity1 All kWh/mth 443,693 MWh 0.094196 41,794$ 0.059274 26,299$ (15,495)$ (37.1) 2 Capacity3 All kWh/mth 443,693 MWh - -$ 0.041771 18,534$ 18,534$ NA4 Provisions5 Education GEI 56,388 MWh - - - - NA6 Total Summer Power Supply 41,794 44,833 3,039 7.3 7 Winter (Oct. - May)8 Non Capacity9 All kWh/mth 821,236 MWh 0.092211 75,727 0.057187 46,964 (28,763) (38.0)

10 Capacity11 All kWh/mth 821,236 MWh - 0.040392 33,171 33,171 NA12 Provisions13 Education GEI 123,051 MWh - - - - NA14 Total Winter Power Supply 75,727 80,135 4,408 5.8 15 Annual PSCR Factor kWh/mth 1,264,930 MWh 0.002230 2,821 0.002230 2,821 - - 16 Total Power Supply 120,342$ 127,789$ 7,447$ 6.2

17 Delivery18 Distribution kWh/mth 1,264,930 MWh 0.019354 24,481$ 0.017248 21,818$ (2,664)$ (10.9) 19 System Access 20,972 Bills 100.00 2,097 100.00 2,097 - - 20 Provisions21 Education GEI 179,439 MWh (0.000557) (100) (0.000530) (95) 5 4.8 22 Total Delivery 26,479$ 23,820$ (2,659) (10.0)

23 ROA Service24 Delivery25 Distribution kWh/mth 64,381 MWh 0.019354 1,246$ 0.017248 1,110$ (136)$ (10.9) 26 System Access 424 Bills 100.00 42 100.00 42 - - 27 Provisions28 Education GEI 18,628 MWh (0.000557) (10) (0.000530) (10) 1 4.8 29 Total Delivery 1,278$ 1,143$ (135)$ (10.6)

30 Total Primary GP (Voltage Level 3) 148,099$ 152,752$ 4,653$ 3.1




Primary Demand GPD (Voltage Level 1)




Non Capacity1 On-peak kW/mth 2,327 MW 20.24 47,104$ 9.58 22,297$ (24,807)$ (52.7) 2 On-peak kWh/mth 420,097 MWh 0.048966 20,570 0.046271 19,438 (1,132) (5.5) 3 Off-peak kWh/mth 1,155,581 MWh 0.031098 35,936 0.030370 35,095 (841) (2.3) 4 Capacity5 On-peak kW/mth 2,327 MW - -$ 10.66 24,807$ 24,807$ NA6 Provisions7 Interruptible GI 201 MW (7.00) (1,407) (7.00) (1,407) - - 8 Education GEI 3,145 MWh - - - - NA9 Total Summer Power Supply 102,204 100,231 (1,973) (1.9)

10 Winter (Oct. - May)11 Non Capacity12 On-peak kW/mth 4,510 MW 19.24 86,775 9.58 43,211 (43,565) (50.2) 13 On-peak kWh/mth 804,835 MWh 0.039207 31,555 0.036318 29,230 (2,325) (7.4) 14 Off-peak kWh/mth 2,200,294 MWh 0.033935 74,667 0.032274 71,013 (3,654) (4.9) 15 Capacity16 On-peak kW/mth 4,510 MW - - 9.66 43,565 43,565 NA17 Provisions18 Interruptible GI 402 MW (6.00) (2,410) (6.00) (2,410) - - 19 Education GEI 5,847 MWh - - - NA20 Total Winter Power Supply 190,587 184,608 (5,979) (3.1) 21 Annual PSCR Factor kWh/mth 4,580,806 MWh 0.002230 10,215 0.002230 10,215 - - 22 Annual Power Factor Adjustment (782) (760) 21 2.7 23 Total Power Supply 302,225$ 294,294$ (7,931)$ (2.6)

24 Delivery25 Maximum kW/mth 7,930 7,930 MW 1.14 9,041$ 0.96 7,591 (1,450)$ (16.0) 26 Distribution kWh/mth 4,580,806 MWh - - - NA27 Skewing 0.122891 28 Substation Ownership 401 MW (0.44) (177) (0.38) (153) 24 13.6 29 Joint Substation Ownership 3,398 MW (0.30) (1,019) (0.26) (878) 141 13.9 30 Allocated Distribution Charge - MW 0.34 - - NA31 System Access 428 Bills 200.00 86 200.00 86 - - 32 Provisions33 Education GEI 8,992 MWh (0.000326) (3) (0.000296) (3) 0 9.3 34 Annual Power Factor Adjustment (20) (12) 8 40.7 35 Total Delivery 7,907$ 6,631$ (1,276) (16.1)

36 ROA Service37 Delivery38 Maximum kW/mth 2,106 MW 1.14 2,400$ 0.96 2,015$ (385)$ (16.0) 39 Distribution kWh/mth 1,180,785 MWh - - - - - NA40 Substation Ownership 226 MW (0.44) (100) (0.38) (86) 14 13.6 41 System Access 163 Bills 200.00 33 200.00 33 - - 42 Provisions43 Education GEI 2,995 MWh (0.000326) (1) (0.000296) (1) 0 9.3 44 Total Delivery 2,333$ 1,961$ (371)$ (15.9)

45 Total Primary GPD (Voltage Level 1) 312,465$ 302,887$ (9,578)$ (3.1)





( a ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i )LineNo. Quantity Units Rates Revenue Rates Revenue Revenue Percent



Non Capacity1 On-peak kW/mth 1,600 MW 21.24 33,989$ 9.58 15,331$ (18,657)$ (54.9) 2 On-peak kWh/mth 197,061 MWh 0.053966 10,635 0.048271 9,512$ (1,122) (10.6) 3 Off-peak kWh/mth 558,517 MWh 0.036098 20,161 0.032370 18,079$ (2,082) (10.3) 4 Capacity5 On-peak kW/mth 1,600 MW - -$ 11.66 18,657$ 18,657$ NA6 Provisions7 Interruptible GI 295 MW (7.00) (2,063) (7.00) (2,063)$ - - 8 Education GEI 22,535 MWh (0.000326) (7) - 7 100.0 9 Total Summer Power Supply 62,714 59,517 (3,197) (5.1) 10 Winter (Oct. - May)11 Non Capacity12 On-peak kW/mth 2,972 MW 20.24 60,145 9.58 28,470$ (31,675) (52.7) 13 On-peak kWh/mth 372,422 MWh 0.044207 16,464 0.038318 14,270$ (2,193) (13.3) 14 Off-peak kWh/mth 1,051,572 MWh 0.038935 40,943 0.034274 36,042$ (4,901) (12.0) 15 Capacity16 On-peak kW/mth 2,972 MW - 10.66 31,675$ 31,675 NA17 Provisions18 Interruptible GI 521 MW (6.00) (3,126) (6.00) (3,126)$ - - 19 Education GEI 36,082 MWh (0.000326) (12) - 12 100.0 20 Total Winter Power Supply 114,414 107,331 (7,083) (6.2) 21 Annual PSCR Factor kWh/mth 2,179,573 MWh 0.002230 4,860 0.002230 4,860$ - - 22 Annual Power Factor Adjustment (112) (105) 6 5.7 23 Total Power Supply 181,877$ 171,604$ (10,273)$ (5.6)

24 Delivery25 Maximum kW/mth 5,806 5,806 MW 2.07 12,018$ 1.85 10,753$ (1,265)$ (10.5) 26 Distribution kWh/mth 2,179,573 MWh - - - NA27 Substation Ownership 767 MW (0.64) (491) (0.65) (499)$ (8) (1.6) 28 Allocated Distribution Charge - MW 0.34 -$ - NA29 System Access 1,443 Bills 200.00 289 200.00 289 - - 30 Provisions31 Education GEI 58,617 MWh (0.000326) (19) (0.000296) (17)$ 2 9.3 32 Annual Power Factor Adjustment (7) (6) 1 12.7 33 Total Delivery 11,789$ 10,519$ (1,270) (10.8)

34 ROA Service35 Delivery36 Maximum kW/mth 3,049 MW 2.07 6,311$ 1.85 5,647$ (664)$ (10.5) 37 Distribution kWh/mth 1,490,701 MWh - - - - - NA38 Substation Ownership 339 MW (0.64) (217) (0.65) (221) (3) (1.6) 39 System Access 497 Bills 200.00 99 200.00 99 - - 40 Provisions41 Education GEI 78,484 MWh (0.000326) (26) (0.000296) (23) 2 9.3 42 Total Delivery 6,167$ 5,502$ (665)$ (10.8)

43 Total Primary GPD (Voltage Level 2) 199,833$ 187,625$ (12,208)$ (6.1) 181,946$








Non Capacity1 On-peak kW/mth 3,472 MW 22.24 77,220$ 9.58 33,266$ (43,955)$ (56.9) 2 On-peak kWh/mth 463,965 MWh 0.052166 24,203 0.053971 25,041$ 838 3.5 3 Off-peak kWh/mth 1,182,496 MWh 0.034298 40,557 0.038070 45,018$ 4,461 11.0 4 Capacity5 On-peak kW/mth 3,472 MW - -$ 12.66 43,955$ 43,955$ NA6 Provisions7 Interruptible GI 493 MW (7.00) (3,448) (7.00) (3,448)$ - - 8 Education GEI 79,396 MWh - - - NA9 Total Summer Power Supply 138,533 143,831 5,298 3.8 10 Winter (Oct. - May)11 Non Capacity12 On-peak kW/mth 6,480 MW 21.24 137,643 9.58 62,087$ (75,556) (54.9) 13 On-peak kWh/mth 861,812 MWh 0.042407 36,547 0.044018 37,935$ 1,388 3.8 14 Off-peak kWh/mth 2,228,836 MWh 0.037135 82,768 0.039974 89,096$ 6,328 7.6 15 Capacity16 On-peak kW/mth 6,480 MW - 11.66 75,556$ 75,556 NA17 Provisions18 Interruptible GI 958 MW (6.00) (5,748) (6.00) (5,748)$ - - 19 Education GEI 199,422 MWh - - - NA20 Total Winter Power Supply 251,210 258,927 7,717 3.1 21 Annual PSCR Factor kWh/mth 4,737,109 MWh 0.002230 10,564 0.002230 10,564$ - - 22 Annual Power Factor Adjustment 61 63 2 3.2 23 Total Power Supply 400,367$ 413,384$ 13,017$ 3.3

24 Delivery25 Maximum kW/mth 12,296 MW 4.92 60,496$ 4.20 51,693$ (8,803)$ (14.6) 26 Distribution kWh/mth 4,737,109 MWh - - - NA27 System Access 19,261 Bills 200.00 3,852 200.00 3,852 - - 28 Provisions29 Education GEI 278,818 MWh (0.000326) (91) (0.000296) (82)$ 8 9.3 30 Annual Power Factor Adjustment 9 8 (1) (14.5) 31 Total Delivery 64,267$ 55,470$ (8,796) (13.7)

32 ROA Service33 Delivery34 Maximum kW/mth 3,066 MW 4.92 15,083$ 4.20 12,888$ (2,195)$ (14.6) 35 Distribution kWh/mth 1,184,207 MWh - - - - - NA36 System Access 3,976 Bills 200.00 795 200.00 795 - - 37 Provisions38 Education GEI 160,930 MWh (0.000326) (52) (0.000296) (48)$ 5 9.3 39 Total Delivery 15,825$ 13,635$ (2,190)$ (13.8)

40 Total Primary GPD (Voltage Level 3) 480,459$ 482,490$ 2,031$ 0.4




Primary Energy Intensive Rate (Voltage Level 1)

( a ) (b) ( c ) ( d ) ( e ) ( f ) ( g ) ( h )

LineNo. Quantity Units Rates Revenue Rates Revenue Revenue Percent

$/unit $000 $/unit $000 $000 %Power Supply

Summer (June - Sept.)Non Capacity

1 Critical-peak kWh/mth 1 MWh 0.142347 0$ 0.083474 0$ (0)$ (41.4) 2 High-peak kWh/mth 4,735 MWh 0.094898 449 0.055649 263 (186) (41.4) 3 Mid-peak kWh/mth 4,917 MWh 0.083074 408 0.051866 255 (153) (37.6) 4 Low-peak kWh/mth 23,913 MWh 0.064447 1,541 0.042562 1,018 (523) (34.0) 5 Off-peak kWh/mth 29,759 MWh 0.048349 1,439 0.031238 930 (509) (35.4) 6 Capacity7 Critical-peak kWh/mth 1 MWh -$ 0.043433 0$ 0$ NA8 High-peak kWh/mth 4,735 MWh - 0.028955 137 137 NA9 Mid-peak kWh/mth 4,917 MWh - 0.026987 133 133 NA10 Low-peak kWh/mth 23,913 MWh - 0.022146 530 530 NA11 Off-peak kWh/mth 29,759 MWh - 0.016254 484 484 NA12 Total Summer Power Supply 3,838$ 3,749$ (1,372)$ (35.7) 13 Winter (Oct. - May)14 Non Capacity15 Critical-peak kWh/mth - MWh 0.093950 -$ 0.078136 -$ -$ NA16 High-peak kWh/mth 9,053 MWh 0.062634 567 0.052091 472 (95) (16.8) 17 Mid-peak kWh/mth 8,939 MWh 0.060278 539 0.041733 373 (166) (30.8) 18 Off-peak kWh/mth 103,712 MWh 0.051142 5,304 0.032301 3,350 (1,954) (36.8) 19 Capacity20 Critical-peak kWh/mth - MWh -$ 0.040656 -$ -$ NA21 High-peak kWh/mth 9,053 MWh - 0.027104 245 245 NA22 Mid-peak kWh/mth 8,939 MWh - 0.021715 194 194 NA23 Off-peak kWh/mth 103,712 MWh - 0.016807 1,743 1,743 NA24 Total Winter Power Supply 6,410$ 6,377$ (2,215)$ (34.6) 25 Annual Power Factor Adjustment 16$ 15$ 26 Annual PSCR Factor kWh/mth 185,029 MWh 0.002230 413 0.002230 413 - - 27 Total Power Supply 10,660$ 10,554$ (106)$ (1.0)

Delivery28 Maximum kW/mth 985 MW 1.14 1,122$ 0.96 942$ (180)$ (16.0) 29 Distribution kWh/mth 185,029 MWh - - - - NA

Skewing - 0.000276 30 Substation Ownership 784 MW (0.44) (345) (0.38) (298) 47 13.6 31 System Access 41 Bills 200.00 8 200.00 8 - - 32 Annual Power Factor Adjustment 2 2 (0) (3.0) 33 Total Delivery 788$ 655$ (133)$ (16.9)

34 Total Primary EIP/MMPP (Voltage Level 1) 11,448$ 11,209$ (239)$ (2.1)

DescriptionBilling Determinants Present Proposed Difference




( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h )




1 Critical-peak kWh/mth 3 MWh 0.145347 0$ 0.085474 0$ (0)$ (41.2) 2 High-peak kWh/mth 795 MWh 0.097898 78 0.057649 46 (32) (41.1) 3 Mid-peak kWh/mth 892 MWh 0.086074 77 0.053866 48 (29) (37.4) 4 Low-peak kWh/mth 5,535 MWh 0.067447 373 0.044562 247 (127) (33.9) 5 Off-peak kWh/mth 10,681 MWh 0.051349 548 0.033238 355 (193) (35.3) 6 Capacity7 Critical-peak kWh/mth 3 MWh -$ 0.046433 0$ 0$ NA8 High-peak kWh/mth 795 MWh - 0.031955 25 25 NA9 Mid-peak kWh/mth 892 MWh - 0.029987 27 27 NA10 Low-peak kWh/mth 5,535 MWh - 0.025146 139 139 NA11 Off-peak kWh/mth 10,681 MWh - 0.019254 206 206 NA12 Total Summer Power Supply 1,077$ 1,093$ 16$ 1.49585913 Winter (Oct. - May)14 Non Capacity15 Critical-peak kWh/mth - MWh 0.096950 -$ 0.080136 -$ -$ NA16 High-peak kWh/mth 1,914 MWh 0.065634 126 0.054091 104 (22) (17.6) 17 Mid-peak kWh/mth 1,938 MWh 0.063278 123 0.043733 85 (38) (30.9) 18 Off-peak kWh/mth 35,520 MWh 0.054142 1,923 0.034301 1,218 (705) (36.6) 19 Capacity20 Critical-peak kWh/mth - MWh -$ 0.043656 -$ -$ NA21 High-peak kWh/mth 1,914 MWh - 0.030104 58 58 NA22 Mid-peak kWh/mth 1,938 MWh - 0.024715 48 48 NA23 Off-peak kWh/mth 35,520 MWh - 0.019807 704 704 NA24 Total Winter Power Supply 2,171 2,216 44 2.0 25 Annual Power Factor Adjustment (9) (10) 26 Annual PSCR Factor kWh/mth 57,279 MWh 0.002230 128$ 0.002230 128$ -$ - 27 Total Power Supply 3,376$ 3,426$ 50$ 1.5

Delivery28 Maximum kW/mth 422 MW 2.07 874$ 1.85 782$ (92)$ (10.5) 29 Distribution kWh/mth 57,279 MWh - - - NA30 Substation Ownership 186 MW (0.64) (119) (0.65) (121) (2) (1.6) 31 System Access 76 Bills 200.00 15 200.00 15 - - 32 Annual Power Factor Adjustment (4) (3) 0 4.2 33 Total Delivery 767$ 673$ (94)$ (12.2)

34 Total Primary EIP/MMPP (Voltage Level 2) 4,143$ 4,099$ (44)$ (1.1)


Billing Determinants Present Proposed




( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h )




1 Critical-peak kWh/mth 1 MWh 0.134347 0$ 0.091174 0$ (0)$ (32.1) 2 High-peak kWh/mth 153 MWh 0.086898 13 0.063349 10 (4) (27.1) 3 Mid-peak kWh/mth 177 MWh 0.075074 13 0.059566 11 (3) (20.7) 4 Low-peak kWh/mth 1,881 MWh 0.056447 106 0.050262 95 (12) (11.0) 5 Off-peak kWh/mth 2,238 MWh 0.040349 90 0.038938 87 (3) (3.5) 6 Capacity7 Critical-peak kWh/mth 1 MWh -$ 0.035433 0$ 0$ NA8 High-peak kWh/mth 153 MWh - 0.020955 3 3 NA9 Mid-peak kWh/mth 177 MWh - 0.018987 3 3 NA10 Low-peak kWh/mth 1,881 MWh - 0.014146 27 27 NA11 Off-peak kWh/mth 2,238 MWh - 0.008254 18 18 NA12 Total Summer Power Supply 223$ 254$ 31$ 13.7 13 Winter (Oct. - May)14 Non Capacity15 Critical-peak kWh/mth - MWh 0.085950 -$ 0.085836 -$ -$ NA16 High-peak kWh/mth 148 MWh 0.054634 8 0.059791 9 1 9.4 17 Mid-peak kWh/mth 218 MWh 0.052278 11 0.049433 11 (1) (5.4) 18 Off-peak kWh/mth 7,997 MWh 0.043142 345 0.040001 320 (25) (7.3) 19 Capacity20 Critical-peak kWh/mth - MWh -$ 0.032656 -$ -$ NA21 High-peak kWh/mth 148 MWh - 0.019104 3 3 NA22 Mid-peak kWh/mth 218 MWh - 0.013715 3 3 NA23 Off-peak kWh/mth 7,997 MWh - 0.008807 70 70 NA24 Total Winter Power Supply 365$ 416$ 51$ 14.1 25 Annual Power Factor Adjustment (3)$ (4)$ 26 Annual PSCR Factor kWh/mth 12,813 MWh 0.002230 29 0.002230 29 - - 27 Total Power Supply 616$ 694$ 77$ 12.6

Delivery28 Maximum kW/mth 102 MW 4.92 500$ 4.20 427$ (73)$ (14.6) 29 Distribution kWh/mth 12,813 MWh - - - NA30 System Access 74 Bills 200.00 15 200.00 15 - - 31 Annual Power Factor Adjustment (2) (2) 0 9.6 32 Total Delivery 512$ 439$ (72) (14.2)

33 Total Primary EIP/MMPP (Voltage Level 3) 1,128$ 1,133$ 5$ 0.4 1,100$





General Service Primary Time-of-Use - GPTU (Voltage Level 1)

( a ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i )




1 High-/On-peak kWh/mth 26 MWh 0.130817 3$ 0.085575 2$ (1)$ (34.6) 2 Mid-peak kWh/mth 32 MWh 0.114519 4 0.079510 3 (1) (30.6) 3 Low-peak kWh/mth 58 MWh 0.088840 5 0.065203 4 (1) (26.6) 4 Off-peak kWh/mth 251 MWh 0.066649 17 0.047789 12 (5) (28.3) 5 Capacity6 High-/On-peak kWh/mth 26 MWh -$ 0.022259 1$ 1$ NA7 Mid-peak kWh/mth 32 MWh - 0.020681 1 1 NA8 Low-peak kWh/mth 58 MWh - 0.016960 1 1 NA9 Off-peak kWh/mth 251 MWh - 0.012430 3 3 NA10 Provisions11 Education GEI - MWh - - - - NA12 Total Summer Power Supply 29 26 (3) (10.6) 13 Winter (Oct. - May)14 Non Capacity15 High-/On-peak kWh/mth 28 MWh 0.086341 2 0.056824 2 (1) (34.2) 16 Mid-peak kWh/mth 38 MWh 0.083093 3 0.053968 2 (1) (35.1) 17 Off-peak kWh/mth 850 MWh 0.070500 60 0.047154 40 (20) (33.1) 18 Capacity19 High-/On-peak kWh/mth 28 MWh - 0.014780 0 0 NA20 Mid-peak kWh/mth 38 MWh - 0.014037 1 1 NA21 Off-peak kWh/mth 850 MWh - 0.012265 10 10 NA22 Provisions23 Education GEI - MWh - - - - NA24 Total Winter Power Supply 65 55 (10) (15.9) 25 Annual PSCR Factor kWh/mth 1,283 MWh 0.002230 3 0.002230 3 - -

26 Annual Power Factor Adjustment (0) (0) 0 12.7 27 Total Power Supply 97$ 83$ (13)$ (13.8) 2829 Delivery30 Maximum kW/mth 4 MW 1.14 5$ 0.96 4$ (1)$ (16.0) 31 Distribution kWh/mth 1,283 MWh - - - - - NA32 Substation Ownership - MW (0.44) - (0.38) - - NA33 System Access 12 Bills 200.00 2 200.00 2 - - 34 Annual Power Factor Adjustment (0) (0) 0 3.0 35 Provisions36 Education GEI - MWh (0.000326) - (0.000296) - - NA37 Total Delivery 8$ 7$ (1)$ (11.0) 3839 Total Primary GPTU (Voltage Level 1) 104$ 90$ (14)$ (13.6)






( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h )


$/unit $000 $/unit $000 $000 %Power Supply Present


1 High-/On-peak kWh/mth 1,167 MWh 0.135817 158$ 0.087575 102$ (56)$ (35.5) 2 Mid-peak kWh/mth 1,540 MWh 0.119519 184 0.081510 126$ (59) (31.8) 3 Low-peak kWh/mth 3,057 MWh 0.093840 287 0.067203 205$ (81) (28.4) 4 Off-peak kWh/mth 6,168 MWh 0.071649 442 0.049789 307$ (135) (30.5) 5 Capacity6 High-/On-peak kWh/mth 1,167 MWh -$ 0.024259 28$ 28$ NA7 Mid-peak kWh/mth 1,540 MWh - 0.022681 35$ 35 NA8 Low-peak kWh/mth 3,057 MWh - 0.018960 58$ 58 NA9 Off-peak kWh/mth 6,168 MWh - 0.014430 89$ 89 NA10 Provisions11 Education GEI - MWh - - -$ - NA12 Total Summer Power Supply 1,071 951 (121) (11.3) 13 Winter (Oct. - May)14 Non Capacity15 High-/On-peak kWh/mth 1,358 MWh 0.091341 124$ 0.058824 80$ (44)$ (35.6) 16 Mid-peak kWh/mth 1,708 MWh 0.088093 150 0.055968 96$ (55) (36.5) 17 Off-peak kWh/mth 11,875 MWh 0.075500 897 0.049154 584$ (313) (34.9) 18 Capacity19 High-/On-peak kWh/mth 1,358 MWh -$ 0.016780 23$ 23$ NA20 Mid-peak kWh/mth 1,708 MWh - 0.016037 27$ 27 NA21 Off-peak kWh/mth 11,875 MWh - 0.014265 169$ 169 NA22 Provisions23 Education GEI - MWh - - -$ - NA24 Total Winter Power Supply 1,171 979 (192) (16.4) 25 Annual PSCR Factor kWh/mth 26,873 MWh 0.002230 60 0.002230 60 - - 26 Annual Power Factor Adjustment (10) (8) 1 12.5 27 Total Power Supply 2,293$ 1,981$ (312)$ (13.6)

28 Delivery29 Maximum kW/mth 67 MW 2.07 139$ 1.85 125$ (15)$ (10.5) 30 Distribution kWh/mth 26,873 MWh - - - - - NA31 Substation Ownership 23 23 (0.64) (14) (0.65) (15) (0) (1.6) 32 System Access 48 Bills 200.00 10 200.00 10 - - 33 Provisions34 Education GEI - MWh (0.000326) - (0.000296) - - NA35 Annual Power Factor Adjustment (1) (1) 0 4.2 36 Total Delivery 134$ 119$ (15) (11.1)

37 Total Primary GPTU (Voltage Level 2) 2,427$ 2,100$ (327)$ (13.5)






( a ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i )


$/unit $000 $/unit $000 $000 %Power Supply Present


1 High-/On-peak kWh/mth 11,127 MWh 0.134017 1,491$ 0.093275 1,038$ (453)$ (30.4) 2 Mid-peak kWh/mth 14,356 MWh 0.117719 1,690 0.087210 1,252$ (438) (25.9) 3 Low-peak kWh/mth 32,194 MWh 0.092040 2,963 0.072903 2,347$ (616) (20.8) 4 Off-peak kWh/mth 55,994 MWh 0.069849 3,911 0.055489 3,107$ (804) (20.6) 5 Capacity6 High-/On-peak kWh/mth 11,127 MWh -$ 0.029959 333$ 333$ NA7 Mid-peak kWh/mth 14,356 MWh - 0.028381 407$ 407 NA8 Low-peak kWh/mth 32,194 MWh - 0.024660 794$ 794 NA9 Off-peak kWh/mth 55,994 MWh - 0.020130 1,127$ 1,127 NA10 Provisions11 Education GEI - MWh -$ - -$ - NA12 Total Summer Power Supply 10,055 10,406 350 3.5 13 Winter (Oct. - May)14 Non Capacity15 High-/On-peak kWh/mth 14,463 MWh 0.089541 1,295$ 0.064524 933$ (362)$ (27.9) 16 Mid-peak kWh/mth 18,422 MWh 0.086293 1,590 0.061668 1,136$ (454) (28.5) 17 Off-peak kWh/mth 129,225 MWh 0.073700 9,524 0.054854 7,088$ (2,435) (25.6) 18 Capacity19 High-/On-peak kWh/mth 14,463 MWh -$ 0.022480 325$ 325$ NA20 Mid-peak kWh/mth 18,422 MWh - 0.021737 400$ 400 NA21 Off-peak kWh/mth 129,225 MWh - 0.019965 2,580$ 2,580 NA22 Provisions23 Education GEI - MWh -$ - -$ - NA24 Total Winter Power Supply 12,409 12,463 55 0.4 25 Annual PSCR Factor kWh/mth 275,781 MWh 0.002230 615 0.002230 615 - -

26 Annual Power Factor Adjustment 14 15 0 2.9 27 Total Power Supply 23,093$ 23,499$ 405$ 1.8

28 Delivery29 Maximum kW/mth 769 MW 4.92 3,786$ 4.20 3,235$ (551)$ (14.6) 30 Distribution kWh/mth 275,781 MWh - - - - - NA31 System Access 984 Bills 200.00 197 200.00 197 - - 32 Provisions33 Education GEI - MWh (0.000326) - (0.000296) -$ - NA34 Annual Power Factor Adjustment 2 2 (0) (9.6) 35 Total Delivery 3,985$ 3,434$ (551) (13.8)

36 Total Primary GPTU (Voltage Level 3) 27,078$ 26,933$ (146)$ (0.5)





Large Self-Generation GSG-2


$/unit $000 $/unit $000 $000 %

Power Supply1 Primary2 On Peak Capacity3 Voltage Level 14 Summer - MW - - 15.20 - - NA5 Winter - MW - - 14.20 - - NA6 Voltage Level 27 Summer - MW - - 17.20 - - NA8 Winter - MW - - 16.20 - - NA9 Voltage Level 310 Summer - MW - - 19.20 - - NA11 Winter - MW - - 18.20 - - NA1213 Delivery14 Standby kW/mth15 Voltage Level 1 1,145 MW 1.14 1,305$ 0.96 1,096$ (209)$ (16.0) 16 Voltage Level 2 529 MW 2.07 1,096 1.85 980$ (115) (10.5) 17 Voltage Level 3 - MW 4.92 - 4.20 -$ - NA18 Substation Ownership19 Voltage Level 1 422 MW (0.44) (186) (0.38) (160)$ 25 13.6 20 Voltage Level 2 96 MW (0.64) (61) (0.65) (62)$ (1) (1.6) 21 Transmission Interconnect 96 MW (1.25) (110) (0.96) (92)$ 18 16.2 22 Standby Option23 System Access 108 Bills 200.00 22 200.00 22 - - 24 Supplement Option (1)25 System Access - Bills 100.00 - 100.00 - - NA26 Total Delivery 2,065$ 1,783$ (282)$ (13.7)

Sources(1) For customers who generate a portion of their load requirements, but take the majority of their power from Consumers Energy.




Metered Lighting Service GML



Secondary ServiceNon Capacity

1 All kWh/mth 17,410 MWh 0.052873 921$ 0.051003 888$ (33)$ (3.5) 2 Capacity3 All kWh/mth 17,410 MWh -$ - -$ -$ NA4 Primary Service5 Non Capacity6 All kWh/mth 794 MWh 0.025948 21 0.025030 20 (1) (3.5) 7 Capacity8 All kWh/mth 794 MWh - - - - - NA9 Annual PSCR Factor kWh/mth 18,204 MWh 0.002230 41 0.002230 41 - -

10 Total Power Supply 982$ 948$ (33)$ (3.4)

11 Delivery12 Secondary Service13 Distribution kWh/mth 17,410 MWh 0.055922 974$ 0.065287 1,137$ 163$ 16.7 14 System Access 3,384 Bills 10.00 34 10.00 34 - - 15 Primary Service16 Distribution kWh/mth 794 MWh 0.042091 33 0.049394 39 6 17.4 17 System Access 48 Bills 20.00 1 20.00 1 - - 18 Total Delivery 1,042$ 1,211$ 169$ 16.2

19 Total Metered Lighting GML 2,024$ 2,159$ 136$ 6.7 1,983$




Unmetered Lighting Service GUL

( a ) ( b ) ( c ) ( d ) ( e ) ( f ) ( g ) ( h ) ( i ) ( j ) ( k ) ( l ) ( m )

Line Customer Company

No. Fixtures Fixtures UnitsWatts Incl

BallastTotal MWh

Annual Service Fixture RevenueNon Cap Service

Cap Service Fixture Revenue Revenue Percent

$/unit $/unit $000 $/unit $/unit $/unit $000 $000 %Mercury Vapor

1 3500 Lumens - 5,626 Lights 128 252 6.21 6.00 69$ 7.76 - 6.00 77$ 9$ 12.6 2 7500 Lumens 36 180,596 Lights 209 13,213 10.14 6.00 2,916 12.67 - 6.00 2,028 274 9.4 3 10000 Lumens 432 40,868 Lights 281 4,062 13.64 6.00 809 17.03 - 6.00 900 133 16.4 4 20000 Lumens 828 29,232 Lights 458 4,819 22.23 6.00 844 27.76 - 6.00 693 114 13.6 5 35000 Lumens - 78 Lights 770 21 37.38 6.00 3 46.67 - 6.00 4 1 21.4 6 50000 Lumens - 58 Lights 1,080 22 52.42 6.00 3 65.45 - 6.00 4 1 22.3 7 Total Mercury Vapor 1,296 256,458 - 4,644 3,707 531 11.4

High-Pressure Sodium - - - 8 5000 Lumens 72 2,138 Lights 83 64 4.03 6.00 22 5.03 - 6.00 24 2 10.2 9 8500 Lumens 804 1,338,324 Lights 117 54,837 5.68 6.00 15,635 7.09 - 6.00 16,897 1,823 11.7

10 14000 Lumens 1,404 188,256 Lights 171 11,351 8.30 6.00 2,704 10.36 - 6.00 3,095 391 14.5 11 20000 Lumens 60 13,548 Lights 247 1,176 11.99 6.00 244 14.97 - 6.00 285 41 16.6 12 24000 Lumens 540 167,346 Lights 318 18,686 15.44 6.00 3,595 19.27 - 6.00 4,240 644 17.9 13 45000 Lumens 180 79,207 Lights 480 13,337 23.30 6.00 2,325 29.09 - 6.00 2,785 460 19.8 14 Total HP Sodium 3,060 1,788,819 - 24,525 27,326 3,361 13.7

Incandescent - - - 15 2500 Lumens - 3,420 Lights 202 242 9.80 6.00 54 12.24 - 6.00 62 8 15.4 16 4000 Lumens 108 - Lights 305 12 14.80 6.00 2 18.48 - 6.00 2 0 24.9 17 6000 Lumens 24 3,540 Lights 405 505 19.66 6.00 91 24.55 - 6.00 109 17 19.1 18 10000 Lumens - 12 Lights 690 3 33.49 6.00 0 41.82 - 6.00 1 0 21.1 19 Total Incandescent 132 6,972 - 147 174 26 17.8

Fluorescent - - - 20 20000 Lumens - 252 Lights 470 41 22.81 6.00 7 28.48 - 6.00 9 1 19.7

Metal Halide - - - 21 9750 Lumens - 492 Lights 170 29 8.25 6.00 7 10.30 - 6.00 8 1 14.4 22 10500 Lumens 468 4,632 Lights 210 375 10.19 6.00 80 12.73 - 6.00 93 13 16.2 23 15500 Lumens 12 1,908 Lights 290 195 14.08 6.00 38 17.58 - 6.00 45 7 17.5 24 24000 Lumens 24 888 Lights 460 147 22.33 6.00 26 27.88 - 6.00 31 5 19.7 25 Total Metal Halide 504 7,920 151 177 26 17.0 26 Annual PSCR Factor kWh/mth 123,389 MWh 0.002230 275 0 0 0.002230 255 - -

27 Total Unmetered Lighting GUL 29,750$ 31,647$ 1,897$ 6.4

Classification Customer Company Customer Company

28 Power Supply (%) 37.2 21.8 29.5 17.9 29 Delivery (%) 62.8 78.2 70.5 82.1

Present ProposedDifference

Billing Determinants

Proposed

Description

Rates Rates

Present U-17990



Unmetered Experimental Lighting Service GU-XL



Non Capacity1 All kWh/mth 14 4,420 MWh 0.051599 1$ 0.059659 264$ 263$ 37,025.1

CapacityAll kWh/mth 14 4,420 MWh - -$ - -$ -$ NA

2 Annual PSCR Factor kWh/mth 14 4,420 MWh 0.002230 0 0.002230 10 10 32,009.4 3 Total Power Supply 1$ 274$ 273$ 36,817.3

DeliveryCustomer Owned Equipment

4 Distribution kWh/mth 10 10 MWh 0.042405 0$ 0.026842 0$ (0)$ (36.7) Company Owned Equipment

5 Distribution kWh/mth 4 4,410 MWh 0.052012 0 0.032923 145 145 74,369.2 6 Fixture Charge/mth 119 168,000 Light 6.00 1 6.00 1,008 1,007 141,076.5 7 Total Delivery 1$ 1,153$ 1,152$ 86,383.0

8 Total Unmetered Service GU-XL 2$ 1,427$ 1,425$ 68,680.7




Unmetered Service GU



Non Capacity1 All kWh/mth 85,150 MWh 0.073436 6,253$ 0.056212 4,786$ (1,467)$ (23.5)

CapacityAll kWh/mth 85,150 MWh -$ 0.018227 1,552$ 1,552$ NA

2 Annual PSCR Factor kWh/mth 85,150 MWh 0.002230 190 0.002230 190 - - 3 Total Power Supply 6,443$ 6,528$ 85$ 1.3

Delivery4 Distribution kWh/mth 85,150 MWh 0.014975 1,275$ 0.017046 1,451$ 176$ 13.8 5 System Access 5,268 Bills 2.00 11 2.00 11 - - 6 Total Delivery 1,286$ 1,462$ 176$ 13.7

7 Total Unmetered Service GU 7,729$ 7,990$ 262$ 3.4


ps0718-1-223

S T A T E O F M I C H I G A N

BEFORE THE MICHIGAN PUBLIC SERVICE COMMISSION

In the matter of the application of ) CONSUMERS ENERGY COMPANY ) for authority to increase its rates for ) Case No. U-18322 the generation and distribution of ) electricity and for other relief. ) )

PROOF OF SERVICE STATE OF MICHIGAN ) ) SS COUNTY OF JACKSON ) Samantha J. O’Rourke, being first duly sworn, deposes and says that she is employed in the Legal Department of Consumers Energy Company; that on July 13, 2018, she served an electronic copy of Consumers Energy Company’s revised tariff sheets (Attachment A), along with supporting workpapers in the form of a revised rate design (Attachment B) upon the persons listed in Attachment 1 hereto, at the e-mail addresses listed therein. She further states that she also served a hard copy of the same document to the Hon. Sharon L. Feldman at the address listed in Attachment 1 by depositing the same in the United States mail in the City of Jackson, Michigan, with first-class postage thereon fully paid. __________________________________________ Samantha J. O’Rourke Subscribed and sworn to before me this 13th day of July, 2018. _________________________________________ Tara L. Hilliard, Notary Public State of Michigan, County of Jackson My Commission Expires: 09/12/20 Acting in the County of Jackson

ATTACHMENT 1 TO CASE NO. U-18322

sl0517-1-225 Page 1 of 3

Administrative Law Judge Hon. Sharon L. Feldman Administrative Law Judge 7109 West Saginaw Highway Post Office Box 30221 Lansing, MI 48909 E-Mail: [email protected] Counsel for the Michigan Public Service Commission Staff Spencer A. Sattler, Esq. Amit T. Singh, Esq. Monica M. Stephens, Esq. Assistant Attorneys General 7109 West Saginaw Highway Post Office Box 30221 Lansing, MI 48909 E-Mail: [email protected] [email protected] [email protected] Michigan Public Service Commission Staff Gary Kitts Bill Stosik Dan Blair Brian Ballinger Paul Proudfoot Bob Nichols Michigan Public Service Commission 7109 West Saginaw Highway Post Office Box 30221 Lansing, MI 48909 E-Mail: [email protected] [email protected] [email protected] [email protected] [email protected] [email protected]

Counsel for Attorney General, Bill Schuette Joel B. King, Esq. Celeste Gill, Esq. Assistant Attorney General Michigan Dept. of Attorney General, Special Litigation Unit 6th Floor Williams Building Post Office Box 30755 Lansing, MI 48909 E-Mail: [email protected] [email protected] [email protected] Consultant for Attorney General Bill Schuette Sebastian Coppola, President Corporate Analytics 5928 Southgate Road Rochester, MI 48306 E-Mail: [email protected] Counsel for the Michigan State Utility Workers Council, Utility Workers Union of America, AFL-CIO John R. Canzano, Esq. Patrick J. Rorai, Esq. McKnight, Canzano, Smith, Radtke & Brault, P.C. 423 North Main Street, Suite 200 Royal Oak, MI 48067 E-Mail: [email protected] [email protected] Counsel for the Michigan Cable Telecommunications Association Michael S. Ashton, Esq. Fraser Trebilcock Davis & Dunlap, P.C. 124 West Allegan Street, Suite 1000 Lansing, MI 48933 E-Mail: [email protected]

ATTACHMENT 1 TO CASE NO. U-18322 (Continued)

sl0517-1-225 Page 2 of 3

Counsel for the Michigan Environmental Council, the Sierra Club, and the Natural Resources Defense Council Christopher M. Bzdok, Esq. Tracy Jane Andrews, Esq. Kimberly Flynn, Legal Assistant Karla Gerds, Legal Assistant Marcia Randazzo, Legal Assistant Olson, Bzdok & Howard, P.C. 420 East Front Street Traverse City, MI 49686 E-Mail: [email protected] [email protected] [email protected] [email protected] [email protected] Counsel for the Sierra Club Michael Soules, Esq. Shannon Fisk, Esq. Flora Champenois, Litigation Assistant Gabrielle Winick, Litigation Assistant 1625 Massachusetts Avenue NW, Suite 702 Washington, DC 20036 E-Mail: [email protected] [email protected] [email protected] [email protected] Counsel for The Kroger Company Kurt J. Boehm, Esq. Jody M. Kyler Cohn, Esq. Michael L. Kurtz, Esq. Boehm, Kurtz & Lowry 36 East Seventh Street, Suite 1510 Cincinnati, Ohio 45202 E-Mail: [email protected] [email protected] [email protected] Consultant for The Kroger Company Kevin Higgins Energy Strategies, LLC Parkside Towers 215 South State Street, Suite 200 Salt Lake City, Utah 84111

E-Mail: [email protected] Counsel for the Michigan Cable Telecommunications Association David E. S. Marvin, Esq. Michael S. Ashton, Esq. Fraser Trebilcock Davis & Dunlap, P.C. 124 West Allegan Street, Suite 1000 Lansing, MI 48933 E-Mail: [email protected] [email protected] Counsel for the Association of Businesses Advocating Tariff Equity (“ABATE”) and Gerdau Macsteel, Inc. Sean P. Gallagher, Esq. Michael J. Pattwell, Esq. Clark Hill PLC 212 East Grand River Avenue Lansing, MI 48906 E-Mail: [email protected] [email protected] [email protected] Consultant for ABATE and Gerdau Macsteel, Inc. Jeffry C. Pollock J. Pollock, Inc. 12647 Olive Boulevard, Suite 585 St. Louis, MO 63141 E-Mail: [email protected] Counsel for the Residential Customer Group Don L. Keskey, Esq. Brian W. Coyer, Esq. Public Law Resource Center PLLC 333 Albert Avenue, Suite 425 East Lansing, MI 48823 E-Mail: [email protected] bwcoyer@ publiclawresourcecenter.com

ATTACHMENT 1 TO CASE NO. U-18322 (Continued)

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Counsel for Wal-Mart Stores East, LP and Sam’s East, Inc. Melissa M. Horne, Esq. Higgins, Cavanagh & Cooney, LLP 10 Dorrance Street, 4th Floor Providence, RI 02903 E-Mail: [email protected] Counsel for Hemlock Semiconductor Corporation and Constellation NewEnergy Inc. Jennifer Utter Heston, Esq. Fraser Trebilcock Davis & Dunlap, P.C. 124 West Allegan, Suite 1000 Lansing, MI 48933 E-Mail: [email protected] Counsel for Midland Cogeneration Venture Limited Partnership Richard J. Aaron, Esq. Jason T. Hanselman, Esq. Dykema Gossett PLLC 201 Townsend Street, Suite 900 Lansing, MI 48933 E-Mail: [email protected] [email protected] Charles E. Dunn, Esq. Midland Cogeneration Venture, LP 100 Progress Place Midland, MI 48640 E-Mail: [email protected] Counsel for Energy Michigan Timothy J. Lundgren, Esq. Laura A. Chappelle, Esq. Varnum, LLP The Victor Center, Suite 910 201 North Washington Square Lansing, MI 48933 E-Mail: [email protected] [email protected] Toni L. Newell, Esq. Varnum, LLP 333 Bridge Street NW Grand Rapids, MI 49504 E-Mail: [email protected]

Counsel for Environmental Law & Policy Center Margrethe Kearney, Esq. Kristin Field, Legal Assistant Environmental Law & Policy Center 1514 Wealthy Street SE, Suite 256 Grand Rapids, MI 49506 E-Mail: [email protected] [email protected] Bradley Klein, Esq. Environmental Law & Policy Center 35 East Wacker Drive, Suite 1600 Chicago, IL 60601 E-Mail: [email protected] Counsel for Midwest Cogeneration Association John R. Liskey, Esq. John R. Liskey Attorney At Law PLLC 921 North Washington Avenue Lansing, MI 48906 E-Mail: [email protected] Patricia Sharkey, Esq. Environmental Law Counsel, P.C. 180 North LaSalle Street, Suite 3700 Chicago, IL 60601 E-Mail: [email protected]

ATTACHMENT A - force.com

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Transcript of ATTACHMENT A - force.com