Key Updates
Colorado adopted an April 2026 revision to Regulation Number 7, Control of Emissions from Oil and Gas Operations, updating oil and gas air emissions requirements to align with the US Environmental Protection Agency’s (EPA) Emissions Guidelines (EG) OOOOc and revising greenhouse gas operator intensity timelines for small operators. The rule was adopted on February 20, 2026, and became effective April 14, 2026.
Colorado revised Regulation Number 7 (Regulation 7) to align with EPA EG OOOOc requirements for existing crude oil and natural gas facilities. Updates address compressor requirements, wellhead only Leak Detection and Repair (LDAR) definitions, transmission and storage cross references, and gas plant LDAR provisions.
The rule also revises the greenhouse gas intensity compliance timeline for small operators. Operators with less than 45 kBOE of annual production now have a 2030 compliance target, while operators above this threshold remain subject to the existing 2025 through 2029 targets.
Operators should confirm whether facility classifications have changed under updated Regulation 7 definitions, particularly for wellhead only and centralized well production facilities. Compressor compliance pathways should be reviewed against the OOOOc aligned flow rate requirements and assumptions related to closed vent systems.
Small operators should update greenhouse gas compliance planning to account for the revised 2030 intensity targets, while larger operators should continue planning against the existing 2025 through 2029 schedule.
Delve Deeper
EG OOOOc Updates in Colorado Regulation 7
EPA finalized EG OOOOc in March 2024, establishing emission guidelines for existing crude oil and natural gas facilities. States were given the option to rely on the federal implementation plan (FIP) or to develop a state implementation plan (SIP) for the purpose of retaining regulatory primacy.
Because Colorado Regulation Number 7 already applies to the designated facility categories covered under EG OOOOc, the state elected to submit a SIP rather than rely on the FIP. However, certain provisions in Regulation 7 did not fully align with the federal requirements, which prompted targeted revisions. The adopted updates clarify and refine requirements related to compressors, wellhead only LDAR definitions, transmission and storage segment equipment, and LDAR obligations at natural gas processing plants. These are discussed in detail by source category below:
Wellhead-only LDAR (Leak Detection and Repair)
Because Regulation 7 requires wellhead-only LDAR, this update did not add new LDAR monitoring frequencies, rather it clarifies facility-type definitions. Colorado updated the “wellhead-only well production facility” definition to clarify which operators are subject to Regulation 7 LDAR requirements in addition to OOOOc. The following Regulation 7 key definitions apply:
“Well Production Facility” means all equipment at a single stationary source directly associated with one or more oil wells or natural gas wells upstream of the natural gas processing plant. This equipment includes, but is not limited to equipment used for storage, separation, treating, dehydration, artificial lift, combustion, compression, pumping, metering, monitoring, and flowline.
“Wellhead Only Well Production Facility” means a well production facility that has only equipment for a wellhead, including piping, casing, tubing, and/or connected valves protruding above the earth’s surface, and does not include other production or processing equipment used for storage, separation, treating, dehydration, combustion, compression, process control (if natural gas-driven), and pumping.
Compressor Requirements (Centrifugal and Reciprocating)
EG OOOOc requires wet seal centrifugal, dry seal centrifugal, and reciprocating compressors to maintain seal and cylinder emissions below specified volumetric flow rate limits. Colorado adopted those flow rate limits to align Regulation Number 7 with the federal standard. Methane emissions requirements for compressors become applicable on the earlier of either: (1) January 1, 2027, or (2) twelve months after EPA approves Colorado’s Clean Air Act Section 111(d) Plan for Crude Oil and Natural Gas Facilities. The state also removed a prior requirement for closed vent systems to operate under negative pressure, noting that normal compressor operation inherently creates a sufficient pressure differential.
EG OOOOc provides exemptions from centrifugal and reciprocating compressor requirements for compressors located at well sites that are not centralized production facilities. Based on the federal definition of centralized production facility and the existing Regulation Number 7 definition of well production facility, Colorado considers a centralized production facility to be a type of well production facility. This approach is consistent with how wellhead only well production facilities are treated as a subset of well production facilities under the regulation. To support this interpretation, Colorado adopted a new definition for centralized well production facility: “Centralized Well Production Facility” means all equipment located at a well production facility that includes one or more storage vessels and all equipment used to gather, for the purpose of sale or processing to sell, crude oil, condensate, produced water, or intermediate hydrocarbon liquid from one or more natural gas or oil production wells located at a separate surface site that is more than 0.25 miles away from the edge of the facility.
Colorado adopted the EG OOOOc exemptions for compressors located at well production facilities, except where a facility meets the adopted definition of a centralized well production facility. Under this framework, a well production facility that gathers production only from wells located at its own surface site is not considered a centralized well production facility.
Transmission and Storage Segment Requirements
Under EG OOOOc, the transmission and storage segment is subject to requirements for storage vessels, compressors, pneumatic devices, and fugitive emissions from regulated components. Colorado implemented these requirements by cross referencing Regulation Number 7 Part B, Sections II and III, allowing them to apply to the transmission and storage segment without making that segment independently subject to all provisions of those sections. The state also clarified that compliance with the methane control requirements can effectively achieve corresponding VOC emission control objectives.
Beginning May 1, 2026, owners and operators of transmission and storage segment natural gas compressor stations located in northern Weld County AND emit or have the potential to emit ≥ 50 tons per year of VOCs, must conduct quarterly LDAR inspections using an approved instrument monitoring method.
Gas Processing Plant LDAR (Optical Gas Imaging and Method 21)
Colorado has required natural gas processing plants to comply with NSPS LDAR requirements statewide since 2023. Early requirements were based on NSPS KKK, which incorporates LDAR provisions from NSPS VV, and were later updated to require compliance with NSPS OOOO or OOOOa, which incorporate LDAR requirements from NSPS VVa.
Following EPA’s adoption of Appendix K to 40 CFR Part 60 and its incorporation into EG OOOOc, Colorado updated Regulation Number 7 to require LDAR provisions for natural gas processing plants that align with OOOOc. This approach specifies the use of Appendix K for optical gas imaging, with Method 21 retained as an alternative monitoring option.
In adopting EPA’s definition of low‑e packing, the Commission clarified that meeting the definition and associated material specifications does not by itself require use of a drill‑and‑tap repair method.
“Low-e packing” means a valve packing product for which the manufacturer has issued a written warranty or performance guarantee that it will not emit fugitives at greater than 100 ppm in the first five years after installation. Low-e injectable packing is a type of low-e packing product for which the manufacturer has also issued a written warranty or performance guarantee and that can be injected into a valve during a “drill-and-tap” repair of the valve.
When the New Requirements Take Effect
The new OOOOc-modeled LDAR program for gas plant process unit equipment becomes applicable on the earlier of: January 1, 2027, or twelve months after EPA approves Colorado’s Clean Air Act Section 111(d) Plan for Crude Oil and Natural Gas Facilities.
Until that trigger date, most gas plants continue to comply under existing NSPS OOOO or OOOOa LDAR programs, as incorporated into Regulation 7.
Colorado Greenhouse Gas (GHG) Operator Intensity Updates
In December 2021, Colorado adopted amendments to Regulation 7 to add greenhouse gas (GHG) emission reduction targets for the oil and gas sector, including GHG intensity targets for upstream operations. The April 2026 update revises the intensity target timeline for small operators, providing additional time to identify and implement compliance strategies. Specifically, Colorado shifted the 2025–2029 intensity targets for small operators out to 2030. These revisions apply to operators with less than 45 kBOE of hydrocarbon and natural gas production in a calendar year. Operators with greater than 45 kBOE remain subject to the existing 2025–2029 intensity targets. Because intensity targets step down over time, some operators may need to achieve larger emission reductions in a shorter timeframe to meet the 2030 targets compared to the earlier stepdown schedule.
As a reference point, 45 kBOE per year is equivalent to approximately 123 barrels of oil per day or 715 thousand cubic feet of gas per day. In some cases, a single horizontal well, even when performing below type curve, may exceed this threshold. The greenhouse gas intensity targets rely on production volume as the denominator. When production is constrained by factors such as limited operating windows or midstream takeaway capacity, operators may appear disproportionately noncompliant despite relatively modest emissions.
Conclusion
Colorado’s April 2026 revision to Regulation Number 7 updates air emissions requirements to align with EPA EG OOOOc and refines how those requirements apply across existing oil and gas operations. Key updates include clarifying wellhead-only LDAR applicability, incorporating compressor flow rate standards, addressing transmission and storage segment requirements through cross references, and adopting OOOOc-aligned LDAR provisions for natural gas processing plants.
The rule also revises greenhouse gas intensity timelines for small operators, extending compliance to 2030 for those below the 45 kBOE annual production threshold, while maintaining the existing 2025 through 2029 schedule for larger operators.
As these updates are implemented, operators should review facility classifications, confirm applicability of revised definitions and exemptions, and align compliance planning with applicable timing triggers and updated requirements.
