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Power Play California's Virtual Power Plant Revolution

California is considering a mandate for virtual power plants (VPPs), with a potential capacity of 7.7 gigawatts by 2035. A recent report by The Brattle Group for GridLab highlights the potential of VPPs to cover about 15% of California’s peak power demand by the same period.

The report identifies various sources contributing to the VPP market potential, including orchestrated electric vehicles (EVs), behind-the-meter batteries, smart thermostats, water heaters, and demand response. These resources could significantly boost VPP capacity, especially from batteries behind residential or commercial meters and managed EV charging.

What is a Virtual Power Plant?

A Virtual Power Plant (VPP) is a network of decentralized, medium-scale power generating units, flexible power consumers, and storage systems. These units are aggregated and coordinated through advanced software and control systems to operate as a single, integrated power resource. 

A VPP aims to optimize energy generation, consumption, and storage in real time to meet demand, stabilize the grid, and maximize efficiency. By leveraging distributed energy resources, VPPs offer a flexible and responsive approach to managing electricity supply and demand, enhancing grid reliability, and supporting the integration of renewable energy sources.

Virtual Power Plant

Energy experts assert that VPPs are crucial for diminishing the power sector’s reliance on environmentally harmful fossil fuels as the country transitions towards electrifying transportation, buildings, and industrial sectors. While still in the early stages, VPPs are positioned for significant expansion in the United States in the forthcoming years. 

Thanks to by President Joe Biden’s recent climate legislation, which incorporates incentives for electric vehicles, solar panels, and home batteries.

However, overcoming barriers to mass VPP deployment may require new policies. Senate Bill 1305 aims to accelerate VPP rollout by directing regulatory bodies, including the following:

  • California Public Utilities Commission (PUC), 
  • California Energy Commission (CEC), and 
  • California ISO to take actions supporting VPP deployment. 

The bill includes provisions for PUC adoption of VPP procurement requirements for investor-owned utilities. The effectiveness of such a mandate hinges on policy details and enforcement mechanisms. 

Legislation Propels California’s VPP Evolution

SB 1305 also tasks the CEC and CAISO with estimating the potential of “resource adequacy-qualifying virtual power plant resources” and addressing regulatory barriers.

This initiative builds upon California’s existing goal of achieving 7 GW of flexible demand by 2030. This aim is set to reduce consumer electricity demand during grid stress periods. 

The Brattle Group’s assessment reveals that batteries installed at homes and businesses, often coupled with rooftop solar arrays, hold the highest potential for inclusion in software-steered Virtual Power Plants (VPPs). 

By 2035, these batteries could cover 5.1% of California’s peak power demand. Synchronized smart thermostats follow closely, offering 4.3%, while managed EV charging, automated demand response, and grid-interactive water heating contribute 3%, 2.3%, and 0.5%, respectively.

The projected 7.7 GW of VPP market potential from these technologies could yield significant savings by 2035. A staggering amount of over $750 million per year could be avoided in traditional system infrastructure investments. Approximately $550 million of these savings would directly benefit consumers.

Realizing the Benefits of VPPs for All Californians

Edson Perez, California lead at Advanced Energy United, emphasizes the tangible benefits of VPPs for Californians, saying that: 

“Virtual power plants offer a very real opportunity for Californians to get paid back directly for helping keep the lights on in communities across the state.”

Accessible VPP technologies like smart thermostats and electric vehicles offer residents payments for their participation, he further noted. This would lead to more affordable rates and increased grid resiliency for all ratepayers.

To realize these benefits, the report suggests California adopt emerging best practices for VPPs, drawing from experiences globally. While pilot projects have provided valuable lessons, the focus now must shift to full-scale deployment. 

Regulators are also encouraged to ensure that successful pilot programs transition into broader implementation. Additionally, the report recommends providing sufficient incentives to encourage consumer participation in VPPs and support utilities or third-party aggregators in implementing and operating them.

Current payment structures may not fully reflect the value of VPP participation, requiring performance-based incentives for utilities and aggregators. Third-party aggregators could be incentivized with better access to wholesale markets and opportunities to participate in distribution investment deferral programs, among other strategies.

This interesting development comes handy as California faces a challenging task to meet its climate goals. The state must almost triple its efforts in reducing annual emissions to achieve its 2030 target.

Virtual Power Plants represent a crucial step towards a more flexible, efficient, and sustainable energy future. They offer tangible consumer benefits, grid reliability, and the integration of renewable energy sources. Policy initiatives like SB 1305 signal a commitment to accelerating VPP deployment, paving the way for a cleaner energy landscape.

The post Power Play: California’s Virtual Power Plant Revolution 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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