Public Works and Utilities Committee Agenda & Packet (PDF)

MEETING AGENDA PUBLIC WORKS & UTILITIES COMMITTEE OF THE PLYMOUTH COMMON COUNCIL CITY OF PLYMOUTH, WISCONSIN TUESDAY, SEPTEMBER 8, 2026 TO BEGIN IMMEDIATELY AFTER THE FINANCE & PERSONNEL COMMITTEE MEETING THAT BEGINS AT 6:00 PM Plymouth City Hall Council Chambers Plymouth, WI 53073 1. Call to Order & Roll Call 2. Approval of August 11, 2026 Meeting Minutes 3. Presentation and Discussion on Parallel Generation Tariff Filing with WPPI 4. Adjournment It is likely a quorum of members of other governmental bodies of the municipality may be in attendance at the above stated meeting to gather information. No action will be taken by any governmental body at the above stated meeting other than the governmen tal body specifically referred to above in this notice. Please note that, upon reasonable notice, efforts will be made to accommodate the needs of disabled individuals through appro priate aids and services. For additional information or to request this service, please contact the City of Plymouth Clerk’s Offic e, located at Plymouth City Hall at 128 Smith St., Plymouth, WI or call (920) 893-1271. Members Present: ____ Mayor Don Pohlman ____ John Binder ____ Dana Haucke ____ Dave Herrmann ____ Kevin Sande (Chair) Staff: ____ Anna Voigt ____Tim Blakeslee Other: PUBLIC WORKS & UTILITIES COMMITTEE OF THE PLYMOUTH COMMON COUNCIL CITY OF PLYMOUTH, WISCONSIN TUESDAY, AUGUST 11, 2026 @ 6:00 PM Plymouth City Hall Council Chambers Plymouth, WI 53073 UNOFFICIAL MINUTES 1. Call to Order & Roll Call: Acting Chairperson Mayor Pohlman called the meeting to order at 6:00 PM. Upon the call of the roll, the following members were present: Mayor Don Pohlman, John Binder, Dana Haucke, and Kevin Sande (Dave Herrmann arrived at 6:09 PM). Others present were City Administrator/Utilities Manager Tim Blakeslee and Assistant City Administrator/Community Development Director Jack Johnston, Fire Chief Jim Klug, Police Chief Ken Ruggles, Assistant Police Chief Matt Starker. 2. Approval of February 10, 2026 Meeting Minutes: Motion was made by Binder/Haucke to approve the minutes from February 10, 2026. Upon the call of the roll, all voted aye. Motion carried. 3. Election of Committee Chair: Binder nominated Sande as chairperson. Sande confirmed he would accept the position if elected. No other nominations were made. Motion was made for a unanimous ballot by Hauke/Binder. Motion carried. 4. Outage Management Presentation: Nick Whipple, the Assistant Electric Operations Manager, presented the Outage Management presentation for the Committee of the Whole. 5. Adjournment: Motion was made by Pohlman/Binder to adjourn the meeting. A unanimous aye vote was cast. Motion carried. City of Plymouth 128 Smith St. - P.O. Box 107 Plymouth, WI 53073-0107 Telephone: (920) 893-1271 Facsimile: (920) 893-0183 Web Site: plymouthgov.com DATE: September 8, 2026 TO: Public Works and Utilities Committee FROM: Christopher Russo, Finance Director RE: Presentation and Discussion on Parallel Generation Tariff Filing with WPPI Background: Staff is recommending Plymouth Utilities join the WPPI group tariff filing with the Public Service Commission of Wisconsin (PSCW) to update the Parallel Generation (Pgs) tariffs. This group filing with WPPI will update the excess generation rates for the Pgs-1 and Pgs-2 tariffs to a MISO market based avoided cost rate. The updates aim to protect non-Pgs tariff ratepayers who have been supplementing the current excess generation rates. Presentation to follow. Recommendation: Direction to present to Common Council for approval on Parallel Generation Tariff Filing with WPPI Plymouth Utilities Pgs - Avoided Cost Parallel Generation Tariff Update Tom Boldt Energy Services Manager, WPPI Energy Christopher Russo Finance Director, Plymouth Utilities Parallel Generation Background wppienergy.org 2 Sturgeon Bay filed on July 14, 2023 RENEW Wisconsin filed to intervene New schedules effective July 1, 2026 Modeled after PSC approved IOU parallel generation schedules Parallel Generation • Pgs-1 Monthly net metered customers Systems less than 20 kW Excess generation credited at avoided cost • MISO market based • Incentive to size system to load • Protects non-Pgs ratepayers (Existing customers on Pgs tariff grandfathered for 10 years) wppienergy.org 3 Parallel Generation • Pgs-2 Systems greater than or equal to 20 kW Excess generation credit rate updated quarterly (previously yearly) • MISO market based avoided cost Existing customers not grandfathered wppienergy.org 4 Parallel Generation Next Steps wppienergy.org 5 Multi-utility filing in October 27 WPPI members currently in the group filing Simplified filing process Full PSC Commission will decide Expect effective date mid first quarter 2027 wppienergy.org 6 Questions? RATE FILE Sheet No. 1 of 2 Schedule No. Pgs-1 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Parallel Generation (20 kW or less) -- Net Energy Billing EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 1. Effective In All territories served by the utility. 2. Availability Available for single-phase and three-phase customers generating power using renewable resource generators that satisfy the requirements of “qualifying facility” status under Part 292 of the Federal Energy Regulatory Commission’s regulations under the Public Utility Regulatory Policies Act of 1978 where a part or all of the electrical requirements of the customer are supplied by the customer’s generating facilities located behind-the-meter (BTM) on the customer’s premises, where such facilities have a total generating capability of 20 kW alternating current (AC) or less, where such facilities are connected in parallel with the utility and where such facilities are approved by the utility. 3. Rate The customer shall be billed monthly on a net energy basis and shall pay the customer charge and energy charge(s) specified in the rate schedule under which the customer is served. When the energy produced exceeds energy consumed for the billing month, the customer shall be credited for the excess energy volumes at the energy credit component (multiplied by the loss factor) specified for BTM COGS in the utility’s Pgs-2 rate schedule, unless the customer qualifies for the rate described in the next paragraph. The buy-back energy rates will be reset annually for billing on or after February 1 of each year based on the most recent three-year average locational marginal price of energy in MISO at the WEC.WPPI commercial pricing node. The following customers will continue to be credited for net monthly excess generation at the energy rate specified in the rate schedule under which the customer purchases energy, including the monthly power cost adjustment clause (PCAC), until April 30, 2036: a) customers taking service under this rate schedule prior to April 6, 2026;. A customer that makes changes to the capacity or type of its generation facilities after April 6, 2026 will be treated as a new customer and shall be subject to the standard avoided cost rate. If, in any month, the customer’s bill has a credit balance of $100 or less, the amount shall be credited to subsequent bills until a debit balance is reestablished. If the credit balance is more than $100, the utility shall reimburse the customer by check upon request. Monthly credits shall be computed by taking the net excess kilowatt-hours produced times the applicable energy charge. RATE FILE Sheet No. 2 of 2 Schedule No. Pgs-1 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Parallel Generation (20 kW or less) -- Net Energy Billing EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 4. Metering and Services Facilities A customer who is served under a regular rate schedule shall have any ratchet and/or other device removed from the meter to allow reverse power flow and measurement of net energy used. Customers eligible for net energy billing but with existing metering facilities equipped with ratchets or other devices preventing reverse registration (i.e. time-of-use metering facilities) may request that the utility install the necessary metering to permit such billing. Non-Standard Meter Service, if any, is not available for customers electing the Pgs-1 Schedule. 5. Customer Obligation See Wis. Admin. Code ch. PSC 119; Rules for Interconnecting Distributed Generation Facilities. 6. Renewable Energy Credits and Benefits All renewable energy credits and benefits, emissions allowances, or other renewable energy, air emissions, or environmental benefits for which the customer’s generation system qualifies under any existing or future applicable law shall remain the property of the customer. RATE FILE Sheet No. 1 of 6 Schedule No. Pgs-2 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Customer-Owned Generation Systems (Greater than 20 kW) EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 1. Effective In All territories served by the utility. 2. Availability Available for single-phase and three-phase customers generating power using renewable resource generators that satisfy the requirements of “qualifying facility” status under Part 292 of the Federal Energy Regulatory Commission’s regulations under the Public Utility Regulatory Policies Act of 1978 who desire to sell excess generation to the utility from behind-the-meter (BTM) customer-owned generation systems (COGS), or who sell all generation to the utility from front-of-the-meter (FTM) COGS. For BTM COGS, a part or all of the electrical requirements of the customer are supplied by the COGS located on the customer’s premises. For FTM COGS, all of the generation is sold to the utility under an executed service agreement between the COGS and the utility, and all of the customer’s electricity usage is supplied separately by the utility under applicable retail service schedules. In either case, BTM or FTM, such facilities shall have a total generating capability of greater than 20 kW and less than or equal to 5 MW alternating current (AC), with such facilities connected in parallel with the utility, and where such facilities are approved by the utility. Customers not desiring to sell energy under this rate have the right to negotiate a buy-back rate. If, in lieu of taking service under this rate schedule, a customer elects to sell their excess generation to another utility or into the market administered by the Midcontinent Independent System Operator, Inc. (MISO) the utility shall transport the customer’s excess generation across the utility’s distribution system and shall recover actual costs of such transportation from the generating customer. 3. Rate Unless separately negotiated in accordance with paragraph 7 of this rate schedule, the utility shall, for all energy sold to the utility, credit the COGS at the applicable avoided cost rate specified below. The avoided cost rates will be reset annually for billing on or after February 1 of each year to reflect the then current value of each component shown in the table below: a. For BTM COGS: Customers shall receive monthly payments equal to the sum of the excess energy volume (in kWh) in each On-Peak Hour of the month multiplied by the seasonal on- peak buy-back rate plus the sum of the excess energy volume (in kWh) in each Off- Peak Hour of the month multiplied by the seasonal off-peak buy-back rate. The following table shows the components of these rates. RATE FILE Sheet No. 2 of 6 Schedule No. Pgs-2 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Customer-Owned Generation Systems (Greater than 20 kW) EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 WINTER (December through February) Component On-Peak Off-Peak Energy Credit $0.0431/kWh $0.0358/kWh Capacity Credit $0.0005/kWh $0.0000/kWh Transmission Credit $0.0000/kWh $0.0000/kWh Sub-Total $0.0435/kWh $0.0358/kWh x Loss Factor 1.03 1.03 Total Buy-Back Rate $0.0448/kWh $0.0369/kWh SPRING (March through May) Component On-Peak Off-Peak Energy Credit $0.0298/kWh $0.0241/kWh Capacity Credit $0.0061/kWh $0.0000/kWh Transmission Credit $0.0000/kWh $0.0000/kWh Sub-Total $0.0359/kWh $0.0241/kWh X Loss Factor 1.03 1.03 Total Buy-Back Rate $0.0370/kWh $0.0249/kWh SUMMER (June through August) Component On-Peak Off-Peak Energy Credit $0.0523/kWh $0.0299/kWh Capacity Credit $0.0328/kWh $0.0000/kWh Transmission Credit $0.0000/kWh $0.0000/kWh Sub-Total $0.0851/kWh $0.0299/kWh X Loss Factor 1.03 1.03 Total Buy-Back Rate $0.0876/kWh $0.0308/kWh FALL (September through November) Component On-Peak Off-Peak Energy Credit $0.0394/kWh $0.0282/kWh Capacity Credit $0.0099/kWh $0.0000/kWh Transmission Credit $0.0000/kWh $0.0000/kWh Sub-Total $0.0493/kWh $0.0282/kWh X Loss Factor 1.03 1.03 Total Buy-Back Rate $0.0508/kWh $0.0291/kWh RATE FILE Sheet No. 3 of 6 Schedule No. Pgs-2 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Customer-Owned Generation Systems (Greater than 20 kW) EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 For BTM COGS, both the Energy Credit and the Capacity Credit will be based on seasonal historical averages. The Energy Credit will be reset annually based on the most recent three-year average locational marginal price of energy in MISO at the WEC.WPPI commercial pricing node. The Capacity Credit will likewise be reset based on the most recent three-year average annual capacity clearing price in the MISO Planning Resource Auction. b. For FTM COGS: Customers shall enter into a service agreement with the utility and shall receive monthly payments equal to: [FTM Energy Credit + FTM Capacity Credit + FTM Trans Credit] x DLF Where: FTM Energy Credit = the sum of the energy produced by the FTM COGS (in kWh) in each On-Peak Hour of the month multiplied by the seasonal on-peak Energy Credit rate, plus the sum of the energy produced by the FTM COGS in each Off-Peak Hour of the month multiplied by the seasonal off-peak Energy Credit rate. The seasonal FTM Energy Credit rates are equal to the Energy Credit components specified in the table for BTM COGS and will be updated annually as described there. FTM Capacity Credit = (1/12) x (Applicable Net CONE) x (Cap of FTM COGS) Applicable Net CONE = MISO’s Net Cost of New Entry (specified in $/kW-year) effective when the FTM COGS and utility enter into a 10- year service agreement, subject to extension in 5 year increments at the end of the initial term and each subsequent term. Net CONE shall be updated upon any extension. Cap of FTM COGS = MISO’s accredited capacity amount (in kW) then effective for the FTM COGS at the time of the service agreement or any extension thereof. FTM Trans Credit = $0 DLF (Distribution Loss Factor) = 1.03 RATE FILE Sheet No. 4 of 6 Schedule No. Pgs-2 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Customer-Owned Generation Systems (Greater than 20 kW) EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 4. On-Peak and Off-Peak Hours and Holidays On-Peak Hours: 8:00 a.m. – 8:00 p.m., Central Prevailing Time, Monday through Friday, excluding Holidays. Off-Peak Hours: All hours that are not On-Peak Hours. Holidays: New Year’s Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day, and Christmas Day, or the date celebrated as such. 5. Minimum Charge The monthly minimum charge paid by the customer shall be the customer charge. 6. Power Factor The customer shall maintain a minimum power factor as specified in Wis. Stats. Chapter PSC 119.20 (7). 7. Negotiated Rates Customers with generation systems greater than 20 kW have the right to negotiate a buy-back rate. The buy-back rate cannot be greater than the full avoided cost. The following are the required procedure guidelines: a. The utility must respond to the customer-owned generating system within 30 days of the initial written receipt of the customer-owned generating system proposal and within 30 days of receipt of a subsequent customer-owned generating system proposal, b. The utility’s rejection of the customer-owned generating system proposal must be accompanied by a counter-offer relating to the specific subject matter of the customer- owned generating system proposal, and c. If the utility is unable to respond to the customer-owned generating system proposal within 30 days it shall inform the customer-owned generating system of: 1) Specific information needed to evaluate the customer-owned generating system proposal. 2) The precise difficulty encountered in evaluating the customer-owned generating system proposal. 3) The estimated date that it will respond to the customer-owned generating system proposal. RATE FILE Sheet No. 5 of 6 Schedule No. Pgs-2 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Customer-Owned Generation Systems (Greater than 20 kW) EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 d. The Commission may become involved in the utility negotiations upon showing by either the utility or the COGS that a reasonable conclusion cannot be reached under the above guidelines. The Commission may provide a waiver to the guidelines and order new negotiation requirements so that a reasonable conclusion can be reached. e. A copy of all negotiated buy-back rates shall be sent to the Commission. These rates shall not be effective until the contract is placed on file at the Commission. 8. Charges for Energy Supplied by the Utility Energy supplied by the utility to the customer shall be billed in accordance with the rate schedules of the utility under which the customer is served. 9. Maintenance Rate A customer-owned generation facility may be billed lower demand charges for energy purchased during scheduled maintenance provided written approval is obtained in advance from the utility. Demand charges other than “Distribution Demand” shall be prorated if maintenance is scheduled such that the utility does not incur additional capacity costs. Such prorated demand charges shall be calculated as the demand charge rate times (the number of days in the billing period minus the number of authorized days of scheduled maintenance), divided by the number of days in the billing period. 10. Application Process and Customer Obligation See Wis. Admin. Code ch. PSC 119, Rules for Interconnecting Distributed Generation Facilities. 11. Utility Obligation a. Metering Facilities The utility shall install appropriate metering facilities to record all flows of energy necessary to bill in accordance with the charges and credits of the rate schedule. To the extent that the utility determines a separate meter is required for the generator, the utility will charge a monthly meter charge of $8.00 for such meter. Non-Standard Metering service is not available for customer metering under this schedule. b. Notice to Communication Firms Each electric utility shall notify telephone utility and cable television firms in the area when it knows that a customer-owned generating facility is to be interconnected with its RATE FILE Sheet No. 6 of 6 Schedule No. Pgs-2 Public Service Commission of Wisconsin Amendment No. 99 STURGEON BAY ELECTRIC UTILITY Customer-Owned Generation Systems (Greater than 20 kW) EFFECTIVE: July 1, 2026 PSCW AUTHORIZATION: Final Decision in Docket 5780-TE-111 issued April 6, 2026 system. This notification shall be as early as practicable to permit coordinated analysis and testing in advance of interconnection, if considered necessary by the electric or telephone utility or cable television firm. 12. Right to Appeal The owner of the generating facility interconnected or proposed to be interconnected with a utility system may appeal to the Commission should any requirement of the utility service rules filed in accordance with the provisions of Wis. Admin. Code § PSC 119.40, or the required contract be considered to be excessive or unreasonable. Such appeal will be reviewed and the customer notified of the Commission’s determination. 13. Renewable Energy Credits and Benefits All renewable energy credits and benefits, emissions allowances, or other renewable energy, air emissions, or environmental benefits for which the customer’s generation system qualifies under any existing or future applicable law shall remain the property of the customer.