Corporate climate targets just got a major overhaul. And this time, the details are in the data.
In June 2026, the Science Based Targets initiative (SBTi) released Version 2.0 of its Corporate Net-Zero Standard, the framework more than 11,000 companies use to set validated emissions reduction targets. V2.0 is the most significant revision since the Standard launched in 2021, and it fundamentally changes how companies will procure, account for, and prove their clean energy usage.
If you buy electricity at scale or sell it to companies that do, here’s what you need to know.
What Changed in V2.0?
With Version 2.0, the Standard is no longer just about setting targets. It’s about delivering on them. Companies will demonstrate credible delivery through transition plans, implementation hierarchies, progress assessments, and third-party assurance.
For energy buyers and suppliers, the most consequential changes sit in Scope 2:
- Geographic matching gets stricter. Clean energy procurement must occur within the same “deliverability region” as consumption, not just the same country or market.
- Hourly matching enters the Standard. Large electricity users must report the percentage of consumption matched to low-carbon electricity on an hourly basis, with an optional recognition program for leaders.
- Market instruments face new integrity criteria. EACs and PPAs must meet requirements for age of generation assets, temporal alignment, registry tracking, and assurance.
- “Low-carbon electricity” (LCE) replaces “renewable” as the organizing concept. LCE includes renewables, nuclear, and generation fitted with carbon capture and storage.
The critical dates:
- V2.0 will go into effect February 1, 2027.
- Version 1 remains open for target setting until the end of 2027.
- Companies with existing 2030 targets should begin setting their next-cycle (2030–2035) targets under V2.0 starting in 2028.
That means the procurement decisions and data infrastructure choices companies make in the next 18 months will determine how smoothly they transition.
The Headline Shift: From Annual Claims to Hourly Proof
For a decade, corporate clean energy accounting has run on annual math: buy enough certificates over the course of a year to cover your annual load, and claim 100% renewable.
V2.0 moves decisively away from that model.
Under the new Standard, companies must define their electricity “activity pools” based on deliverability regions i.e. the grid systems that physically serve their consumption. Procurement outside that region generally doesn’t count, with two notable exceptions: companies that can demonstrate transmission interconnection rights to a neighboring region, and companies that aggregate load across interconnected regions under a single PPA with a new-build project. The project must have offtake beginning within 36 months of commissioning.
Then comes the temporal layer. Companies with 10 GWh or more of annual electricity consumption in any activity pool must calculate and report the percentage of that consumption matched with low-carbon electricity on an hourly basis. For Category A companies, which are defined as large companies globally and medium-sized companies in high-income countries, their hourly matching percentage must be independently assured.
Every company setting targets under V2.0 must also declare, at target validation, whether it intends to participate in the SBTi’s optional Scope 2 Hourly Matching recognition program. Companies that opt out must explain why.
The recognition thresholds are ambitious:
- At least 50% hourly matching until 2030
- At least 75% hourly matching until 2035
- At least 90% hourly matching from 2035
Hourly matching is voluntary for recognition purposes for now, but hourly reporting is mandatory for large loads. The SBTi has signaled a Call for Evidence on how hourly matching should be deployed in future target-setting requirements, and the GHG Protocol’s Scope 2 revision is moving in the same direction. The trajectory is unmistakable: annual averages are out, and time-stamped proof is in.
What This Means for Corporate Energy Buyers
1. Your REC Strategy Needs a Review
V2.0 imposes new eligibility criteria on market instruments:
- A 15-year generator age limit. Instruments must come from LCE generators commissioned or re-powered within 15 years preceding the consumption period. PPAs can run longer with generating projects less than 36 months into operation.
- A 12-month temporal alignment requirement. Instruments must correspond to generation occurring within 12 months of consumption.
- Deliverability-region matching. Certificates from outside your grid region generally won’t qualify.
Existing contracts are grandfathered for their duration, but renewals won’t extend legacy treatment. If your portfolio leans on older assets, distant geographies, or loosely vintaged certificates, now is the time to model what qualifies after February 2027.
2. Hourly Data Becomes Table Stakes
You cannot report an hourly matching percentage without hourly data. That means hourly interval load data for every significant facility, hourly generation data for every contracted resource, and a defensible method for matching the two consistently applied within each activity pool, auditable end to end.
For Category A companies, this isn’t optional. And because the hourly matching figure must survive third-party assurance and public display on the SBTi Dashboard, spreadsheet-grade estimates won’t hold up.
3. Procurement Strategy Gets More Sophisticated
Once matching moves to the hour, not all clean megawatt-hours are equal. Solar-heavy portfolios that look great on an annual basis can leave large overnight gaps. Buyers pursuing recognition thresholds will need diversified portfolios shaped against their actual hourly load profile.
That’s a fundamentally data-driven exercise. The companies that understand their hourly consumption patterns today will negotiate better contracts tomorrow.
4. High-Growth Loads Face Extra Scrutiny
Companies projecting more than 20% average annual electricity demand growth over a target cycle (such as data centers) must set an absolute scope 2 emissions target, not just a clean energy percentage target. Growth doesn’t exempt you; it raises the bar.
What This Means for Energy Suppliers
The buyer requirements above translate directly into supplier opportunity or supplier risk, depending on how it’s managed.
1. Utility-Grade Hourly Data Is Now a Product Requirement
Large customers will need hourly consumption data, hourly generation attribution, and emissions factors they can hand to an assurance provider. Suppliers that can deliver granular, time-stamped, registry-linked data will win and retain these accounts. Suppliers that can’t will watch buyers go elsewhere (or you will hear about it until you act).
2. Your Offerings Will Be Evaluated Against V2.0 Eligibility
The Standard defines the eligible instruments: physical and virtual PPAs with grid-connected LCE generators, supplier contracts for LCE attributes, unbundled EACs, and default-delivered LCE supported by certificates. Every one of them now carries integrity criteria including age limits, deliverability, temporal alignment, unique attribution, and secure registry tracking that prevents double counting.
Suppliers should be prepared to answer, for every product: Which deliverability region does this serve? How old are the generators? Can attributes be tracked hourly? Can the claim survive an audit?
3. Prioritize the Customers the Standard Prioritizes
The customers with the most urgent needs are easy to identify: SBTi participants and companies planning validation, large Category A companies, loads of 10 GWh or more per year in any region, fast-growing electricity users, and any customer with material scope 2 emissions. These organizations need immediate help with structuring compliant portfolios, closing hourly gaps, and building the data pipelines that V2.0 assumes.
Strategic Questions to Ask Now
- Which of our targets and contracts carry over under V2.0’s grandfathering provisions and which expire under the new rules?
- Do we have hourly load data for every facility and activity pool above 10 GWh?
- Can we attribute contracted generation to consumption at the hourly level, in the right deliverability region?
- What does our hourly matching percentage look like today and how far are we from 50%?
- Is our emissions and energy data auditable enough to survive third-party assurance and public display on the SBTi Dashboard?
- Can our products and data services meet what Category A customers will demand starting in 2028?
The Bigger Picture: Clean Energy Claims Must Be Provable
V2.0 doesn’t exist in isolation. It lands alongside the GHG Protocol Scope 2 revision, the EU’s CBAM, and a broader wave of frameworks all converging on the same principle: carbon and clean energy claims must be granular, location-aware, time-matched, and verifiable.
The era of buying annual certificates and calling it done is closing. What replaces it is an evidence-based system, and evidence requires infrastructure.
How Cleartrace Helps
The SBTi Corporate Net-Zero Standard V2.0 is, at its core, a data challenge.
Energy buyers and suppliers need:
- Hourly load and generation visibility
- Deliverability-region-aware matching
- Transparent PPA and EAC attribution
- Verifiable audit trails built for assurance
- Reporting that scales across facilities and regions
Cleartrace provides the hourly energy and carbon data infrastructure that makes these claims provable thereby helping companies measure, match, and verify their clean energy with the granularity V2.0 demands.
V2.0 becomes effective February 1, 2027. The companies that build their hourly data foundation now won’t just be ready to comply. They’ll be positioned to lead.
The question isn’t whether hourly accountability is coming. It’s whether your energy data will be ready when it arrives.
