Colorado’s State Default Intensity Verification Factor does more than adjust reported methane tonnage upward on paper. [1] It changes the verified emission total that CDPHE uses to evaluate intensity-target compliance, and that total drives compliance planning and enforcement exposure. The 2025 State Default factor of 1.164 adds 164 tons to the verified inventory for every 1,000 reported metric tons of CH₄. [2] Those 164 marginal tons matter in two ways, and both are worked through below. The first is a fee estimate. AQCC Regulation 3 assesses annual per-ton fees on criteria pollutants such as VOCs reported through the Air Pollutant Emission Notice (APEN) system. [3] Methane itself carries no Regulation 3 fee, so any fee-side impact runs through the VOCs co-emitted from the same equipment. [4] The second is compliance. Colorado’s methane intensity program measures verified CH₄ tons against production, so an upward adjustment moves operators closer to their intensity targets. [5] For a representative operator reporting 1,000 metric tons of CH₄ per year, assuming a 0.3 VOC:CH₄ co-emission ratio and the published $13.54-per-ton APEN fee for criteria pollutants, the fee estimate works out to roughly $670 per year. The derivation is below, step by step. [6] The analysis below puts numbers on both, with the intensity-target cost remaining unpriced due to enforcement discretion, building on our earlier post on how the Colorado Reg 7 verification factor works. [7]

Quick Answer: At the 2025 State Default factor of 1.164, each 1,000 reported metric tons of CH₄ generates 164 marginal verified tons. For a representative operator (1,000 t CH₄/yr reported, 0.3 VOC:CH₄ ratio, $13.54/t criteria-pollutant APEN fee), those tons correspond to roughly $670 per year in fee terms, if co-emitted VOC scaled with the verified methane adjustment. [8] The harder-to-price cost is compliance: the multiplier can move operators past their methane intensity targets, creating enforcement exposure that depends on CDPHE discretion.

How the Multiplier Converts Reported Tons Into Dollar Exposure

The cost calculation starts with the gap between what an operator reports and what CDPHE treats as verified. An operator reporting 1,000 metric tons of CH₄ annually with the 2025 State Default factor of 1.164 has a verified total of 1,164 metric tons. [9] That 164-ton gap is the multiplier’s cost basis. [10]

An Illustrative Regulation 3 Fee Calculation: Roughly $670 Per Year

AQCC Regulation 3 establishes Colorado’s emission fee schedule for criteria pollutants and hazardous air pollutants (HAPs) reported through the Air Pollutant Emission Notice (APEN) system. [11] Methane is not a criteria pollutant and carries no Regulation 3 fee. VOCs and HAPs co-emitted from the same sources are subject to Regulation 3 fees. [12]

Regulation 3 fees are assessed on APEN-reported emissions. [13] The verification factor adjusts a different number: the verified methane total used by the Regulation 7 intensity program. [14] Nothing in the factor’s terms changes the VOC tonnage an operator reports on its APENs. [15] So the calculation below is an illustrative proxy, not an automatic charge. It answers a narrower question: if the same measurement gap the factor represents also applied to co-emitted VOCs, what would that gap cost at current fee rates? Operators whose APEN VOC totals already reflect measured emissions would not see this charge from the multiplier alone.

CDPHE’s published APEN fee schedule assesses $13.54 per ton of criteria pollutants (which covers VOCs) and $90.34 per ton of non-criteria HAPs. [16] Methane and VOC emissions originate from common O&G source categories. Sources that emit both include storage tanks, pneumatic controllers, dehydrators, and well completions. [17]

Consider a representative operator: 1,000 reported metric tons of CH₄, VOC-to-methane ratio of approximately 0.3. [18] The multiplier’s marginal 164 tons of CH₄ implies roughly 49 tons of co-emitted VOCs. [19] At the published $13.54-per-ton criteria-pollutant fee, those 49 tons correspond to roughly $670 per year. [20] That is the fee estimate.

The Multiplier Can Push Operators Past Intensity Targets

The fee arithmetic is the visible, calculable number. The larger financial consideration for most operators is the intensity program itself. Colorado’s greenhouse gas intensity program under AQCC Regulation 7, Part B, requires operators to demonstrate progress against declining methane intensity targets, measured as verified CH₄ tons per unit of production. [21] An April 2026 revision to Regulation 7 (adopted February 20, 2026, effective April 14, 2026) shifted the intensity-target timeline for small operators, those under 45 kBOE of annual production, to a 2030 compliance target. Larger operators remain on the 2025-through-2029 targets. [22] Annual verification reports and intensity plan reports were due June 30, 2026 for applicable operators. [23]

The intensity calculation uses verified emissions, not reported emissions. [24] An operator whose reported intensity would meet the applicable target can exceed it after the multiplier is applied. Operators can replace the State Default factor with a lower operator-specific verification factor by qualifying a monitoring program. Missing an intensity target does not trigger an automatic per-ton penalty in the current rule structure. [25] CDPHE retains enforcement discretion. That authority can include compliance orders, penalty assessments under the Colorado Air Pollution Prevention and Control Act, and corrective action plans. [26]

No publicly documented case as of July 2026 identifies a specific penalty assessment by CDPHE solely for missing a methane intensity target under the Regulation 7 program. The absence of a published case does not mean the risk is zero. It means the risk is unpriced.

Sensitivity Analysis: What Different Multiplier Values Cost Per 1,000 Reported Tons

The 1.164 factor is the published 2025 value, not a permanent constant. [27] Operators planning multi-year budgets should model a range. Four multiplier scenarios are shown below, all based on 1,000 reported metric tons of CH₄. [28] Each row shows marginal tonnage, estimated VOC co-emission, and the fee value at the published rate. [29]

MultiplierVerified CH₄ (t)Marginal CH₄ from Multiplier (t)Est. Marginal VOC (t)Illustrative Fee at $13.54/t ($/yr)
1.051,0505015~$200
1.101,10010030~$410
1.1641,16416449~$670
1.201,20020060~$810

All figures are calculated from the stated multiplier applied to a 1,000 t CH₄ baseline and rounded to the nearest $10. [30] VOC estimates use a 0.3 VOC:CH₄ ratio. Fee values use the published $13.54/t criteria-pollutant APEN rate. [31]

The fee column is the calculable piece. [32] Each row also carries the intensity-target consideration described in the preceding section, scaling with the multiplier value. For operators near an intensity threshold, the difference between 1.10 and 1.164 is not a few hundred dollars per year. It is the difference between meeting and exceeding the target. Never miss an ONGAEIR or GHGRP deadline: subscribe for compliance updates and regulatory news.

Three Cost Categories Excluded From This Analysis

Staff costs, monitoring investment, and ESG disclosure impact are excluded from the figures above because they vary too widely across operators to model generically. Each category is real, and each scales with the multiplier.

Submission Preparation Adds Staff and Engineering Costs

Preparing and documenting an ONGAEIR submission that accounts for the multiplier requires staff time, internal data validation, and often third-party engineering support. Those costs are hard to generalize. For operators considering an operator-specific monitoring program to lower the effective multiplier, the upfront cost of program design, measurement procurement, and CDPHE approval adds capital and labor expense that the sensitivity table does not capture.

Lowering the Multiplier Requires Monitoring Investment

Operators pursuing a lower multiplier through an approved monitoring program will incur costs for continuous monitoring equipment, aerial survey contracts, or OGI inspection programs. Those costs vary widely by operator size, facility count, and chosen measurement technology. The range is wide.

Higher Verified Totals Flow Into Public ESG Disclosures

A higher verified emission total flows into any public disclosure that references Colorado-reported data, including OGMP 2.0 submissions, investor ESG reports, and supply-chain methane intensity certifications. The reputational cost of a 16.4% upward adjustment to verified methane is not quantifiable in a generic model. That number follows operators into public filings. Operators with public methane intensity commitments should expect scrutiny on the gap between reported and verified figures.

For operators evaluating whether to accept the State Default factor or pursue a lower operator-specific multiplier, our next post covers the mechanics and requirements of operator-specific monitoring programs. [33]

This post is for informational purposes only and does not constitute legal or compliance advice. Consult qualified legal counsel or a compliance professional for guidance specific to your operations and jurisdiction.

Frequently Asked Questions

Does the state default intensity verification factor apply to all ONGAEIR emission categories?

The State Default Intensity Verification Factor applies to the methane component of emissions reported under the ONGAEIR intensity framework in AQCC Regulation 7, Part B. [34] Not every emission category in an ONGAEIR submission is subject to the multiplier; it targets the methane intensity calculation specifically. [35] Operators should confirm which source categories and pollutants in their submission are affected by the factor in the current reporting year’s CDPHE guidance.

Can an operator reduce the state default verification factor without continuous monitoring?

The operator-specific verification factor pathway under Regulation 7, Part B does not require continuous monitoring exclusively. [36] Approved monitoring programs can include periodic aerial surveys or OGI inspections on defined schedules. Other measurement protocols that CDPHE accepts may also qualify. The requirements and approval process for these programs are the subject of the next post in this series. [33]

Has CDPHE published data on the distribution of reported methane tonnage across Colorado upstream operators?

CDPHE publishes aggregated ONGAEIR data, but operator-level methane tonnage distributions are not published in a single summary table as of July 2026. TetraSoft’s Colorado dataset covers 168,000+ wells, 59,000+ facilities, and 460,000+ equipment rows. [37] The dataset spans 48 counties with 4+ years of ONGAEIR data, providing facility-level and operator-level resolution. Operators seeking to benchmark their reported tonnage against peers can explore the TetraSoft Atlas Dashboard, a subscription platform, for facility-level Colorado emissions data. [38] Stay ahead of ONGAEIR deadlines and regulatory changes: sign up for the TetraSoft newsletter.

References

  1. Colorado Air Quality Control Commission, Regulation 7 (5 CCR 1001-9), Part B, Section VIII.F: Greenhouse Gas Intensity Verification (State Default Intensity Verification Factor, Section VIII.F.3.a). Colorado Department of Public Health and Environment.
  2. Colorado Air Quality Control Commission, Regulation 3 (5 CCR 1001-4): Stationary Source Permitting and Air Pollutant Emission Notice Requirements. Fee schedule provisions.
  3. Colorado Department of Public Health and Environment, Emissions and Permitting Fees (Air Pollution Control Division): APEN annual fee of $13.54 per ton of criteria pollutants and $90.34 per ton of non-criteria HAPs. Verified July 2026.
  4. Colorado Air Quality Control Commission, Regulation 7 revision adopted February 20, 2026 (effective April 14, 2026): EG OOOOc alignment and revised GHG intensity timeline for small operators (<45 kBOE/yr moved to a 2030 compliance target).
  5. Colorado Revised Statutes § 25-7-115: Powers and duties of the Air Quality Control Commission.
  6. Colorado Revised Statutes § 25-7-122: Enforcement; penalties; injunctions.
  7. Colorado Department of Public Health and Environment, Oil and Gas Greenhouse Gas Intensity Program page and ONGAEIR Reporting Guidance (current reporting year). Available at CDPHE Air Quality Division website.
  8. TetraSoft Colorado dataset: 168,000+ wells, 59,000+ facilities, 460,000+ equipment rows, 48 counties, 4+ years ONGAEIR data. Internal data asset.