The European Union’s new Methane Regulation is making waves in the global energy market, especially in the U.S. liquefied natural gas (LNG) sector. The regulation aims to curb methane emissions from imported fuels, marking a significant step toward reaching net zero goals.
Methane, the second-largest contributor to global warming after carbon dioxide, is a potent greenhouse gas. The regulation sets a clear signal that suppliers, particularly those in the U.S., must improve tracking and control of methane emissions.
The Regulation’s Impact on the US Natural Gas Sector
The EU Methane Regulation sets a long-term framework with the key compliance period beginning in 2027. However, reporting requirements will start earlier, in May 2025, which will establish an emissions baseline. These initial reports will help lay the foundation for future compliance efforts.
Cheniere Energy Inc., the top U.S. LNG exporter, sees this regulation as a wake-up call for the industry to sharpen its focus on emissions. Robert Fee, Cheniere’s vice president of international affairs and climate, highlighted that the company has already been working on methane measurement and reporting for over 6 years. This head start positions Cheniere to navigate the new regulations more smoothly than some of its peers. Fee emphasized,
“Today and into the future, that’s going to be in a world where there’s an increasing focus on climate-related issues, and certainly through 2030 industry needs to take action to measure and mitigate methane emissions to near zero.”
Rather than imposing immediate and stringent penalties, the regulation gives companies time to adapt. They are expected to start by submitting information on existing supply deals and progressively incorporate these requirements into new contracts.
This phased approach has alleviated fears of market disruptions. Fee explained that despite the new rules, the EU still views U.S. LNG as a critical energy supply, especially following the loss of Russian pipeline gas 3 years ago.
In terms of natural gas demand projection, S&P Global Commodity Insights estimates show that it will grow to over 70% by 2050 under a base case scenario, but it could drop under the green energy transition scenario.

Challenges for US LNG Suppliers
The new regulation sends a clear message. Yet, there are still uncertainties about its exact implementation, especially concerning how it applies to LNG importers. This has created a degree of uncertainty in supply contract negotiations.
The most significant challenge for U.S. exporters is the requirement to collect methane emissions data “at the level of the producer.” This poses a hurdle, as many companies in the U.S. gas supply chain lack direct access to emissions information from wellheads.
Ben Cahill, a director of energy markets at the University of Texas, also noted that U.S. gas producers often struggle to gather this information due to the complexity and vastness of the U.S. gas pipeline network.
EU Methane Push: Taking the Lead on Global Efforts
The EU’s new regulation aligns with the Global Methane Pledge, a commitment made by the U.S. and over 100 other countries in 2021 to reduce global methane emissions by 30% from 2020 levels by 2030. European authorities aim to establish the EU as a global leader in methane mitigation by pushing for stringent mitigation measures.
Starting in 2027, LNG importers will have to demonstrate that the supplies they bring into the EU meet methane emissions standards equivalent to those in the EU.
By 2030, the region will have a methane emissions intensity standard that all imported fuels must meet. The regulation will also align with the Oil and Gas Methane Partnership 2.0 (OGMP 2.0), a reporting framework developed by the United Nations Environment Program. Cheniere Energy joined the OGMP 2.0 initiative in 2022, with Fee describing it as the “best measurement framework” for the industry.
Despite the clear direction set by the EU Methane Regulation, several details remain unresolved. For instance, importers must start reporting to a “competent authority” in each member state by May 2025. However, these authorities have not yet been established, and penalties for non-compliance are still unclear.
Another question mark is how the EU will handle regulatory exemptions for countries whose methane regulations are deemed equivalent to those in the EU. U.S. government officials may need to collaborate with their EU counterparts to ensure that the U.S. methane fee and the Environmental Protection Agency’s emissions regulations are recognized.
These U.S. regulations are among the strictest globally. Still, whether they will satisfy the EU’s new standards remains to be seen. Analysts believe that this uncertainty has led to a temporary pause in long-term supply contract negotiations.
A Growing LNG Market Amid Climate Regulations
Despite the challenges posed by the EU’s methane regulations, the global demand for LNG is rising. The U.S. LNG export capacity, expected to exceed 13 billion cubic feet per day (Bcf/d) by the end of 2024, is set to double by the end of the decade as new export projects come online.

For these U.S. LNG exporters, the EU’s stance on methane emissions could bring regulatory continuity. It is both a challenge and an opportunity.
While there are compliance hurdles, the phased approach provides time for adaptation. Moreover, the EU’s continued reliance on U.S. LNG supplies, combined with global efforts to curb methane emissions, underscores the importance of U.S. participation in these regulatory frameworks.
The post EU Methane Regulation Sends a Strong Signal to US Natural Gas Suppliers appeared first on Carbon Credits.
Carbon Footprint
Where should an SME start with a carbon action plan?
More and more small and medium-sized businesses are hearing the same question from their larger customers: What is your carbon footprint? That question now travels down entire supply chains, and it arrives next to tender requirements, certification criteria, and rising customer expectations.
![]()
Carbon Footprint
Insetting vs Offsetting: Which Actually Counts Toward Your Scope 3 Targets
The accounting differences that decide whether your nature investment shows up in inventory, in BVCM, or nowhere at all.
The question reaches a procurement team about three weeks before the next sustainability committee meeting. Someone has read about insetting. Someone else has just signed off on an offset purchase. The CSO wants to know if the two are interchangeable. The answer is no, and the GHG Protocol Land Sector and Removals Standard is the reason why.
This article walks through what each term means at audit-grade specificity, what the standards actually say about how each gets counted, and how to decide which tool fits which target. The insetting vs offsetting question is one of the most-searched in corporate climate strategy, and one of the most poorly answered. By the end of this piece, you should be able to brief a committee on the difference without notes.
The two definitions, in plain English
Offsetting means buying carbon credits generated outside your value chain and retiring them against your residual emissions. The reduction happens somewhere else, financed by you, and the credit is the receipt.
Insetting means investing in emission reductions or removals inside your own value chain, typically with suppliers, where the reduction is directly linked to the products and services you buy. The reduction happens inside the boundary of your Scope 3 inventory, and the accounting treatment is fundamentally different.
The shorthand from the University of Oxford’s Nature-based Insetting Initiative is useful: insetting is what you do with the supply chain you have; offsetting is what you do with the supply chain you do not have.
What the GHG Protocol Land Sector Standard actually says
The GHG Protocol Land Sector and Removals Standard, finalised in 2024 after a multi-year pilot, sets the rules for how land-based emission reductions and removals enter corporate inventories. The Standard distinguishes between inventory accounting (Scope 1, 2, and 3) and project or intervention accounting (a separate methodology for crediting).
For insetting, the practical implication is that supplier-level interventions, when properly measured and attributed, can reduce your Scope 3 category 1 (purchased goods and services) emissions in your inventory. The reduction is not a credit retired against the inventory; it is a lower inventory number, period.
For offsetting, the credit is retired separately. It can be reported as a contribution toward a net-zero claim under the SBTi Beyond Value Chain Mitigation framework or as part of a VCMI Carbon Integrity claim, but it does not lower the inventory number.
A practical consequence: if your Science Based Target requires a 50% absolute reduction in Scope 3 emissions by 2030, insetting moves you toward the target. Offsetting does not. This single point of difference reshapes the procurement decision.
When insetting counts toward Scope 3 (and when it does not)
Insetting counts toward Scope 3 only when several conditions are met:
- The intervention must occur with an entity in your value chain.
- The emissions reduction or removal must be measured against a defensible baseline.
- The reduction must be attributed to your share of that supplier’s output, not double-counted with other buyers.
- It must follow the inventory accounting rules in the GHG Protocol Land Sector Standard, not the project accounting rules used to generate credits.
The most common failure mode is double counting. If your supplier sells the same reduction as a credit on the voluntary market and also reports it to you as a Scope 3 reduction, the math breaks. The Standard requires you to address this risk, typically by purchasing and retiring the supplier-issued credit as part of your inventory or by contractual provisions that prevent the supplier from selling the reduction twice.
When insetting does not count toward Scope 3: when the intervention sits with a supplier you do not buy from, when the baseline is not defensible, when the attribution is unclear, or when the documentation does not survive audit. Those cases default to Beyond Value Chain Mitigation, which is still useful but operates on a different ledger.
The procurement and supplier engagement question
Insetting is harder than offsetting. That is the unfashionable truth most buyers eventually confront. Offsetting is a transaction; insetting is a relationship.
To run an insetting program, you need supplier mapping precise enough to know which farms or facilities sit at which Scope 3 boundary. You need an engagement model that gets suppliers to participate, which usually requires multi-year commitments and shared economics. You need an MRV architecture that measures the right things and produces audit-ready documentation. And you need a contractual structure that prevents double counting and protects both sides.
The trade-off you receive in return is significant. Reductions count against your inventory rather than your residual. Supplier relationships deepen, which protects sourcing continuity. Yield and quality improvements often follow regenerative interventions, which reduces your input cost over time. And the regulatory file, under CSRD, CSDDD, EUDR, and the SBTi FLAG Guidance, is materially stronger.
Choosing the right tool for the right target
A practical decision rule. If your target is a science-based Scope 3 reduction and you operate in a FLAG sector or source FLAG commodities, insetting is the structurally correct tool. If your target is a net-zero claim that includes neutralising hard-to-abate residual emissions outside your value chain, BVCM via high-integrity offsets is the structurally correct tool. Most companies with material Scope 3 exposure need both, in different proportions, sequenced over time.
The sequencing matters. Insetting takes longer to stand up but produces a permanent reduction in the inventory. Offsetting can be transacted faster but does not change the inventory and now sits under tighter claim restrictions. Treat them as complementary tools with different jobs, not as substitutes. The Accountability Framework Initiative and the IUCN Global Standard for Nature-based Solutions both provide useful guardrails for the insetting side, with biodiversity, human rights, and benefit-sharing requirements that go beyond carbon math.
If you are mapping a Scope 3 reduction roadmap and need to scope which interventions count toward your inventory versus which sit in Beyond Value Chain Mitigation, the carbon and sustainability experts at Carbon Credit Capital can help you structure a nature-based supply chain investment program that fits your FLAG exposure, your target architecture, and your audit horizon. Schedule a consultation.
Carbon Footprint
Net zero needs nature: a carbon credit guide
Net zero is often described as a balancing act: cut what you can, account for the rest, and reach zero on the ledger. That framing is useful, but it leaves something out. It treats every tonne of carbon as interchangeable and every route to zero as equally sound, while the science tells a more specific story.
![]()
-
Climate Change1 year ago
Guest post: Why China is still building new coal – and when it might stop
-
Greenhouse Gases1 year ago
Guest post: Why China is still building new coal – and when it might stop
-
Greenhouse Gases2 years ago嘉宾来稿:满足中国增长的用电需求 光伏加储能“比新建煤电更实惠”
-
Climate Change2 years ago嘉宾来稿:满足中国增长的用电需求 光伏加储能“比新建煤电更实惠”
-
Climate Change2 years ago
Bill Discounting Climate Change in Florida’s Energy Policy Awaits DeSantis’ Approval
-
Renewable Energy10 months agoSending Progressive Philanthropist George Soros to Prison?
-
Greenhouse Gases1 year ago
嘉宾来稿:探究火山喷发如何影响气候预测
-
Carbon Footprint2 years agoUS SEC’s Climate Disclosure Rules Spur Renewed Interest in Carbon Credits

