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HF 4874

Electric cooperatives and municipal utilities; recovery of fixed costs clarified with respect to net metered facilities, meter aggregation allowed for electric cooperatives and municipal utilities, commission authority clarified with respect to electric cooperative practices, member access to cooperative documents and meetings improved, and electronic voting and voting by mail required for cooperative board directors.

2025-2026 Regular Session Introduced by Ned Carroll and 5 co-sponsors

Defines fixed-cost recovery for net-metered facilities and allows meter aggregation for cooperatives and municipal utilities.

Introduction and first reading, referred to Energy Finance and Policy
#cooperatives #energy #publicutilitiesandpublicutilitiescommission
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Bill Summary · HF 4874

Summary of HF 4874 (2025-2026) – Minnesota

Aimed at electric cooperatives and municipal utilities, HF 4874 clarifies fixed-cost recovery for net metered facilities, introduces meter aggregation for cooperatives and utilities, clarifies commission authority over cooperative practices, enhances member access to cooperative information, and requires electronic voting and voting-by-mail for cooperative board elections. Effective dates: immediate for most provisions; specific rollout for board election provisions.

1) Main purpose and intent

  • Provide clarity on how fixed costs are recovered from net metering customers served by electric cooperatives and municipal utilities.
  • Allow meter aggregation (combining multiple meters for net metering) for cooperatives and municipal utilities.
  • Clarify Minnesota Public Utilities Commission authority over cooperative practices.
  • Improve member access to cooperative governance documents and meetings.
  • Establish electronic voting and voting-by-mail requirements for cooperative board director elections, with phased timeline.

2) Key provisions and changes

A. Fixed costs recovery for net metering (Sec. 1)

  • Applies to cooperative electric associations and municipal utilities (and public utilities with different thresholds).
  • For net-metered facilities:
    • If the facility is less than 40 kW (cooperatives/municipal utilities): customer may be billed for net energy; utility may add an additional charge to recover fixed costs not covered by existing billing. However, fixed-cost recovery via other means is prohibited. Additional charges must be reasonable and based on the most recent cost-of-service study, which must be available upon request.
    • For net input (generation into the system) of less than 40 kW, compensation can be at the per-kWh rate determined under specified subparagraphs (c, d, or f).
  • For public utilities (broad utilities, including larger net-metered facilities):
    • For 1 kW to <1,000 kW facilities, compensation determined under subparagraphs (c) or (f) depending on size.
    • For net input under 1,000 kW, compensation details mirror the small-facility approach but with public-utility-specific rates.
  • Subparagraphs (c) and (d) set the framework for rate setting, avoidance costs, and options for facilities under 40 kW to elect average retail energy rate.
  • Interconnections to nongenerating utilities and options to be governed by subdivision 4 are addressed (e).
  • Economic protections: rates must consider fixed distribution costs not otherwise captured elsewhere and avoid discriminatory treatment.

Effective date: day after final enactment.

B. Aggregation of meters (Sec. 2)

  • Allows aggregation of a customer-designated meter with one or more aggregated meters for billing, with ownership and contiguity requirements.
  • Customer-generator can request aggregation within 90 days; rank-order for applying net metered credits can be adjusted, with a 60-day lead-time prior to the next annual billing period.
  • Aggregation applies only to kilowatt-hour-based charges; other charges stay with their respective meters.
  • Credits apply first to the designated meter, then to aggregated meters in rank order; any excess credits roll to the next month.
  • Cooperative may charge a reasonable administrative fee for implementing aggregation, subject to commission approval if via tariff.

Effective date: day after final enactment.

C. Commission authority – cooperative practices (Sec. 3)

  • Clarifies that “cooperative electric associations” are included within the scope of this section, ensuring applicable service standards, practices, terms, conditions, and policies cover cooperatives.

Effective date: day after final enactment.

D. Transparency, elections, and governance (Sec. 4)

  • Open board meetings: Regular or special board meetings must be open to all members, with reasonable notice. Closed sessions allowed for specified reasons (personnel, legal privilege, or protection of competitive/financial position and confidential information).
  • Remote participation: Cooperatives must provide remote participation options so members can attend and participate.
  • Access to documents (Subd. 2):
    • Required online access to key cooperative documents: articles of incorporation, bylaws, board minutes, annual reports, IRS Form 990, audited financials, and, if applicable, nonconfidential subsidiary information.
    • Access to meeting dates, board contact information, how to vote in board elections, and the most recent voting statistics (including proxy votes).
  • Access to membership list (Subd. 3):
    • Members may request a list of all members, with limits: good faith request, purpose tied to member interest, prohibition on commercial use, and potential affidavit requirements to assure proper use and damages for misuse.
    • Defines “membership list” as names, addresses, phone numbers, and emails of all members.
  • Board nominations (Subd. 4): A candidate may be nominated by a petition signed by at least 40 members.
  • Board elections; voting (Subd. 5):
    • Requires the cooperative to develop a secure ballot system that preserves secrecy while allowing mail and Internet voting.
  • Capital credits notification (Subd. 6):
    • Annual notice to each member of the prior year’s capital credit allocation.
    • Members may request a calculation of cumulative unretired capital credits, with a 45-day response window.
    • Defines “capital credit allocation” as each member’s share of surplus revenues over costs, allocated by contributed revenue.

Effective date: day after final enactment; Subd. 5 (board elections) applies to elections held on or after September 1, 2026.

3) Who/what would be affected

  • Electric cooperatives and municipal utilities operating in Minnesota.
  • Cooperative members (ratepayers) who participate in net metering or aggregation programs.
  • Members seeking governance information and participation in meetings/elections.
  • Cooperative boards and election processes (nominations, voting, capital credits reporting).

4) Procedural/timeline considerations

  • Immediate effect for most sections (effective the day after final enactment).
  • Board elections governance provisions (Subd. 5) apply to elections held on or after September 1, 2026.
  • Aggregation rules and fixed-cost recovery provisions are designed to align with cost-of-service considerations and public utility rate-setting processes.
  • Members gain enhanced access to information and the ability to participate remotely in board meetings.

5) Potential impacts to monitor

  • Utility rate practices: clarity on fixed-cost recovery could affect net-metering compensation and total bills for small facilities.
  • Net metering economics: options for 40 kW threshold facilities to elect average retail rates may influence project economics.
  • Meter aggregation: administrative feasibility and any fee structures approved by the commission.
  • Governance transparency: cost and administrative burden of expanded document access and online voting systems.
  • Election integrity: security of mail/Internet voting systems and response times for capital credit data requests.

Compiled from official sources — confirm details with the bill’s official record.

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