Scope 2 reform is tightening how companies report purchased electricity emissions, pushing Singapore corporates to match consumption with local renewable energy certificates (RECs) from the same grid, rather than relying on cheaper regional certificates. In practice, this means imported I‑RECs from Vietnam, India, or Thailand are far less likely to count for high‑integrity, audit‑ready claims.
The GHG Protocol is updating its Scope 2 Guidance to strengthen both location‑based and market‑based accounting. A technical working group has proposed stricter hierarchies for emission factors and more granular matching between electricity use and renewable supply, including new regional and hourly matching criteria. While hourly data will not be mandatory in every case, the direction of travel is clear: claims must be closer to physical reality.
For Singapore, that shift lands in a uniquely constrained context. The grid is small, over 90% gas‑fired, and domestic renewables are almost entirely rooftop solar capped by land availability. Historically, many corporates buying power in Singapore met “100% renewable” goals via ASEAN RECs, often at lower cost. Under proposed guidance and parallel frameworks like RE100 and ISO 14064‑1, those regional certificates will no longer be acceptable for market‑based Scope 2 claims in Singapore.
Local expectations are moving in the same direction. Singapore Standard SS 673 already recommends that buyers prioritise Singapore‑origin RECs and use regional supply only where local options are unavailable. As scrutiny from auditors, investors, and customers increases, CFOs and sustainability teams face a simple question: can they defend their renewable electricity claims if challenged under emerging rules?
The result is a fast‑tightening compliance gap. Companies with long‑dated net‑zero targets may see reported Scope 2 emissions rise sharply if they continue to rely on imported RECs. Forward‑looking procurement teams are therefore re‑examining contracts, internal policies, and risk assumptions to ensure their renewable strategies will hold up when the revised GHG Protocol becomes binding in internal and external reporting cycles.
Singapore‑local RECs are becoming the linchpin of credible Scope 2 reporting because standards now expect certificates to come from the same market boundary as electricity consumption, yet Singapore has limited domestic solar capacity. That tension is already visible in pricing and availability for Singapore‑origin certificates.
Under GHG Protocol Scope 2 and aligned initiatives like RE100, companies are expected to match electricity use with renewable instruments from within the same interconnected grid. Climate Impact X notes that, for Singapore, that usually means RECs generated inside the national market rather than in neighbouring ASEAN countries. Singapore’s SS 673 standard reinforces this, positioning local RECs as the most straightforward route to high‑integrity claims.
Supply, however, is structurally constrained. By early 2026, Singapore had installed around 2 GW of solar capacity against a 3 GW 2030 ambition, leaving limited remaining headroom for new projects. Most of that capacity is distributed rooftop PV rather than large‑scale ground‑mount farms. Once available rooftop space is contracted, incremental REC volumes will be hard to add, even if corporate demand keeps rising.
Market data already shows how scarcity plays out. Eco‑Business reported that solar RECs from Singapore fetch some of the highest prices globally, estimated at around US$65/MWh, driven by high demand and tight supply. As GHG Protocol reforms make imported RECs less acceptable for claims in Singapore, any remaining spread between Singapore and regional REC prices is likely to widen further.
At the same time, there is growing risk that some existing contracts do not provide the level of traceability and additionality that future auditors will expect. Generic unbundled RECs bought on short‑term (1–2 year) contracts provide little visibility on future volumes or project‑level details. Companies that want defensible claims increasingly look for long‑term offtake linked to identifiable local assets, with clear documentation they can show to auditors and stakeholders.
All of this means Singapore‑origin RECs are not just a compliance requirement but a strategic asset class. Finance and procurement leaders now need a sourcing strategy that secures long‑dated access to local RECs, ideally via structured offtake that pre‑empts scarcity rather than chasing spot volumes in an increasingly competitive market.
A Singapore‑local virtual power purchase agreement (VPPA) links your load to specific rooftop solar assets, delivering bundled local RECs and audited documentation that make Scope 2 claims more defensible under revised GHG rules. Instead of buying anonymous certificates, you contract against named projects on the Singapore grid.
In a typical off‑site VPPA structure, a developer leases rooftop space from building owners to install PV systems that inject electricity into the grid. Your company signs a contract‑for‑difference with the developer, paying a fixed strike price for each MWh of renewable generation and receiving the associated Singapore‑origin RECs. The electrons flow into the local grid, while you retain the environmental attributes and price certainty.
This structure addresses several GHG Protocol expectations in one step. First, it secures market‑based Scope 2 instruments from the same grid as your consumption, satisfying regionality requirements. Second, because the VPPA is tied to identified assets and generation volumes, you gain project‑level evidence of impact and avoid double‑counting. Third, if the contract enables new rooftop installations, it clearly demonstrates additionality compared to short‑term REC purchases.
The Maiora portfolio that Peak Energy recently acquired in Singapore is an example. Nearly 10 MWp of operating rooftop capacity across roughly 30 sites injects about 4.5 GWh per year into the grid, with RECs historically sold on a merchant basis. Under a VPPA, those volumes are allocated to a contracted corporate buyer instead, locking in long‑term access to local certificates that meet emerging standards for regional matching.
From a defensibility standpoint, a contract‑backed VPPA also simplifies audit workflows. Rather than compiling a patchwork of short‑term REC contracts from various registries and brokers, you can point to a single long‑term agreement, meter data, and registry records that directly link your claims to specific Singapore assets. That can be particularly valuable for listed companies and multinationals subject to external assurance.
Finally, VPPAs create a forward‑looking hedge against further tightening of guidance. If the GHG Protocol or initiatives like RE100 move towards stricter temporal matching (e.g., annual, seasonal, or even hourly), a relationship with a Singapore rooftop portfolio offers more flexibility to adapt than commodity‑style REC purchases from distant markets.
Fixed‑price VPPAs in Singapore use a contract‑for‑difference structure to stabilise the combined cost of electricity and RECs over the contract life, reducing exposure to volatile USEP and REC spot prices. For CFOs, this converts a variable, difficult‑to‑forecast environmental spend into a predictable line item.
Under Peak’s VPPA model, the rooftop system injects power into the grid and receives the Uniform Singapore Electricity Price (USEP). Your company pays a fixed strike price per MWh (for example, S$220/MWh), and the difference between the strike and realised USEP is settled monthly. In parallel, the bundled Singapore‑origin RECs are transferred to you, aligned with the metered generation.
This structure insulates you from two sources of volatility. First, Singapore’s wholesale power prices are heavily exposed to global gas markets, with roughly 96% of generation gas‑fired. Regional geopolitical shocks have recently caused USEP spikes, and analysts expect elevated volatility to persist. Second, REC prices in Singapore are already high and can swing significantly as new buyers enter the market or regulatory expectations shift.
Contrast that with current retail options. Two‑year fixed retail electricity plans in Singapore have recently hovered around 27.7–28.8 cents/kWh, slightly below the SP regulated tariff of about 29.7 cents/kWh including GST, but these rates cover electrons only. RECs must be procured separately, typically under short‑term contracts that do little to hedge future price risk or supply access.
By locking in a VPPA strike price for five to twelve years, you effectively cap your long‑run cost for both electrons and environmental attributes associated with a defined volume. That can support more accurate budgeting, improve visibility for capital planning, and reduce the likelihood of unpleasant surprises late in your decarbonisation journey.
For developers, the same structure provides a stable revenue stream, improving bankability and enabling more rooftop capacity to be built. That, in turn, increases the pool of Singapore‑origin RECs available to corporates. In this way, a well‑structured VPPA becomes both a financial hedge and a mechanism for expanding local supply.
To “future‑proof” Scope 2 reporting, Singapore corporates need a structured procurement strategy that combines location‑aligned instruments, long‑term contracts, and clear internal rules for renewable claims. This requires coordination between finance, procurement, and sustainability teams.
The starting point is a gap analysis. Map your current electricity supply, REC purchases, and contractual terms against emerging GHG Protocol expectations and local standards like SS 673. Identify what portion of your claimed renewable consumption is backed by Singapore‑origin instruments, and where you still rely on regional or global RECs that may not qualify in future disclosures.
Next, define your risk appetite across three dimensions: compliance, cost, and reputation. Some companies will prioritise locking in high‑integrity local supply even if it carries a premium over imported certificates. Others may seek a staged transition, reallocating a portion of demand to Singapore VPPAs while gradually phasing down regional instruments as contracts roll off.
From there, procurement can build a portfolio approach. One common pattern is to secure a core tranche of long‑tenor VPPAs covering a significant share of predictable load—especially in energy‑intensive facilities like fabs, data centres, or pharma plants—while retaining some flexibility through shorter‑term retail contracts and limited spot REC purchases. The goal is to ensure that, by the time Scope 2 revisions are fully embedded in reporting regimes, your major sites are substantially covered by local, contract‑backed supply.
Governance is equally important. Update internal policies to specify which instruments qualify for external claims, how evidence is stored, and who signs off on renewable disclosures. This reduces the risk of inconsistencies between sustainability reports, financial filings, and marketing materials, and provides a clear audit trail if external assurance providers or regulators ask detailed questions.
Finally, engage early with key stakeholders: auditors, board committees, and major customers who themselves face decarbonisation pressures. Transparent communication about how your organisation is adapting to Scope 2 reform—and prioritising Singapore‑local RECs—can strengthen trust and position your company as a credible leader rather than a late‑stage compliance follower.
Peak Energy’s Singapore rooftop VPPA owns domestic solar capacity into contract‑backed volumes of Singapore‑origin RECs, giving corporates a scalable, defensible path to Scope 2 compliance. It combines immediate availability of local supply with long‑term price and volume visibility.
Following the acquisition of a nearly 10 MWp rooftop portfolio from Maiora Renewable Energy, Peak can now allocate approximately 4.5 GWh per year of operating rooftop solar generation into corporate VPPAs. A portion of this volume is available for contracting as early as 2027, with full 4.5 GWh/year starting in 2028 and additional 20–30 GWh/year expected in later tranches as more assets are built.
The contract structure is a fixed‑price contract‑for‑difference on the RECs versus USEP, with tenors typically ranging from 5 to 12 years. Corporates pay a pre‑agreed strike price per MWh and receive the associated Singapore‑origin RECs, aligned to metered generation injected into the Singapore grid. This directly supports compliance with GHG Protocol regionality requirements and local guidance that prioritises domestic certificates.
Because the portfolio consists of rooftop PV projects already operating—or in late‑stage development—offtakers gain immediate or near‑term access to local volumes rather than waiting for cross‑border imports that may not be fully operational until the 2030s. In a market where distributed generation is likely to remain the primary route for new solar due to land constraints, this early access can be a significant strategic advantage.
Financially, the VPPA structure converts volatile electricity and REC prices into a predictable cost base over the life of the contract. For energy‑intensive manufacturers, data centres, and industrial clusters in Singapore, that stability can support both margin protection and investment cases for on‑site efficiency or electrification projects that depend on clean power assumptions.
Crucially, the offer is built around defendability. Contract documents, metering data, and REC registry records can be aligned to support assurance processes, while Peak’s local development and operations team provides ongoing support on questions from auditors or global headquarters. Backing from Stonepeak, a global infrastructure investor with roughly US$76 billion in assets under management, reinforces the long‑term reliability of delivery.
For Singapore corporates facing a tightening Scope 2 landscape, this kind of contract‑backed, Singapore‑local VPPA can move renewable procurement from a tactical REC purchase to a strategic, board‑level risk management tool—anchoring both compliance and competitiveness in a more demanding regulatory era.