The EPA Wants to Scrap the Program That Lets Anyone Report Giant Methane Leaks. The Oil Industry Sends Its Regards.
By Dakota Jones
Desk: Political & Government, Public Policy & Regulatory
Date: November 2, 2026
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The Environmental Protection Agency has proposed a broad rewrite of federal methane rules for oil and gas operations. One of the clearest changes: remove the program built to turn reports of exceptionally large methane releases into required investigations and repairs.
There is one important clarification before we go further. The program does not let anyone become an EPA-certified reporter. It lets certified third parties use EPA-approved detection methods to report events through a specific regulatory channel. And even if that channel is eliminated, the EPA says people would still be free to send the agency information about methane releases through other means. The proposal would, however, remove the special certification-and-notification system, and the response duties that can follow from it.
The proposed rule was published October 29. It would revise the 2024 Clean Air Act standards for oil and gas facilities, known as OOOOb and OOOOc, in 40 C.F.R. Part 60. The proposal also revisits rules for associated gas, well-site categories, and equipment monitoring.
This is the second phase of EPA’s reconsideration of the 2024 methane regulations. It is a proposal, not a final rule. For now, that distinction matters: existing requirements do not disappear just because the agency has put a new version on the table.
Here is what the proposal would actually change, and what you should watch as the comment period proceeds.
The 2024 Rule, Reopened Again
To understand this proposal, start with the regulatory alphabet soup.
OOOOb sets federal performance standards for covered new, modified, and reconstructed sources. OOOOc provides emission guidelines for existing sources; states use those guidelines as a starting point when developing plans. Put simply, one subpart applies standards directly to certain newer sources, while the other sets a framework for state plans covering existing sources.
The 2024 rules established stronger methane controls across the oil and gas sector, including leak monitoring and requirements related to flaring. EPA later extended some compliance deadlines. In November 2025, it finalized those deadline extensions. Earlier revisions also addressed certain flaring and monitoring provisions.
Now the agency is proposing another round of changes. The central question is no longer just when operators must comply. It is also which sources should be covered, which controls should count, and how much weight the regulations should give to outside monitoring.
EPA estimates that the proposal, if finalized, would produce $45 billion in savings and additional U.S. production of 210 million barrels of oil and 1.41 trillion cubic feet of natural gas. Those are the agency’s estimates, not established outcomes. The more immediate story is the rule’s mechanics: who can trigger a formal response, what happens to associated gas, and which well sites might face lighter requirements.
1. The Super Emitter Program: No More Special Reporting Lane
The Super Emitter Program was designed to add a rapid-response layer to existing monitoring rules.
A super-emitter event is defined in the 2024 framework as a methane release of at least 100 kilograms per hour detected near an oil and gas facility. Certified third parties use EPA-approved remote-sensing technologies to identify events and submit notifications to the agency. EPA then reviews and forwards qualifying notifications to the relevant operator. That notification can trigger an investigation, a report back to EPA, and corrective action where required.
The proposed rule would rescind the program’s third-party certification and notification provisions across several oil and gas subparts, including OOOO, OOOOa, OOOOb, and OOOOc. It would also remove the associated obligations for operators to respond to notices under that program.
EPA’s case for removal has several parts:
- The evidence base is not strong enough, in the agency’s view. EPA says more information is needed about how often super-emitter events occur, how long they last, and what causes them.
- The program may add limited value. EPA argues that existing standards, such as routine leak monitoring and requirements for certain control equipment, already prevent, detect, or mitigate many large releases.
- The program may not be timely or targeted enough. The agency says its early implementation experience showed that six of seven notifications it sent went to operators after the reported event had ended.
- The legal basis is disputed. EPA questions whether the Clean Air Act authorizes the certification structure and the program’s special role for third parties.
There is an important qualifier to that early-data argument: the Super Emitter Program had not yet reached full implementation. EPA had postponed its implementation date to January 22, 2027, while reconsideration continued. The agency also reports that only three remote-sensing technology applications had been submitted and only one entity had become a certified third-party notifier. Low participation is a real implementation fact. It is not, by itself, proof that a fully operating program would never have found or addressed leaks.
The proposal’s critics and supporters are likely to disagree over what these early results demonstrate. That is precisely why the public comment record matters.
And “scrapping the program” does not mean the public loses every way to alert EPA. The agency says people may still submit information about methane releases outside this system. The difference is that a submission would no longer travel through this certified program, with its defined review-and-notification process and corresponding operator response duties.
The practical verdict: the proposal would remove a formal, specialized reporting mechanism, not make methane leaks impossible to report. Those are different things, even if headlines would rather not carry the footnote.
2. Associated Gas: The Sales-Line Preference Gets Reconsidered
When oil comes up from a well, natural gas can come with it. That gas is called associated gas. The 2024 framework generally favored routing it to a sales line rather than routinely flaring it.
EPA now proposes that routing associated gas to a sales line is not the appropriate BSER. The “best system of emission reduction,” a key Clean Air Act concept used to determine the level of control a standard requires.
Instead, the proposal would allow operators of oil wells to route associated gas to a flare or other control device that achieves at least a 95% emissions reduction. The proposal also revisits the previous requirement that all covered oil-well operators route associated gas to a sales line.
That is a significant change in direction. The 2024 approach treated gas recovery and sale as the preferred standard in circumstances where infrastructure was assumed to be available. The new proposal puts more weight on whether the required system is achievable across different locations and production conditions.
This is not the same as a proposal to allow unlimited venting. A flare or control device meeting the proposed reduction level remains part of EPA’s stated approach. But the choice between capturing gas for sale and controlling it on site has clear consequences for operators, infrastructure planning, and methane emissions.
For communities near oil-producing areas, from the Permian Basin in West Texas and southeastern New Mexico to other producing regions, the distinction is not abstract. It concerns what happens to gas at the well and what equipment operators would be expected to install and run.
3. Well-Site Categories: Smaller Wells Could Face Lighter Standards
EPA is also co-proposing two ways to divide well sites into separate categories, with reduced or eliminated requirements for some smaller or lower-production wells.
Option one: production level. Well sites could be grouped as marginal or non-marginal. EPA proposes reduced requirements for marginal wells and asks about further dividing that group by production level.
Option two: resource type. Well sites could be classified as conventional or unconventional, with reduced requirements for conventional wells.
These are alternatives under consideration, not two categories EPA has already selected. Nor does the proposal mean every small well would automatically become exempt. The definitions, thresholds, and specific standards would determine who qualifies and what requirements change.
That detail matters because “small” and “low-producing” do not necessarily mean “low-emitting.” The proposed classifications may reduce compliance burdens for some operators, but commenters can challenge whether the proposed categories accurately capture emissions and whether different rules are justified.
If you follow the debate in places such as the Permian Basin or the Appalachian region, where well types and production profiles differ, the core question is practical: does a category track meaningful operational differences, or does it create a broad carve-out that leaves important emissions outside the stricter standards?
4. Covers, Closed-Vent Systems, and the Fine Print of Repairs
The proposal also addresses covers and closed-vent systems. Equipment intended to capture and route emissions rather than release them.
Under the 2024 rule, the “No Identifiable Emissions” requirement could treat detected emissions as an immediate violation. EPA proposes to split this into separate design and operational requirements. Under the proposed operational approach, an operator could repair an identified defect rather than having the detection itself automatically count as an immediate violation.
That is a change in how a defect is treated, not a declaration that emissions do not matter. The proposal still concerns inspection, identification, and repair. The key difference is whether a detected problem is automatically a violation at the moment it is found, or whether the rules recognize a pathway to fix it.
EPA also proposes technical flexibility for control devices, including how operators handle flame-monitoring data deviations, alerts, and visible-emissions test conditions. These details may sound like paperwork trivia. In a compliance rule, they can determine whether a monitoring glitch becomes a violation, what records an operator must keep, and how an inspection is conducted.
What the Power-Plant Debate Has to Do With Methane
This methane proposal arrives alongside a separate EPA effort concerning greenhouse-gas standards for power plants. In September 2026, the agency issued a supplemental proposal arguing that Clean Air Act Section 111 does not authorize regulating power-plant greenhouse-gas emissions in the manner at issue, and proposed repealing the remaining power-plant standards.
Methane rules also arise under Section 111. So the legal relationship is hard to ignore.
EPA, for now, says the oil-and-gas methane rules “operate in a distinct manner, have their own regulatory history, and involve different and additional considerations.” The agency says it may revisit the methane rules later, after completing the separate power-plant proceeding.
That is not a final answer to the broader statutory question. It is EPA’s explanation for treating the two rulemakings differently at this stage. If the agency later adopts a sweeping interpretation of Section 111 in the power-plant matter, expect parties to ask what that means for methane standards, too.
What Operators, States, and the Public Should Do Now
The proposal is not final, and it does not itself cancel current obligations. But the comment period is where affected parties can make the record, and where the details of proposed categories, control standards, and monitoring rules can be tested.
If you are an operator, state regulator, local official, or community member, consider these steps:
- Read the proposed rule itself. The National Law Review summary is useful, but the Federal Register notice is the primary place to check the agency’s rationale and questions.
- Identify the provisions that apply to your situation. A new or modified facility under OOOOb and an existing facility affected through a state plan under OOOOc are not the same compliance case.
- Be specific about the Super Emitter Program. If you comment, address whether the 100 kg/hour threshold, event duration, location attribution, and notification timing support EPA’s conclusions, or point to other evidence.
- Address well-site classifications with evidence. Explain whether production level or resource type is a reliable way to distinguish sites, and what emissions data support your position.
- Spell out operational consequences. For associated gas, describe infrastructure constraints, control-device performance, and the difference between routing gas to a sales line and using a flare or other control.
- Submit comments by December 16, 2026. Comments go to docket EPA-HQ-OAR-2025-0163 through Regulations.gov. The Federal Register also says comments on information-collection provisions are best assured of consideration if a copy reaches the Office of Management and Budget by November 30, 2026.
Comments submitted to the docket may be made public. Review the agency’s instructions before including personal or confidential information.
FAQ: EPA’s Proposed Methane-Rule Changes
Is the Super Emitter Program already gone?
No. EPA has proposed eliminating it. The proposal is not final, and existing requirements remain in force unless and until a final action changes them.
Can people still report a methane leak if the program is rescinded?
Yes. EPA says anyone may still submit information about methane releases outside the Super Emitter Program. What would disappear is the special certified third-party process and its defined notification and response framework.
Would the proposal allow operators to vent associated gas without limits?
That is not how EPA describes its proposal. The agency proposes a flare or other control device achieving at least 95% emissions reduction as the relevant control approach. The proposed rule would change the sales-line requirement, not establish an unrestricted permission to vent.
Are all small wells automatically exempt?
No. EPA is considering alternative subcategories based on production level or resource type. The final definitions and standards would determine which well sites qualify and what requirements apply.
What is the comment deadline?
Comments are due December 16, 2026, under docket EPA-HQ-OAR-2025-0163. The separate earlier date for information-collection comments is November 30, 2026.
Final Thoughts
EPA’s proposal would change more than the compliance calendar. It would remove the special system for certified third-party reports of major methane events, make sales-line routing no longer the preferred standard for associated gas, and create potential lighter requirements for certain well sites. It would also adjust how repairs and control-device monitoring are handled.
For the public, the central question is not whether a leak can still be mentioned to a federal agency. It can. The question is whether the formal route that turns certain outside detections into an agency-reviewed notice, and an operator investigation, should remain.
For operators and regulators, the task is to separate what EPA has proposed from what is currently required. For everyone else, the task is to read the fine print, follow the docket, and make comments that address the actual provisions rather than the headline alone.
This is the second phase of a reconsideration, not the final frame. The next one depends partly on what EPA hears before December 16.
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For continuing coverage, visit LD3 Productions’ Political & Government desk and Science, Health & Environment desk.
This article is news analysis for general informational purposes and is not legal advice. The proposed rule is not final; consult the current regulations and qualified counsel about specific compliance obligations.