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.

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.
Carbon Footprint
Want a simpler way to buy carbon credits? Discover our carbon marketplace
Most businesses that decide to act on their net-zero targets reach the same point of friction. Buying carbon credits has meant tracking down brokers, sitting through sales calls, and requesting a quote just to learn a price, sometimes with limited proof of what you are buying.
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Carbon Footprint
Climate-Linked Supply Chain Risk Is Already in Your P&L
The earnings calls that quietly reframed climate from sustainability question to operating risk.
Three earnings calls in the last 18 months tell the story without any help from a press release.
Hershey, May 2024: cocoa price exposure compresses margin, and the company attributes part of the cost shock to West African weather. Olam, July 2024: coffee climate exposure quantified in the annual report. JBS, January 2025: supply chain climate disclosures expanded materially in response to investor pressure and regulatory expectation. None of these companies issued the announcement as climate news. They issued it as financial news. The climate-linked supply chain risk did not arrive with a sustainability framing; it arrived as a P&L line.
You are probably reading this article because you suspect the same thing is happening to your business. This piece walks through what is showing up on which earnings calls, how procurement and finance leaders are quantifying the exposure, and what serious corporates are doing about it before the regulator asks.
Where climate risk has already appeared in earnings
The pattern is consistent across resource-intensive sectors. A weather event compresses supply, the price spikes, the cost flows through the income statement, and the analyst on the call asks whether the event is anomalous or structural. Increasingly, the honest answer is the second one.
Cocoa is the cleanest example. The 2023 to 2024 West African harvest fell sharply on the back of erratic rainfall and disease. Cocoa futures more than tripled. Companies with concentrated West African sourcing absorbed the cost; companies with diversified sourcing absorbed less. The exposure was not climate as ESG topic. It was climate as cost of goods.
Coffee follows the same pattern. Brazilian and Vietnamese harvests have moved on weather more sharply across the last several seasons. Roasters with long-tenor supplier relationships and origin diversification have managed the volatility; roasters with spot-market exposure have not. Wheat, sugar, palm oil, beef: the same dynamic in different commodities, a pattern the IPCC AR6 Working Group II report projects will intensify across agricultural systems through mid-century.
What this means: climate risk is no longer a footnote in the 10-K. It is a line item the CFO has to explain on the call.
The three commodity exposures that hit margin first
For most companies with material Scope 3 exposure, three exposures dominate the near-term P&L risk.
- Concentrated single-origin sourcing in a climate-vulnerable region. If your tier-one supply for any material commodity sits in one geography, you have a concentration risk that climate amplifies. Diversification across origins is the obvious hedge, but it takes years to build and requires relationships you cannot acquire by tender.
- Supplier financial fragility under climate stress. Smallholder farmers, who supply a large share of the global cocoa, coffee, and palm oil market, do not carry the balance sheets to absorb yield shocks. When yields collapse, they exit. When they exit, your supply base shrinks, and the surviving suppliers raise prices. The risk is structural, not cyclical.
- Logistics and storage exposure to extreme weather. Hurricane disruptions to Gulf shipping, drought-driven Panama Canal restrictions, flooding in European inland waterways: each of these has moved input costs in the last three years, a pattern documented in Munich Re’s natural catastrophe data. The exposure shows up as a one-quarter event in the financial press but accumulates over time on the cost line.
TCFD and ISSB disclosure changes
The disclosure architecture has now caught up with the risk. The Task Force on Climate-related Financial Disclosures, whose recommendations are now embedded in the ISSB’s IFRS S2 climate standard, requires companies to disclose climate-related risks across physical and transition categories, with quantification where possible.
For physical risk specifically (the climate-linked supply chain risk you are reading about), the disclosure must address both acute exposures (extreme weather events) and chronic exposures (gradual changes in temperature, precipitation, and growing seasons). The disclosure must address the time horizon over which the risk is material, the parts of the value chain exposed, and the financial impact under different scenarios.
The CSRD imposes similar requirements under European law, with double materiality (both financial and impact materiality) embedded in the assessment. The practical effect: your auditors and your investor relations team now need a defensible answer to the climate-linked supply chain risk question, and the answer needs to be quantified.
What procurement and finance can do now
Three actions matter near-term.
Map your exposure. Most companies do not have a clear view of which tier-one and tier-two suppliers sit in which climate-vulnerable geographies. Without the map, you cannot quantify the risk, and without the quantification, you cannot disclose it credibly. The map is the foundation, and World Resources Institute climate risk research provides useful public tooling to start.
Diversify and deepen, in that order. Diversification across origins reduces concentration risk, but the deeper move is to invest in the resilience of the suppliers you already have. Regenerative practices, agroforestry, soil health interventions: these reduce yield volatility under climate stress and protect your input cost trajectory.
Embed the climate spend inside procurement, not outside it. Treating climate risk as a sustainability cost line subordinates it to the ESG budget. Treating it as a procurement and resilience investment puts it in the budget that matters, which is the cost-of-goods budget that the CFO defends quarterly.
Nature-based supply chain investments are the asset class designed for exactly this purpose. They sit inside the value chain, they reduce climate-linked supply risk, they generate verifiable Scope 3 reductions, and they produce the documentation an auditor and a regulator can both test.
If you are quantifying climate-linked supply chain risk in advance of the next earnings cycle or the next disclosure period, the carbon and sustainability experts at Carbon Credit Capital can help you map your exposure and structure a Dual-Value Model response that addresses reduction, resilience, and disclosure-readiness in a single program. Schedule a consultation.
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.
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