The A-Z of Energy Procurement: Changes in Reporting and Compliance
The GHG Protocol has opened a consultation on Scope 2
The GHG Protocol launched a public consultation on 20 October 2025 to revise its Scope 2 guidance for electricity emissions. The proposed changes would require companies to report purchased electricity using more granular methods, including hourly matching of clean power attributes and stricter deliverability requirements for renewable energy certificates. After receiving more than 1,000 submissions from stakeholders across 39 countries, the consultation deadline was extended to 31 January 2026.
For UK businesses, this represents a fundamental shift in how electricity procurement and carbon reporting align. The changes would move corporate accounting closer to how power is actually generated and consumed on the grid, rather than relying on annual certificate volumes that may not reflect real-time conditions. Consequently, procurement strategies built around simplified renewable energy claims may need significant adjustment before the revised standard takes effect.
The GHG Protocol's Scope 2 Technical Working Group stated the update aims to improve how companies account for electricity emissions by introducing "a new way to recognize the broader climate benefits of clean energy." The group is developing updated inventory rules based on hourly and regional matching, so reported electricity emissions better reflect when and where electricity is actually used. This matters because Scope 2 reporting influences how companies buy power, structure power purchase agreements, and choose renewable energy certificates.
Several advisory firms have noted the proposed changes would reshape corporate procurement strategy, not just reporting requirements. According to NUS Consulting, the revisions aim to improve accuracy, clarity, and comparability across electricity procurement and renewable energy claims. KPMG similarly observed that the market-based method would become more exacting, with greater emphasis on temporal and spatial matching alongside more rigorous contractual instruments.
Current Scope 2 guidance allows annual certificate matching
The existing Scope 2 Guidance requires companies to report purchased electricity using both location-based and market-based methods. The location-based method uses average emissions factors for the grid where electricity is consumed. Meanwhile, the market-based method allows contractual instruments such as renewable energy certificates to support lower reported emissions, effectively enabling companies to claim zero-emission electricity regardless of when or where it was generated.
This approach has faced sustained criticism. Environmental groups and energy analysts have argued that annual certificate matching allows companies to make claims that do not reflect real-time grid conditions. For example, a business might purchase renewable energy certificates generated by wind farms in Scotland during summer months, then apply those certificates against electricity consumed in London during winter evenings when wind generation is low. Under current rules, this practice is permissible.
The gap between accounting and physical reality has grown more pronounced as corporate climate commitments have expanded. Many companies have reported significant reductions in Scope 2 emissions by purchasing certificates, even when their actual electricity consumption has not shifted toward cleaner sources. This discrepancy has raised questions about the credibility of corporate climate claims and whether existing reporting standards adequately reflect genuine emissions reductions.
Proposed revisions introduce hourly matching and deliverability tests
The proposed Scope 2 updates would introduce four significant changes to how companies account for purchased electricity. First, hourly matching would require clean power attributes to align with consumption on an hourly basis, rather than annual totals. Second, deliverability requirements would mean instruments must come from generators that could plausibly serve the consuming grid. Third, a more precise location-based emissions hierarchy would expect companies to use the most relevant publicly available emissions factor. Fourth, clarified treatment of residual mix and standard supply service claims would reduce double counting.
Hourly matching represents the most substantial shift. Under this approach, renewable energy certificates or other contractual instruments would need to correspond to electricity consumption within the same hour. A business consuming electricity at 6pm on a Tuesday would need clean power attributes generated during that specific hour, not averaged across a month or year. This requirement would fundamentally change how companies procure and account for renewable electricity.
Deliverability requirements would add a geographic dimension. Certificates would need to come from generators connected to grids that could physically deliver power to the consuming location. For UK businesses, this means renewable energy claims would likely need to be backed by generation within Great Britain or via interconnectors with demonstrated import capacity. Certificates from distant markets with no physical connection would not qualify under the market-based method.
The location-based emissions hierarchy would also become more rigorous. Companies would be expected to use the most specific emissions factors available, rather than defaulting to broad national averages. For example, a manufacturer operating in Scotland might need to use Scottish grid emissions factors rather than UK-wide averages, if such data is publicly available. This change would improve accuracy but requires better data systems and more detailed reporting processes.
Timeline points toward 2027 finalization and 2028 implementation
The GHG Protocol has not published a definitive timeline, but several sources tracking the consultation expect the revised Scope 2 standard to be finalized in 2027. Phased implementation is widely anticipated to begin around 2028, giving companies roughly two years to adjust procurement strategies and reporting systems after the final standard is published. However, these dates remain indicative rather than confirmed.
The extended consultation deadline of 31 January 2026 reflects the complexity and significance of the proposed changes. The volume of submissions, more than 1,000 from 39 countries, indicates widespread stakeholder engagement. Responses have reportedly come from multinational corporations, renewable energy developers, certificate registries, industry associations, and environmental organizations. This level of engagement suggests the final standard will likely incorporate diverse perspectives and may include modifications to the initial proposals.
For businesses already planning procurement changes, the timeline creates a practical window. Companies can begin assessing their current electricity contracts, evaluating data availability for hourly reporting, and identifying gaps in their ability to demonstrate deliverability. Early preparation may reduce disruption when the revised standard takes effect, particularly for organizations with complex procurement structures or operations across multiple grid regions.
Market-based reporting faces stricter quality standards
The proposed changes would significantly raise the bar for market-based Scope 2 reporting. Currently, many companies rely on unbundled renewable energy certificates purchased separately from electricity supply contracts. These certificates often represent generation from distant locations or different time periods, with no connection to the electricity actually consumed. Under the proposed rules, such certificates would likely not qualify for market-based reporting unless they meet hourly and deliverability criteria.
This shift could change the relative value of different clean energy procurement approaches. Power purchase agreements that include hourly generation data and demonstrate deliverability would become more attractive. Green electricity tariffs backed by time-matched renewable generation would similarly gain credibility. Conversely, low-cost unbundled certificates with weak temporal or geographic alignment may lose their accounting value, even if they remain available in the market.
The residual mix clarification addresses another longstanding issue. Residual mix refers to the average emissions intensity of grid electricity after accounting for renewable energy certificates and other contractual claims. When certificates are sold separately from physical electricity, the remaining grid supply becomes more carbon-intensive on paper. The proposed guidance would provide clearer rules on how companies account for this residual supply, reducing the risk that multiple parties claim the same renewable generation.
For UK businesses, these changes interact with domestic electricity market structures. The UK government has supported contracts for difference schemes that provide revenue certainty for renewable generators. Many companies have entered corporate power purchase agreements under these frameworks. The extent to which existing PPAs meet the new hourly matching and deliverability standards will vary depending on contract terms, data provisions, and generator locations.
Critical details for UK business planning
Understanding the proposed changes requires familiarity with several technical elements. Hourly matching means renewable energy certificates or other instruments must correspond to consumption within the same clock hour. Deliverability means certificates must come from generators connected to grids capable of serving the consuming location. The location-based hierarchy means companies must use the most granular publicly available emissions factors. Residual mix treatment means clearer rules on accounting for grid electricity after contractual claims.
Several factors will determine how UK businesses experience these changes. Companies with operations in Scotland, where renewable generation is concentrated, may find hourly matching easier than those in regions dependent on gas generation. Businesses with access to detailed half-hourly settlement data will have better foundations for hourly reporting than those relying on aggregated monthly figures. Organizations with existing corporate PPAs that include generation profiles may need fewer adjustments than those purchasing unbundled certificates.
Data availability represents a practical challenge. Hourly matching requires granular information about both electricity consumption and renewable generation. Many UK businesses receive half-hourly metering data through their suppliers, but accessing hourly generation data for specific renewable projects may require new contractual arrangements or third-party verification. Certificate registries and renewable energy tracking systems will likely need to evolve to support hourly attribute tracking at scale.
The proposed changes also raise questions about voluntary carbon markets and corporate climate claims. Companies that have reported substantial Scope 2 reductions through annual certificate purchases may see those reductions diminish under hourly matching rules. This could affect net zero roadmaps, science-based targets, and public climate commitments. Consequently, sustainability teams may need to revisit emission reduction strategies and consider whether current approaches remain viable under the revised framework.
Implications extend beyond carbon accounting
The Scope 2 revisions would affect procurement strategy, contract negotiation, supplier relationships, and internal coordination between sustainability and finance functions. Procurement teams would need to evaluate electricity contracts not just on price and renewable content, but on hourly generation profiles and geographic deliverability. This requires different skills and data than traditional energy buying, potentially necessitating training or external support.
Contract negotiations with renewable generators or electricity suppliers would become more detailed. Buyers would need provisions for hourly generation data, verification of deliverability, and alignment with consumption patterns. Sellers would need systems to track and report generation at hourly intervals, adding operational complexity. These requirements could influence contract pricing, as higher-integrity products may command premiums over simplified annual claims.
Supplier relationships may also shift. Renewable generators capable of providing hourly data and demonstrating deliverability could become preferred partners. Electricity suppliers offering tariffs with robust time-matching and transparent emissions factors would differentiate themselves. Certificate providers without granular tracking capabilities might lose market position. These dynamics could reshape the UK renewable energy market over the implementation period.
Internal coordination would need to improve. Sustainability teams responsible for carbon reporting would need closer collaboration with procurement functions managing electricity contracts. Finance teams would need to understand how contract terms affect reported emissions and climate commitments. IT systems would require enhancements to handle hourly data and support more complex accounting methodologies. This cross-functional coordination takes time to establish and may require investment in systems and processes.
Planning steps for affected businesses
Companies should begin assessing their current Scope 2 reporting and electricity procurement arrangements. Review existing electricity contracts to understand whether they include hourly generation data or can demonstrate deliverability. Evaluate internal data systems to determine whether they can handle hourly consumption and attribute matching. Identify gaps between current practices and likely requirements under the revised standard.
Engage with electricity suppliers and renewable energy providers to understand their readiness for hourly reporting and deliverability verification. Some suppliers may already offer products designed to meet anticipated standards, while others may need time to develop appropriate offerings. Early dialogue can help businesses understand market options and potential timelines for transitioning to higher-integrity procurement approaches.
Consider whether renewable energy claims are material to business operations beyond carbon reporting. Companies bidding for public sector contracts under PPN 06/21 or similar frameworks may need to demonstrate credible emissions reductions. Organizations making public net zero commitments may face stakeholder scrutiny over accounting methodologies. Businesses targeting sustainability-linked finance may need robust Scope 2 reporting to meet loan or bond criteria. These broader contexts should inform decisions about when and how to adjust procurement strategies.
Develop a transition plan that accounts for contract renewal cycles and data system capabilities. Many electricity contracts run for one to three years, providing natural points for renegotiation. Data systems may require longer lead times for enhancements, particularly if hourly metering is not currently in place. Phasing changes over time can reduce disruption and spread costs, but requires early planning to align with anticipated implementation deadlines.
Monitor the consultation process and final standard publication. The GHG Protocol may modify proposals based on stakeholder feedback, potentially affecting specific requirements or timelines. Industry associations and professional bodies such as IEMA may provide guidance on interpreting and implementing the revised standard. Staying informed about these developments will help businesses refine their plans as details become clearer.
Where to find authoritative guidance
The GHG Protocol website provides the current Scope 2 Guidance and consultation documents for the proposed revisions. This resource includes technical annexes, stakeholder submissions, and updates on the standard development process.
The Institute of Environmental Management and Assessment offers professional guidance on carbon accounting and environmental reporting for UK businesses. IEMA members have access to technical briefings and training on GHG Protocol standards and their application in UK contexts.
The UK government's energy and emissions projections provide context on grid decarbonization and electricity system changes that underpin the Scope 2 revisions. These projections help businesses understand how grid emissions factors may evolve and inform long-term procurement planning.
For businesses seeking support with carbon reporting compliance and procurement strategy aligned with emerging standards, SBS provides compliance services that address Scope 2 reporting and renewable energy procurement. Additionally, our net-zero program helps organizations develop emissions reduction strategies that account for evolving reporting requirements.