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Unraveling U.S. EPA's Bold Emission Rule for Fossil Fuel Power Plants

The debate over new carbon dioxide limits for power plants has centered on carbon capture technology, with the US Environmental Protection Agency (EPA) defending its readiness despite industry skepticism.

The EPA had finalized a rule establishing carbon emissions standards for coal- and new gas-fired generation, effectively requiring carbon capture technology for many power plants. This climate policy was first revealed in April last year.

Under the new EPA mandate, coal plants must implement carbon capture and storage (CCS) technology. This technology involves capturing CO2 from power plant emissions and then storing it underground to prevent it from entering the atmosphere. 

The EPA’s New Mandate for Coal Plants

The directive is a bold ultimatum for coal-fired power plants to either capture their smoketstack emissions or face shut down. The new rule aligns with President Joe Biden’s pledge to combat carbon pollution from fossil fuel-fired electric plants by 2035 and economy-wide by 2050. 

The latest restrictions on GHG emissions represent the Biden administration’s most aggressive stance to fight global warming. President Biden’s National Climate Advisor Ali Zaidi, made a promise that,  

“This year, the United States is projected to build more new electric generation capacity than we have in two decades – and 96 percent of that will be clean,” 

US EPA carbon emissions rule power plant type

Here are the main points of the EPA’s new carbon emissions rule for power plants: 

  • Existing coal-fired plants intending long-term operation and all new baseload gas-fired plants must control 90% of their carbon pollution.
  • Boost the Mercury and Air Toxics Standards (MATS) for coal-fired power plants, tightening toxic metal emissions standards by 67% and finalizing a 70% reduction in mercury emissions from existing lignite-fired sources
  • Cut pollutants discharged through wastewater from coal-fired power plants by over 660 M pounds/year, guaranteeing cleaner water for impacted communities, particularly those with environmental justice concerns facing disproportionate impacts.
  • Safe management of coal ash in previously unregulated areas, including disposal sites prone to leakage and groundwater contamination.

Coal remains the largest energy source for electricity generation, steelmaking, and cement production. However, it’s also the largest source of man-made carbon dioxide (CO2) emissions.

The Rule’s Climate Impact and Benefits

The EPA’s finalized rule on carbon emissions standards for power plants is projected to have significant financial and climate impacts.

According to EPA estimates, industry compliance with the rule could cost between $7.5 billion and $19 billion through 2047. However, the agency also anticipates substantial climate and public health benefits, totaling to $370 billion over the next two decades. 

  • In terms of emissions reductions, the rule is forecasted to prevent 38 million metric tons of CO2 emissions in 2028 and 123 million metric tons in 2035.

Mona Dajani, global co-chair of energy, infrastructure, and hydrogen at Baker Botts, emphasized that the rule sends a clear message to power plant operators about the end of unlimited carbon pollution. While carbon capture technology will contribute to emissions reductions, the EPA projects that the greatest impact will come from coal plant retirements prompted by the rule.

By 2035, the agency expects US coal-fired capacity to decrease to about 20 GW, comprising 19 GW with carbon capture and 1 GW with natural gas co-firing. This contrasts with a scenario without the regulations, where coal-fired capacity would consist of 11 GW with carbon capture and 41 GW of unabated coal plants.

new gas generation by 2030 in US

Regarding gas-fired generation, the EPA anticipates 1GW of capacity with carbon capture and 484 GW without carbon capture by 2035. Additionally, the EPA announced plans to set carbon limits for existing gas-fired power plants in a future rulemaking process.

However, this decision has ignited debate from industrialists and environmental stalwarts. Trade groups also criticized the standards, questioning the feasibility of capturing and storing CO2 emissions, echoing concerns raised after the EPA’s initial proposal in May 2023.

Challenges and Controversies

Dan Brouillette, president and CEO of the Edison Electric Institute (EEI), stated that CCS is not yet ready for full-scale deployment and that there isn’t enough time to develop the necessary infrastructure for compliance by 2032.

While CCS involves scrubbing CO2 from emissions sources like power plants for underground storage, operational implementations are not enough. Currently, only one utility-scale US power plant, W.A. Parish 5-8, utilizes carbon capture technology, with the captured gas used for oil extraction. The abandonment of another project in Kemper County, Miss., led to significant costs for Southern Co., raising doubts about CCS.

Some industry groups, such as the National Rural Electric Cooperative Association (NRECA), have challenged the legality of the rule. NRECA CEO Jim Matheson criticized the rule as unlawful, unrealistic, and unachievable, arguing that it undermines electric reliability and poses risks to an already strained electric grid. 

  • However, the EPA highlighted technological advancements and federal incentives making CCS more economically viable in its final rule.

The expansion of tax credits for carbon capture under the US Inflation Reduction Act in 2022, now valued at up to $85 per metric ton of CO2 stored, has bolstered support. Additionally, process improvements from previous CCS deployments have contributed to cost reductions.

The EPA noted that some companies have already planned to install CCS on their units independent of regulatory requirements, indicating growing industry interest in the technology’s potential.

The new rule’s first provision allows units to respond to declared grid emergencies without being held accountable for their CO2 emissions, providing a short-term mechanism to address urgent situations. The second provision permits US states to delay compliance measures for certain units in the event of unanticipated grid reliability issues. 

States have the option to include both reliability exceptions in the plans they submit to the EPA for implementing the new rule.

As the debate rages on, the EPA’s carbon emission standards mark a pivotal moment in the nation’s energy transition, highlighting the delicate balance between environmental goals and industry realities.

The post Unraveling US EPA’s Bold Emission Rule for Fossil Fuel Power Plants appeared first on Carbon Credits.

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Carbon Footprint

Insetting vs Offsetting: Which Actually Counts Toward Your Scope 3 Targets

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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.

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Carbon Footprint

Net zero needs nature: a carbon credit guide

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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.

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Carbon Footprint

Deforestation in Malawi: causes and solutions

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Malawi has lost a striking share of its forests over the past three decades. Woodlands that once covered well over a third of the country now cover less than a quarter, and the pressure on what remains is increasing. Behind those figures sit two practical questions: what is driving the loss, and what reverses it?

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