Regulatory calendar

PJM's next BRA, scheduled for July 2026 as it returns to the three-year-forward schedule. Exact dates are set in PJM's RPM Auction Schedule.

Filed in the July 1-15 window (RSA 362-F:8 as amended by HB 2 sec. 112, effective 2023); Classes I-IV; NEPOOL GIS.

Within 30 days after Q4 NEPOOL GIS reports (no later than July 15); ACP to the Renewable Energy Development Fund; 810-RICR-40-05-2.

PCC1 = RPS-eligible generation interconnected to / scheduled into a CA balancing authority (bundled, delivered). Retail sellers (IOUs/ESPs/CCAs) file the Annual RPS Compliance Report by Aug 1 (D.12-06-038); measured over 3-year compliance periods; WREGIS-tracked; SB 100: 60% by 2030.

PCC2 = firmed-and-shaped / incremental electricity with substitute energy. Same Aug 1 CPUC Annual RPS Compliance Report (D.12-06-038); WREGIS-tracked.

PCC3 = unbundled RECs (TRECs) and products not qualifying as PCC1/PCC2 - the tradable category, subject to a procurement cap and portfolio-balance limits. Same Aug 1 CPUC Annual RPS Compliance Report (D.12-06-038).

Roughly five months after the annual report; confirm exact day on the CARB LCFS compliance calendar.

Distribution utilities file by Aug 31 (PUC Docket 8550); Tiers I/II met by retiring NEPOOL GIS RECs, plus Tier III energy transformation. No retail choice in VT.

Electric power suppliers file the forward compliance plan (Rule R8-67(b)) and prior-year compliance report (R8-67(c)) by Sept 1; retail-sales data entered into NC-RETS by June 1; IOU target 12.5%; expanded to CEPS by SL 2023-138; RECs tracked in NC-RETS.

Three-month true-up from the May 31 reporting-year close; after this the PUC verifies compliance and assesses ACP/SACP.

Identified as the likely 2025 compliance date in litigation over RIN expiry; confirm against EPA.

First-Wednesday quarterly pattern; confirm against Ecology's 2026 Summary of Expected Auction Dates.

Sept 9 per RGGI; Virginia's first auction since rejoining.

Standard-offer RPS obligation sits with Delmarva; transitional-contract RECs transfer to the standard offer by Aug 1 (90%) and Sep 1; 26 Del. Admin. C. 3008.

Annual report demonstrating Class I, Class II and solar (SREC-II/SuSI) compliance for the prior Energy Year; N.J.A.C. 14:8-2.2.

Due Oct 15 of the year following the compliance year (docket YEAR-06-01); Class I/II/III RECs settle via NEPOOL GIS by June 15.

Annual partial-surrender window; full true-up at the close of each compliance period.

Under Regulation (EU) 2025/1733 the 90% storage target may be met any time between 1 October and 1 December (replacing the former hard 1 November deadline), with limited deviations allowed; in force through 2027. 1 November shown as the reference benchmark.

Remaining obligation due at the close of each four-year compliance period.

EPA frequently misses this statutory date; treat as a target, not a fixed event.

ISO-NE expects to file CAR-SA with FERC in Q4 2026 (date provisional). The capacity market is moving to a prompt/seasonal design; the next capacity auction is delayed to about February 2028 for the commitment period beginning June 1, 2028.

Dec 2 per RGGI auction schedule.

First-Wednesday quarterly pattern; confirm against Ecology's 2026 Summary of Expected Auction Dates.

Increased-rate deadline follows in mid-February; CAD 110/t excess-emissions charge for 2026.

2027 cap ~69.8M tons (from 75.7M); CCR restructured, offsets removed. Completed Jul 3, 2025.

PJM announced a 2027/2028 Incremental Auction for February 2027; the exact date is set in the RPM Auction Schedule.

Annual four-year-ahead (T-4) and one-year-ahead (T-1) capacity auctions, typically held late February to early March; exact dates and parameters are set each cycle by DESNZ and NESO.

Typically end of February; confirm against the annual allocation timetable.

Early-March window, mirroring the 2025 interim cycle (transfer deadline Mar 2, 2026).

MISO accepts PRA offers in the last four business days of March and posts results in late April (April 28 in 2026). Seasonal accreditation applies; exact days vary.

Net emissions must be at or below baseline; compliance assessed as of 1 April.

Compliance period aligns with the calendar year; reports due on or before March 31.

HECO companies and KIUC file annual RPS status reports with the PUC under HRS 269-95; 100% by 2045 on a net-generation basis (Act 140, 2022). Islanded grids - no external REC trading market. Exact statutory filing date varies; approximate marker.

Maine PUC publishes its annual RPS report to the Legislature ~Mar 31 (35-A M.R.S. 3210); competitive electricity providers self-report and settle RECs via NEPOOL GIS. Exact CEP filing date set by PUC instructions.

Pay-as-you-go: LSEs remit monthly obligation payments to NYSERDA within 15 days of invoice; after the Jan 1-Dec 31 compliance year NYSERDA reconciles against final NYISO load. Annual reconciliation date varies; ZEC runs on a fiscal-year basis. Tracked in NYGATS.

Quarterly reports are due about 90 days after each quarter-end; March 31 is the Q4 deadline.

Due by April 1 of the year following the compliance year; high-value solar carve-out (DC SRECs); DCMR Title 15, Ch. 29.

On or before April 1 each supplier files its RPS report and retires Tier 1/Tier 1 solar/Tier 2 RECs; COMAR 20.61.04.02.

Investor-owned utilities (Ameren Missouri, Evergy, Empire) file annual RES compliance reports and forward compliance plans under 20 CSR 4240-20.100; 15% by 2021 with a 2% solar carve-out and a 1% rate-impact cap; RECs tracked in MRETS.

EDUs and CRES providers file by April 15; standard caps at 8.5% by 2026; OAC 4901:1-40-05.

Electric providers demonstrate compliance by April 15 by retiring RECs/RRCs in M-RETS; Wis. Stat. 196.378. Statewide 10% goal (2015) met; provider-specific baseline+6% requirements continue indefinitely.

Annual financial and operational report for major / non-major interstate natural gas pipelines; due April 18 of the following year under 18 CFR 260.1-260.2.

CC1 and CC3 credits are created on April 30 with this report; CI-Pathway Reports share this deadline.

LCFS-family April 30 standard; confirm on Oregon DEQ's CFP calendar. Quarterly progress reports are due about 90 days after each quarter-end.

A double-surrender easing applies for the 2026-2027 maritime years (both due 30 April 2028).

RECs for the prior compliance year retired in M-RETS by May 1; annual verification report (RES, Solar Energy Standard, Green Pricing) filed with the PUC by June 1. 2023 law: 55% renewable by 2035, 100% carbon-free by 2040; REC shelf life = generation year + 4.

Proceeding-based: Dominion (~May 1) and APCo (late April) file annual RPS development plans (Va. Code 56-585.5(D)); compliance demonstrated by retiring RECs every year via PJM-GATS; 100% by 2045 (Dominion) / 2050 (APCo); from 2025, 75% of Dominion's RECs must be Virginia-sited.

Federal OBPS now applies only in Manitoba, PEI, Yukon and Nunavut; most large emitters sit under provincial systems.

Approximate; confirm the exact Quebec reporting date.

Qualifying retail utilities (Xcel/Public Service, Black Hills) and wholesale utilities (Tri-State) file annual RES compliance reports under PUC Rule 3662 (4 CCR 723-3) ~June 1, plus forward compliance plans; 30% by 2020 (IOUs); SB19-236 clean-energy 80% by 2030 / 100% by 2050 goals; WREGIS-tracked. Exact date approximate.

Illinois RPS is procurement-based: the Illinois Power Agency procures RECs for ComEd/Ameren/MidAmerican via its Long-Term Plan (Illinois Shines/ABP). Per-supplier ARES REC obligations phased out after the 2018-19 delivery year. Indexed-REC procurements run on calendar years; other procurements on the delivery year.

IOUs and electricity service suppliers file by June 1 (ORS 469A); consumer-owned utilities report to their boards/members; RECs retired via WREGIS; ACP option under a 4% cost cap; large utilities 50% by 2040 (SB 1547). RPS Implementation Plan filed Jan 1 of even years.

Qualifying utilities report annually by June 1 (RCW 19.285); the 15% renewable target was met (2020). CETA (RCW 19.405) layers a 100%-clean-by-2045 obligation via 4-year Clean Energy Implementation Plans and multi-year compliance periods (first CETA interim performance report due July 1, 2026).

Generally June 1 following the compliance year; the exact year tracks the compliance-deadline timing.

Runs June 1 to July 31; held only if parties have unmet obligations (determined by May 15). Max price set by the first Monday of April.

Electric providers retire RECs in MIRECS at year-end and file annual compliance reports in their renewable-energy-plan dockets by June 30; PA 235 (2023): RPS 50% by 2030, 60% by 2035, Clean Energy Standard 100% by 2040; REP plans filed biennially.

Interstate oil pipeline rate ceilings adjust each July 1 by the FERC index (PPI-FG - 0.55% for the July 1, 2026 - June 30, 2031 term); FERC publishes the annual multiplier in May.

Covers RPS Class I/II, APS, CES and CPS; due July 1 (or next business day); 225 CMR 14.09/15.09/16.09.

Annual procurement plan and prior-year portfolio report filed on a staggered schedule (El Paso Electric May 1, PNM June 1, SPS July 1) under Rule 572 / 62-16-4 NMSA; ETA 2019: 50% by 2030, 80% by 2040, 100% carbon-free by 2045; WREGIS; RECs carry forward up to 4 years.

Providers of electric service file by July 1 (NRS 704.7825); 50% by 2030 / 100% carbon-free goal by 2050; portfolio energy credits (PECs); EE counts toward up to 10% (phasing out for 2025+).

Filed in the July 1-15 window (RSA 362-F:8 as amended by HB 2 sec. 112, effective 2023); Classes I-IV; NEPOOL GIS.

Within 30 days after Q4 NEPOOL GIS reports (no later than July 15); ACP to the Renewable Energy Development Fund; 810-RICR-40-05-2.

PCC1 = RPS-eligible generation interconnected to / scheduled into a CA balancing authority (bundled, delivered). Retail sellers (IOUs/ESPs/CCAs) file the Annual RPS Compliance Report by Aug 1 (D.12-06-038); measured over 3-year compliance periods; WREGIS-tracked; SB 100: 60% by 2030.

PCC2 = firmed-and-shaped / incremental electricity with substitute energy. Same Aug 1 CPUC Annual RPS Compliance Report (D.12-06-038); WREGIS-tracked.

PCC3 = unbundled RECs (TRECs) and products not qualifying as PCC1/PCC2 - the tradable category, subject to a procurement cap and portfolio-balance limits. Same Aug 1 CPUC Annual RPS Compliance Report (D.12-06-038).

Distribution utilities file by Aug 31 (PUC Docket 8550); Tiers I/II met by retiring NEPOOL GIS RECs, plus Tier III energy transformation. No retail choice in VT.

Electric power suppliers file the forward compliance plan (Rule R8-67(b)) and prior-year compliance report (R8-67(c)) by Sept 1; retail-sales data entered into NC-RETS by June 1; IOU target 12.5%; expanded to CEPS by SL 2023-138; RECs tracked in NC-RETS.

Three-month true-up from the May 31 reporting-year close; after this the PUC verifies compliance and assesses ACP/SACP.

Standard-offer RPS obligation sits with Delmarva; transitional-contract RECs transfer to the standard offer by Aug 1 (90%) and Sep 1; 26 Del. Admin. C. 3008.

Annual report demonstrating Class I, Class II and solar (SREC-II/SuSI) compliance for the prior Energy Year; N.J.A.C. 14:8-2.2.

Due Oct 15 of the year following the compliance year (docket YEAR-06-01); Class I/II/III RECs settle via NEPOOL GIS by June 15.

Annual partial-surrender window; full true-up at the close of each compliance period.

Under Regulation (EU) 2025/1733 the 90% storage target may be met any time between 1 October and 1 December (replacing the former hard 1 November deadline), with limited deviations allowed; in force through 2027. 1 November shown as the reference benchmark.

Allowances due by November following the end of the compliance period; confirm exact date.

Remaining obligation due at the close of each four-year compliance period.

EPA frequently misses this statutory date; treat as a target, not a fixed event.

Increased-rate deadline follows in mid-February; CAD 110/t excess-emissions charge for 2026.